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174-066
STATE OF ALASKA • RECEIVED ALA. OIL AND GAS CONSERVATION COMMISSION APR 1 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate ❑ Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate 0 Re -enter Suspended Weft ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ID Exploratory ❑ 174 -066 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: AK 99503 50-133-20268-00 — a a 7. Property Designation (Lease Number): 8. Well Name and Number: Soldotna Creek Unit (FEDA- 028997) ^ Soldotna Creek Unit (SCU) 44 -04 9. Field /Pool(s): �, Swanson River Field /Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,031 feet Plugs measured 10,546 & 10,696 feet true vertical 10,853 feet Junk measured N/A feet Effective Depth measured 10,546 feet Packer measured 10,356 feet true vertical 10,853 feet true vertical 10,221 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 18" 77' 77' Surface 3,357' 10 -3/4" 3,357' 3,356' 3,130 psi 1,580 psi Intermediate Production 10,585' 7 -5/8" 10,585' 10,439' 6,020 psi 3,400 psi Liner 625' 5 -1/2" 11,031' 10,853' 10,560 psi 11,160 psi Perforation depth Measured depth 10,418- 10,423: 10,424- 10,447: 10,471- 10,527 feet True Vertical depth 10, 281 -10, 285 :10,286- 10,308:10.331- 10,384 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3 # /L -80 10,414' 10,276' Packers and SSSV (type, measured and true vertical depth) Baker Premier 10,356' MD, 10,221' N/A N/A Packer TVD 11. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A '` ` APR 1 2 2U12 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 150 25 750 psi 200 psi Subsequent to operation: 1 250 30 1,250 psi 250 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development IN - Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Stan Golis Printed Name Stan Golis D Title Operations Manager Signature c._) \ ti"t+- Phone 907 - 777 -8300 Date q / S I jl. DMS APR 1 p I `t' -//- / a_ Submit o %4 1 2 Form 10 404 Revised 10/2010\�� • • 1 11 Hilcorp Alaska, LLC W ell Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 44 -04 Plug Back /Perforate 50- 133 - 20268 -00 174 -066 3/12/12 3/18/12 Daily Operations: 3/11/2012 - Sunday RU lubricator, pressure test lubricator to 250 psi low /2,500 psi high. RIH with 2- 1/2 "x30' bailer loaded with 5 gal of chemical wash with 2.72" LIB on bottom. Close vent at 10,565' and dump chemical wash to get good cement bond. POOH. LIB did not show a good sign of closing vent. RIH w/2.72" centralized LIB and close vent on plug at 10,565'. POOH. RIH twice w/2 -1/2 "x30' dump bailer of Neo 17 lb cement and dumped cement from from 10,565' to 10,556'. Cement in Place at 17:35 hrs. Rig Down E- line and WOC. Tubing pressure 200 psi. 3/17/2012 - Saturday RU and pressure test to 250 psi low and 2,500 psi high. Ran the following perforation run using Perf Record of 11/14/11: RIH w/2 -1/2 "x26' HC, 6 spf, 60 deg perf gun. Perfed from 10,501' to 10,527'. POOH. RD. 3/18/2012 - Sunday RU and pressure test to 250 psi low and 2,500 psi high; ran three of the following perforation runs using Perf Record from 11/14/11: 1) RIH w/2 -1/2 "x31' HC, 6 spf 60 deg phase perf gun. Perfed from 10,470' to 10,501'. 2) RIH w/2 -1/2 "x23' HC, 6 spf, 60 deg phase perf gun. Perfed from 10,447' to 10,424'. 3) RIH w/2- 1/2 "x6' HC, 6 spf, 60 deg phase perf gun. Perfed from 10,423' to 10,418'. RD lubricator and turned well over to production. III Swanson River Unit SCU 44 -04 Well SCU 44-04 Last Completed 11/1/11 SCHEMATIC Updated 3/23/12 Itilrnr Ala °Lc,. 1.1.4 RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB — THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top ) J ' 1 1 1 18" Conductor 104. B - Surf 77' - - Driven 18" 10 -' /I' Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77+ T / °" 33.7 P -110 6.765 Surf 78' 73/4" 26.4 N -80 6.969 78' 3,868' 2 ( 7'/," 29.7 N -80 6.875 3,868' 5,759' 1200 sx '5,075' CBL r 7'/" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 - %" 3 1 1 7'/," 33.7 P -110 6.765 7,235' 7,927' T / °" DV Collar 7,927' 7,929' 740 sx 5,075' CBL 10 -3/4" j 4 1 * 7 %" 33.7 P -110 6.765 7,929' 10,585' 3,357' I 5'h" Liner 23 N -80 4.670 10,406' 11,031' 6'/," 130 sx 10,500' CBL 5 1 Tubing • C I OD CBL TOC 3 W', EUE 8RD 1 9.3 1 L -80 1 2.992 1 Surf 1 10,414' 5,606' 6 1 7 I - JEWELRY DETAIL No. Depth ID OD Item ° "' 8 I r* Sqz Perfs 1 23' Tubing Hanger, Shaffer 91 8,033' - 8,034' 2 2,177' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL CBL TOC 111 1 I 3 3,873' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 9,840 — ' 4 5,378' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.ORSL 11 .-.i 5 6,690' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 12 . L 6 7,813' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.ORSL 7 8,748' 2.867" 5.313" Gaslift Mandrel, GLMAX- I.ORSL `i r -, 8 9,590' 2.867" 5.313" Gaslift Mandrel, GLMAX- I.ORSL 13 E 9 10,241' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.0RSL 0 - A 9 10 10,322' 2.992" 5.02" Chemical Injection Sub ; 14 ' 1 11 10,337' 3.250" 4.000" 10' Seal Assembly (Bury 7' of seals) 12 10,340' 4.00" 5.875" 10' PBR Corrected ' , 15 ow 13 10,356' 4.00" 6.625" Permanent Packer, Premier TOL 10,409' 14 10,362' 2.992" 3.50" 3 -1/2" TC II x 3 -1/2" EUE 8RD XO CBL TOC `' ' r+ 16 15 10,406' 2.813" 3.95" X- Profile (2.813" Min ID) 10,41 1 G -1 16 10,414' 3.00" 4.49" Wireline Entry Guide 17 10,578' 5 -1/2" TTBP w/ 22' cement / TOC @ I 17A 10,696' 5 -1/2" EZ -SVB Cement Retainer (corrected depth) 0,546'ELM • 1 G -2 18 10,697' 1.997" - Sliding Sleeve, Otis XA (Opens Up) Closed 4/21/75 7 17 19 10,699' - - Packer, 5 -1/2" Baker FH 10,585' . - L 19A +/- 10705' Slickline fish - SS shifting tool H - 20 10,706' - - Otis `S' Nipple Position #2 w/ plug installed - H-4 21 10,707' - - Blast Joints, 3 jts, 3.062" OD ' 22 10,768' CC Safety Joint, Brown Tag retainer . 23 10,770' 1.997" Sliding Sleeve, Otis XA (Opens Up) Open 2/6/78 10,692'ELM , H -5 24 10,772' Packer, 5 -1/2" Baker FH Rotational Set Tubing Stub. 17A +1 25 10,773' Fish, possible gaslift valve covered with asphaultenes wed 7 18 • ��� 'a 26 10,779' Camco `D' Nipple 1 _— ` 1 , 27 10,780' Blast Joints, 3 jts, 3.062" OD 19 = ` --a 28 10,825' Shear Out Sub, Baker • ralii 20 ►fit PERFORATION HISTORY 21 UH - Interval Accum. 22 Date Zone Top Btm Amt spf Comments 23 LA 03/20/75 Sqz Perf 8,033' 8,034' 1' 4 Squeezed 24 = I1 = 03/20/12 G -1 10,418' 10,423' 5' 6 2 -1/2" HC 60deg ' E 03/20/12 G -1 10,424' 10,447 23' 6 2 -1/2" HC 60deg 25 1 ' « 26 %til LH - 8 03/20/12 G - 2 10,470' 10,527 57' 6 2 - 1/2" HC 60deg 27 1.t.. 1 11/14/11 H -3 10,583' 10,599' 16' 6 2 -1/2" PJ Omega Retainer w/ cmt 'S' 28 r �f� H -9 11/14/11 H-4 10,620' 10,629' 9' 6 2 -1/2" PJ Omega :.V. f 11/14 H -5 10 655' 10 690' 35' 6 2 -1/2" PJ Omega lo10,844'40,850' 10,844'40,850' ::+ , ; ; y a g 111 - 10 04/11/75 UH -8 10,720' 10,770' 50' 4 Proposed P&A 2011 5 -1/2" ' . 04/11/75 LH -8 10,782' 10,802' 20' 4 Proposed P&A 2011 1Q = TD D = 11,031' PBTD = 11,005 11,005' 04/09/75 H -9 10,808' 10,824' 16' 4 Proposed P&A 2011 = MAX HOLE ANGLE = 26.25° @ 11,031' 04/05/75 H -10 10,856' 10,876' 20' 4 P&A 4/9/75 SCU 44 -04 Actual Well Schematic 3 -23 -12 Updated by CVK 3 -23 -12 ATE OF ALASKA • ALASKA OIL AN CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 11 Repair Well U Plug Perforations U • Stimulate 11 Other U Performed: Alter Casing ❑ Pull Tubing Q Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El - Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 174 -066 . 1 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic El Service ❑ 6. API Number: 50- 133 - 20268 -00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 [Soldotna CreekUnit] Soldotna Creek Unit 44 -04 " 9. Field /Pool(s): 4. Swanson River Field/ Hemlock Oil Pool • 10. Present Well Condition Summary: Total Depth measured 11,031 • feet Plugs . measured 10,696 feet true vertical 10,853 • feet Junk measured N/A feet Effective Depth measured 10,696 feet Packer measured 10,356 feet true vertical 10,544 feet ': "t tr` . ;F. ri t -l I true vertical 10,221 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 18" 77' 77' Surface 3,357' 10 -3/4" 3,357' 3,356' 3,130 psi 1,580 psi Intermediate Production 10,585' 7 -5/8" 10,585' 10,439' 6,020 psi 3,400 psi Liner 625' 5 -1/2" 11,031' 10,853' 10,560 psi 11,160 psi Perforation depth Measured depth 10,583- 10,599; 10,620- 10,629; 10,655- 10,690 Feet True Vertical depth 10,437- 10,452; 10,472- 10,481; 10,505- 10,539 Feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" L -80 10,414' 10,276' Baker Premier 10,356' MD, Packers and SSSV (type, measured and true vertical depth) Packer 10,221' TVD N/A _ N/A E E.tvE 11. Stimulation or cement squeeze summary: N/A �C Intervals treated (measured): N/A FIE t - 5 j_ ?M'' Treatment descriptions including volumes used and final pressure: N/A Aintka Olt 8i. tam Cons. Commission 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 0 psi Subsequent to operation: 1 45 98 827 psi 161 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 ' • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil - 0 • Gas ❑ WDSPL Lf GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -304 Contact Chris Kanyer Phone: 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager f � Signature ` 0 � P hone 276-7600 Date 12/8/2011 Form 10 -404 Re - i 011 : • M T C 16 2014: 4.010, Submit Original Only I + I r evro Swanson River Unit SCU 44 - 04 Well SCU 44 -04 SCHEMATIC Updated1p2/8/1 11/1/11 1 RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB — THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 18" J 1 I 18" Conductor 104 B Surf 77' Driven ` 10-%" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' 7' /," 33.7 P -110 6.765 Surf 78' 7 %" 26.4 N -80 6.969 78' 3,868' 2 1 7'/," 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL 7 %" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 - %" 3 1 7 %" 33.7 P -110 6.765 7,235' 7,927' 7 %" DV Collar 7,927' 7,929' 3,357 4 it 7'/," 33.7 ' P -110 6.765 7,929' 10,585' 740 sx 5,075' CBL 3,357' 11.11 S' / :" Liner 23 N -80 4.670 10,406' 11,031' 6-%" 130 sx 10,500' CBL 5 1 Tubing C 1 OD CBL TOC 3'h ", EUE 8RD 1 9.3 1 1, 1 2.992 1 Surf 1 10,414' 5,606' 6 1 ' 7 1 JEWELRY DETAIL c,-,.. No. Depth ID OD Item 'c . 8 1 - Sqz Perfs 1 23' Tubing Hanger, Shaffer 9 8,033' - 8,034' 2 2,177' 2.867" 5.313" Gaslift Mandrel, GLMAX- I.ORSL CBL TOC 10 3 3,873' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 9,840' 4 5,378' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 11 5 6,690' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL . 12 r _ 6 7,813' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 7 8,748' 2.867" 5.313" Gaslift Mandrel, GLMAX- l.ORSL f _ 1 8 9,590' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.ORSL 13 9 10,241' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 0 k 10 10,322' 2.992" 5.02" Chemical Injection Sub 1 4 11 10,337' 3.250" 4.000" 10' Seal Assembly (Bury 7' of seals) q 12 10,340' 4.00" 5.875" 10' PBR Corrected TOL 15 I 13 10,356' 4.00" 6.625" Permanent Packer, Premier 10,409' 1 14 10,362' 2.992" 3.50" 3 -1/2" TC II x 3 -1/2" EUE 8RD XO CBL TOC , 1 6 5 15 10,406' 2.813" 3.95" X- Profile (2.813" Min ID) 10,409' 16 10,414' 3.00" 4.49" Wireline Entry Guide 17 10,696' 5 -1/2" EZ -SVB Cement Retainer (corrected depth) 18 10,697' 1.997" - Sliding Sleeve, Otis XA (Opens Up) Closed 4/21/75 . 19 10,699' - - Packer, 5 -1/2" Baker FH 19A +1- 10705' Slickline fish — SS shifting tool 7-5/8" 10,585' L 20 10,706' - - Otis `S' Nipple Position #2 w/ plug installed H -3 21 10,707' - - Blast Joints, 3 jts, 3.062" OD 22 10,768' CC Safety Joint, Brown : H -4 23 10,770' 1.997" ___Sidin Sleeve, Otis XA (Opens Up) Open 2/6/78 Tag retainer u' " 24 10,772' Packer, 5 -1/2" Baker FH Rotational Set 10 692'ELM H -5 25 10,773' Fish, possible gaslift valve covered with asphaultenes Tubing stul � 17 26 10,779' Camco `D' Nipple Milled to +1 10,697' 18 ,M: 27 10,780' Blast Joints, 3 jts, 3.062" OD i i - t 28 10,825' Shear Out Sub, Baker 19 __ . PERFORATION HISTORY UH -8 Interval Accum. r Date Zone Top Btm Amt spf Comments 03/20/75 SqzPerf 8,033' 8,034' 1' 4 Squeezed 24 1 ' t i IE! 11/14/11 H -3 10,583' 10,599' 16' 6 2 -1/2" PJ Omega / 11/14/11 H-4 10,620' 10,629' 9' 6 2- 1 /2 "PJ Omega `' 26 r f 11/14/11 H -5 10,655' 10,690' 35' 6 2 -1/2" PJ Omega r LH -8 04/11/75 UH-8 10,720' 10,770' 50' 4 P &A 2011 27 i 04/11/75 LH-8 10,782' 10,802' 20' 4 P &A 2011 SO Retainer w/ cmt 28 `fti { {: 11 - 04/09/75 H -9 10,808' 10,824' 16' 4 P &A 2011 10,844' - 10,850' t j tirti:;f�a tia 04/05/75 H -10 10,856' 10,876' 20' 4 P &A 4/9/75 ' H -10 5-1/2" 10,964' • ■ TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44 -04 Actual Well Schematic 12- 8- 11.doc Updated by CVK 12 - - 11 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 44 -04 SOLDOTNA CK UNIT 44 -04 FEDA028997 5013320268 QA9354 150.00 Jabs, ; Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion - Reconfigure Major Rig 10/17/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 44 -04 501332026800 1 740660 Dally 01xtraliOtte 10/17/2011 00:00.1011812011 00:00 Operations Summary Received AOGCC & BLM approval to sundry changes. RU slickline at 16:00hrs. Pressure test lubricator 250psi low /2500psi high. RIH and brush sliding sleeve (10,697) & S nipple (10,706'). RIH and set plug in S nipple at 10,706'. RIH and opened sliding sleeve at 10,697'. RIH with 2.8" GR and tag 2- 3/8 "x3 -1/2" crossover at 10,324'. RD slickline. 10/18/2011 00:00 - 1011912011 00:00 Operations Summary Attempt to fill well with lease water and circulate same, no returns to surface. RU slickline, pressure test lubricator 250psi low /2500psi high. RIH with 1.6" GR and tag plug in S nipple at 10,706'. RIH with with sliding sleeve shifting tool and latch sliding sleeve at 10,697', attempted to close, tool sheared, pulled up hole, working through tight spots until pulling into 3 -1/2" tubing at 10,324', POOH, left several components of shifting tool in tubing. RD slickline. 10/1912011 00:00 - 10/20/2011 00:00 Operations Summary RU Eline, pressure test lubricator 250psi low /3,000psi high. RIH and set 3 -1/2" WRP at 300'. RD Eline. Fill tubing with lease water and pressure test WRP to 3,000psi for 30min. ND tree and begin mobe of equipment. 10/20/2011 00:00 - 10/21/2011 00:00 Operations Summary Continue to mobe equipment and begin rig up of Key Rig #3. Notified AOGCC and BLM of upcoming BOP test. 10/21/2011 00:00 - 10/2212011 00:00 Operations Summary Continue rig up of Key Rig #3. NU BOPE. Pressure test all valves & rams 250psi low /3,000psi high, and annular to 250psi low /1,500psi high. RU slickline, pressure test lubricator 250psi low /2,500psi high. RIH and latch 3 -1/2" WRP at 300', POOH w/ same. RIH with 2.5" magnet to 10,324', no recovery. RIH with 1.75" magnet (2 runs) to 10,726' SLM, no recovery. RIH with 1.68" LIB and tag at 10,726'SLM. RIH w/ 1.83" aligator grab to 10,726'SLM, no recovery. RIH w/ 1.75" pump bailer to 10,726'SLM, POOH recovered scale. 10/22/2011 00:00 - 10123/2011 00:00 • Operations Summary RIH with 1.75" magnet to 10,726' SLM, no recovery. RIH w/ 1.83" aligator grab to 10,726'SLM, no recovery. RD slickline. Attempt to unseat tubing hanger, no success. RU Eline, pressure test lubricator 250psi low /2,500psi high. RIH with 6' tubing punch to 10,692'ELM, pull up hole and punch 2 -3/8" tubing from 10,682'- 10,687.5'ELM, POOH. RIH with 1 -1/2" radial torch and tag at 10,689'ELM, pull up hole and cut tubing at 10,677'ELM. RD Eline. Attempt to unseat tubing hanger, no success. LD landing joint, PU spear, bumper sub, jar and drill collar, spear hanger and jar tubing hanger off seat. 10/2312011 00:00 - 10/2412011 00:00 Operations Summary LD drill collar, jar, spear, & tubing hanger. Circulate well with lease water. Begin POOH with 3- 1/2 "x2 -3/8" completion. 10124/201100:00 - 10/25/2011 00:00 Operations Summary Continue POOH & LD with 3- 1/2 "x2 -3/8" completion from 10,677ELM'. RIH with overshot, 12 jts 2 -7/8 ", 2- 7/8 "x3 -1/2" crossover, jar, drill collars and 3 -1/2" workstring to 10,653', circulate well, RIH and engage tubing stub at 10,692'DPM, jar and attempt to rotate off at CC safety joint at 10,768', pulled free, circulate bottoms up. 10/25/2011 00:00 - 10126/2011 00:00 Operations Summary POOH with workstring & overshot. LD 5.75' of parted 2 -3/8" tubing fish. Begin RIH with 4 -1/2" mill assembly. Notified AOGCC & BLM of upcoming tag of plug. 10/26/201100:00.10 /27 /2011 00:00 Operations Summary RIH with 4 -1/2" mill assembly, mill tubing from 10,698' to 10,708' (top of sliding sleeve). Circulate well, POOH and LD milling BHA. 10/27/2011 00:00 - 10/28/2011 00:00 Operations Summary RIH with 5 -1/2" EZ -SVB cement retainer on workstring and set at 10,707', sheared out of plug, set down on retainer with 10K, witnessed by AOGCC Bob . NQble. Sting into retainer, Test 7 -5/8" casino to 1500osi for 15min. Attempt injection below retainer, pressured to T4 psi or min, no El ee o f . Uniting from retainer and POOH to 9,081', MU RTTS storm packer and RIH placing RTTS at 60' and set same. Release from RTTS and POOH. Pressure tested RTTS to 1500psi for 10min, ND BOP, ND old tubing head, NU new tubing head and test same to 250psi low /3500psi high Notified AOGCC and BLM of upcoming BOP test. 10/28/2011 00:00 - 10/29/2011 00:00 Operations Summary NU BOP, pressure test all valves & rams 250psi low /3,000psi high, annular to 250psi low /1500psi high. RIH to 60', release and retrieve RTTS storm packer, POOH with cement stinger from 9,081'. Begin RIH with 4 -1/2" mill & string mill x 7 -5/8" casing scraper BHA. Bob Noble waived witness of BOP test. Chevron 1 1 Nt0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) ' Water Depth (ft) SCU -04 SOLDOTNA CK UNIT 44 -04 FEDA028997 5013320268 QA9354 150.00 10/2912011 00:00 - 10/30/2011 00:00 Operations Summary Continue RIH with 4 -1/2" mill & string mill x 7 -5/8" casing scraper BHA to 10,678', tagging top of liner with 7 -5/8" scraper at 10,419'. Circulate well over to 6% KCI. Begin POOH with tandem scraper assembly. 10/30/2011 00:00 - 10/31/2011 00:00 Operations Summary POOH & LD workstring and tandem scraper assembly. Begin RIH with 3 -1/2" 9.3# L -80 completion tubing with 7 -5/8" packer, 10' PBR, 10 seal assembly, & GLMs. 10/3112011 00:00.11/1/2011 00:00 Operations Summary RIH w/ 3 -1/2" completion to 10,457' and tag top of liner, pull up hole to 10,410', leaving 5' of tubing tail into line.", RU slickline, RIH with PX prong and set in plug body in X profile at 10,422'SLM. RD slickline. Pressure up tubing to 3000psi to set 7 -5/8" Premier packer at 10,356', continue to hold pressure for 30min for tubing pressure test, bleed off same. Shear out seal assembly from PBR, space out, and land hanger leaving 7' seals buried in 10' PBR. RU slickline, pull PX prong and plug body set in X profile. RD slickline. Pressure up tubing and pressure test below packer to 1500psi for 30min. Begin ND BOPE. 11/112011 00:00.11/2/2011 00:00 Operations Summary Continue to ND BOPE. NU tree, test same to 250psi low /5000psi high. Begin RD of equipment and demobe of Key Rig #3. 1112/2011 - 11/3/2011 00:00 Operations Summary Demobe Key Rig #3 and equipment from field. 11/3/2011 00:00 - 11/412011 00:00 Operations Summary Demobe Key Rig #3 and equipment from field. 11/4/2011 00:00 - 11/6/2011 00:00 Operations Summary Demobe Key Rig #3 and equipment from field. 11/5/2011 00:00 - 11/6/2011 00:00 Operations Summary Demobe Key Rig #3 and equipment from field. 11/6/2011 00:00 - 11/7/2011 00:00 Operations Summary Demobe Key Rig #3 and equipment from field. Prepare to gaslift well prior to perforating. 11/14/2011 00:00 - 11/16/2011 00:00 Operations Summary RU Eline. Pressure test lubricator 250psi low /3,000psi high. RIH with 2.5" PJ Omega 6spf 60 deg phased guns, tie in and tag cement retainer at 10,692'ELM. perforate 10,690'- 10,670'ELM, POOH. RIH w/ 2.5" PJ Omega guns and make three additional runs and perforate 6spf, 60 deg phased at __ 10,655'ELM, 10,620'- 10, 629'E L M, &00,583'- 10,599'ELM. RD ELine, Turn well over to production. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i1( 10(tf DATE: 10/27/11 P. I. Supervisor I FROM: Bob Noble SUBJECT: Plug Tag and Test Petroleum Inspector Union Oil of California SCU 44 -04, PTD 174 -066 • October 27, 2011: I met with Union Oil of Calif. Rep. Sloan Sunderland. We went over the procedure that they were going to use to set, tag and test the plug. They were running the cement retainer in the hole when I arrived on the location. The retainer was set and then they stung off of it. We then tagged the retainer with 10,000 lbs. The top of the retainer was found to be at 10705' RKB. It appeared not to move. They then performed a pressure test on the plug. 1500 psi was put on the inner ✓ annulus. It was held for 15 min with 0 psi loss. Attachments: none 2011- 1027_P lug_SCU_44- 04_bn. doc 1 of 1 Sheet/Calculations 01/29/10 LG Chevron Swanson River 1110 frp -04 /7Y 666 10/19/2011 • OBJECTIVE: Pull existing completion, abandon existing perfs, replace tubing head, run new completion, thru- tubing wireline perforate Hemlock H -3, H -4, & H -5 sands. Current BHP: 2,680 psi @ 10,633' TVD Max Downhole Pressure: 2,680 psi @ 10,633' TVD (Based on SITP = 0 psi, fluid level at 4,451' and a produced water gradient) MASP: 0 psi (Based on actual reservoir conditions and water cut of 98% (0.438psi /ft) with added Safety Factor of 1000' TVD of oil cap) PROCEDURE SUMMARY: 1 - _ _ . - - - - . _ _ S - 25Opsi- low/250Op- s+ -igh. (Completed) 2 RIkl -and set plug in S nipple at 10,706'. (Completed) ..,. ?WI 3 RIH- and -open sliding sleeve at 10,69T. (Completed) 4 RD sliokine. (Completed) 5 _ _ . - - - _ _ e - _ - - - . (Unable to get returns to surface) 5e¢ . • - -•. •• -•-• - - - - -- •- -•: - - • - •-- - !!e (Not performed) ---2 r<.r /eat 7 MIRU Key Energy Rig # 3. /0./1.,( 8 ND tree, NU ROPE & test same 250psi low/ 3,000psi high, test annular to 250psi low/ 1,500psi high. 9 Pump + /- 8.4ppg lease water down tubing and annulus. 10 RU slickline. 11 RIH and attempt to fish BO shifting tool at +/- 10,324'. 12 RIH and attempt to recover plug in S nipple at 10,706'. 13 RD slickline. 14 RU Eline. 15 RIH and punch tubing at +/- 10,682' to +1- 10,688'. 16 RIH and cut the 2 -3/8" tubing at +/- 10,677'. 17 Pull 3 -1/2" & 2 -3/8" production tubing from +/- 10,677'. 18 RIH and fish upper FH packer at 10,699' and 2 -3/8" tubing down to CC safety joint at 10,768'. 19 RIH and set 5 -1/2" cement retainer at +/- 10,710'. Tag cement retainer w/ 10k to confirm set. 20 Unstab from retainer and circulate well with +/- 8.4ppg lease water. 21 Perform charted pressure test casing to 1,500psi. 22 Stab into retainer, perform injectivity test with +/- 8.4ppg lease water. 23 Attempt to pump +/- 3 bbl of +/- 15.3 ppg cement below retainer Contingency: Circulate out any excess cement, if unable to pump +/- 3 bbl cement below retainer. 24 RIH w/ 5 -1/2" x 7 -5/8" casing cleanout BHA to +/- 10,710'. /' �� lL 1< . . 25 Displace well to +/- 8.6ppg 6% KCI. 26 Pull up hole to +/- 9,000'. PUMU 7 -5/8" RTTS packer, RIH and set at +/- 60'.Release and POOH. 27 ND BOPE. ND tubing head. 28 NU new tubing head and test voids to 250psi low/ 3,500psi high. SCU 44-04 CVK 10/19/2011 Chevron Swanson River • SCU 44 -04 10/19/2011 29 NU BOPE & shell test same 250psi low/ 3,000psi high. 30 RIH w/ retrieving tool, latch & release RTTS packer at +/- 60', POOH & LD RTTS packer, and continue to POOH w/ 5 -1/2" x 7 -5/8" tandem scraper assembly. 31 RIH 7 -5/8" Premier packer, seal assembly, and 3 -1/2" gaslift completion to +/- 10,411', and set packer at +/- 10,353'. 32 ND BOPS. NU and test tree. 250psi Low/ 5,000psi High. 33 RU Eline. Pressure test lubricator 250psi low/ 2,500psi high. 34 RIH and perforate the Hemlock H -3, H-4, & H -5 sands at +/- 10,586' to +/- 10,602', +/- 10,622' to 10,631', +/- 10,656' to +/- 10,691'. 35 RD Eline. 36 Turn well over to production_ SCU 44 -04 CVK 10/19/2011 Page 1 of 3 Schwartz, Guy L (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Wednesday, October 19, 2011 1:45 PM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) We believe that the packer is unset and leaking. Not test was performed on casing /packer prior since live gas lift valves are in the mandrels. We will be able to confirm this hypothesis when we set the cement retainer & pressure test the casing in step #21 of the procedure I sent to you today. Let me know if you have any further questions. Thanks. Chris Kanyer •• Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz @alaska.gov] Sent: Wednesday, October 19, 2011 1:21 PM To: Kanyer, Christopher V Cc: Maunder, Thomas E (DOA) Subject: RE: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Chris, Strange you can't even fill up the tubing and IA with fluid. Any idea where leak is? ( plug , packer , casing ) Did IA test before opening sleeve? None the less , reverting to the original sundry is fine. Regards. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kanyer, Christopher V [ mailto: Chris.Kanyer @chevron.comj Sent: Wednesday, October 19, 2011 12:16 PM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Please see attached proposed procedure change and schematic for SCU 44 -04, approved sundry 311- 304 (PTD 174 -066). Due to our inability to fill the well with lease water with a plug set in the S nipple, prior to pressure testing the packer & plug, we plan to return to the original sundry procedure to fish the upper FH packer and set a cement retainer to abandon the open perforations. 10/19/2011 Page 2 of 3 I will call shortly to follow up if you have any questions. Thanks, Chris Kanyer • • Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, October 17, 2011 9:18 AM To: Kanyer, Christopher V Cc: Maunder, Thomas E (DOA) Subject: RE: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Chris, I don't see any issue with replacing the retainer with a retrievable plug set in the nipple at 10706'md. Looks like you are foregoing fishing the packer and blast joints also. The perforations are all behind the blast joints in this straddle section. You are testing the plug and casing to 1500 psi which will prove you have competent barriers ( plug and Packer are holding.). You are adding additional Hemlock (same pool) perforations just above this zone as part of the RWO scope. At final abandonment for the well this zone (UH -8) can be further isolated with cement set on top of the packer and tubing stub (or possibly even attempting to retrieve the plug and squeezing off the UH -8 zone). The use of the plug set in the nipple profile is granted per 20 AAC 25.112 (i) Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kanyer, Christopher V [mailto:Chris.Kanyer @chevron.com] Sent: Monday, October 17, 2011 6:57 AM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Guy, Please see message below and attached documents. I will call you sometime this morning to discuss. Thanks, Chris Kanyer • • Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 10/19/2011 Page 3 of 3 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Kanyer, Christopher V Sent: Monday, October 17, 2011 6:45 AM To: 'Maunder, Thomas E (DOA)! Subject: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Tom, Please see attached proposed procedure change and schematic for SCU 44 -04, approved sundry 311 -304 (PTD 174 -066). Along with these changes we would like to request a variance from requirements of 20AAC25.112(c)(1) (E) to allow plugging with a mechanical bridge plug and not placing the required 25ft cement on top of plug. Planned start date of this well is 10/19/2011. I will call this morning to follow up if you have any questions. Chris Kanyer • • Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 10/19/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, October 17, 2011 9:18 AM To: 'Kanyer, Christopher V' Cc: Maunder, Thomas E (DOA) Subject: RE: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Chris, I don't see any issue with replacing the retainer with a retrievable plug set in the nipple at 10706'md. Looks like you are foregoing fishing the packer and blast joints also. The perforations are all behind the blast joints in this straddle section. You are testing the plug and casing to 1500 psi which will prove you have competent barriers ( plug and Packer are holding.). You are adding additional Hemlock (same pool) perforations just above this zone as part of the RWO scope. At final abandonment for the well this zone (UH -8) can be further isolated with cement set on top of the packer and tubing stub (or possibly even attempting to retrieve the plug and squeezing off the UH -8 zone). The use of the plug set in the nipple profile is granted per 20 AAC 25.112 (i) Guy Schwartz ' Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kanyer, Christopher V [ mailto :Chris.Kanyer @chevron.com] Sent: Monday, October 17, 2011 6:57 AM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) Guy, Please see message below and attached documents. I will call you sometime this morning to discuss. Thanks, Chris Kanyer •• Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Kanyer, Christopher V Sent: Monday, October 17, 2011 6:45 AM To: 'Maunder, Thomas E (DOA)' Subject: SCU 44 -04, Approved Sundry 311 -304 (PTD 174 -066) 10/19/2011 Page 2 of 2 Tom, Please see attached proposed procedure change and schematic for SCU 44 -04, approved sundry 311 -304 (PTD 174 -066). Along with these changes we would like to request a variance from requirements of 20AAC25.112(c)(1) (E) to allow plugging with a mechanical bridge plug and not placing the required 25ft cement on top of plug. Planned start date of this well is 10/19/2011. 1 will call this morning to follow up if you have any questions. Chris Kanyer•• Drilling Engineer Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 10/19/2011 ' /0/ i( , hevron • Swanson River Unit SCU 44 -04 Well SCU 44 -04 4 Proposed PROPOSED SCHEMATIC Updated 9/08/11 tion RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB - THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 L 18" Conductor 104 B - Surf 77' - - Driven 18" — 10 - %" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' 7'/" 33.7 P -110 6.765 Surf 78' 7 %s" 26.4 N -80 6.969 78' 3,868' 2 1 7/" 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL I 71/4" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 -%" 3 1 71/4" 33.7 P -110 6.765 7,235' 7,927' OM 71/4" DV Collar 7,927' 7,929' 740 sx 5,075' CBL 10 -3/4" 4 71/4" 33.7 P -110 6.765 7,929' 10,585' 3,357' I 5%z" Liner 23 N -80 4.670 10,406' 11,031' 6-'/" 130 sx 10,500' CBL 5 I Tubing C OD CBL TOC I 3 % ", EDE 8RD 1 9.3 I 1.-80 I 2.992 I Surf 1 10,411' 1 :. ` , ` . , rs „ 5,606' 6 1 1 ' , - ' 1 © - 1 .1 8 1 1 JEWELRY DETAIL — syz reds No Depth ID OD Item 9 8,033'- 8,034' CBL TOC, i� 1 23.0' Tubing Hanger, Shaffer 9,840' 1 10 .n ' 2 +/- 2,200' 2.867" 5.313" Mandrel, GLMAX- 1.0RSL . 11 3 +/- 3,900' 2.867" 5.313" Gay Mandrel, GLMAX- 1.ORSL 12 4 +/- 5,400' 2.867" 5.313" Gasl i : , Mandrel, GLMAX- 1.ORSL 5 +/- 6,700' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL - 6 +/- 7,820' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL ` a 7 +/- 8,750' 2.867" 5.313" Gaslift Mandrel, GLMAX -1.ORSL 13 -0. w_ 8 +/- 9,600' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 0 II 9 +/- 10,250' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL ' , 14 10 +/- 10,291' 2.992" 4.500" Chemical Injection Sub 11 +/- 10,330' 3.250" 4.000" 10' Seal Assembly (Bury 7' of seals) TOL 15 12 +/- 10,338' 4.000" 5.250" 10' PBR 10,406' , 13 +/- 10,353' 4.000" 6.500" Permanent Packer, Premier CBL TOC 16 j + 14 +/- 10,360' 2.992" 3.500" XO 10,406' N 15 +/- 10,402' 2.813" 3.500" X- Profile (2.813" Min ID) 16 +/- 10,411' 2.992" 4.500" Wireline Entry Guide 17 10,697' 1.997" - Sliding Sleeve, Otis XA (Opens Up) Closed 4/21/75 18 10,699' - - Packer, 5 -1/2" Baker FH 7 -5/8" L Y' 19 10.706' - - Otis `S' Nipple Position #2 w/ plug installed 10,585' 11-3 20 10,707' - - Blast Joints, 3 jts, 3.062" OD 21 10,768' CC Safety Joint, Brown 22 10,770' 1.997' Sliding Sleeve, Otis XA (Opens Up) Open 2/6/78 H4 23 10,772' Packer, 5 -1/2" Baker FH Rotational Set Planned cu: 24 10,773' Fish, possible gaslift valve covered with asphaltenes at +/- H -5 25 10,779' Camco `D' Nipple 10,696'ELN 26 10,780' Blast Joints, 3 jts, 3.062" OD 27 10,825' Shear Out Sub, Baker 35 35 3.5 18 11 19 PERFORATION HISTORY UH -8 ' Interval Accum. 21 Date 1 Zone Top Btm Amt spf Comments 22 L _� 03/20/75 SqzPerf 8,033' 8,034' 1' 4 Squeezed a= mr 11 Proposed H -3 +/- 10,586' +/- 10,602' 16' 6 2- 1 /2 "PJ Omega 23 .=.4.• Proposed H-4 +/- 10,622' +/- 10,631' 9' 6 2 -1/2" PJ Omega 24 a 1.11 - Proposed H -5 +/- 10,656' +/- 10,691' 35' 6 2 -1/2" PJ Omega 25 ,. : g 04/11/75 UH-8 10,720' 10,770' 50' 4 Proposed P &A2011 26 1 a ?j 04/11/75 LH-8 10,782' 10,802' 20' 4 Proposed P &A 2011 Retainer w/ cmt 27 ti; { H 9 04/09/75 H -9 10,808' 10,824' 16' 4 Proposed P &A 2011 r .r r r 10,844' - 10,850' r;;, ;r:.i _ 04/05/75 H -10 10,856' 10,876' 20' 4 P &A 4/9/75 H -10 5-1/2" 10,964' 4 • TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44 -04 Proposed Well Schematic 10- 13- 11.doc Updated by CVK 10 -13 -11 Chevron • wanson River CU 44 -04 IOW 10/17/2011 'T O 17Y- 044 OBJECTIVE: Pull existing completion, abandon existing perfs, replace tubing head, run new completion, thru- tubing wireline perforate Hemlock H -3, H-4, & H -5 sands. Current BHP: 2,680 psi @ 10,633' TVD Max Downhole Pressure: 2,680 psi @ 10,633' TVD (Based on SITP = 0 psi, fluid level at 4,451' and a produced water gradient) MASP: 0 psi (Based on actual reservoir conditions and water cut of 98% (0.438psi/ft) with added Safety Factor of 1000' TVD of oil cap) PROCEDURE SUMMARY: 1 RU slickline. Pressure test lubricator 250psi low /2500psi high. 2 RIH and set plug in S nipple at 10,706'. l' 3 RIH and open sliding slidin sleeve at 10,697'. - �� 4 RD slickline. / 5 Circulate well with +/- 8.4ppg lease water. (/t 6 Perform charted pressure test casing and plug in S nipple to 1,500psi. 7 MIRU Key Energy Rig # 3. cs� 8 ND tree, NU BOPE & test same 250psi low/ 3,000psi high, test annular to 250psi low/ 1,500psi high. 9 RU Eline. 10 RIH and cut the 2 -3/8" tubing at +/- 10,696'. 11 Pull 3 -1/2" & 2 -3/8" production tubing from +/- 10,696'. 12 RIH w/ 5 -1/2" x 7 -5/8" casing cleanout BHA to +/- 10,696'. 13 Displace well to +/- 8.6ppg 6% KCI. 14 Pull up hole to +/- 9,000'. PUMU 7 -5/8" RTTS packer, RIH and set at +/- 60'.Release and POOH. 15 ND BOPE. ND tubing head. 16 NU new tubing head and test voids to 250psi low/ 3,500psi high. 17 NU BOPE & shell test same 250psi low/ 3,000psi high. RIH w/ retrieving tool, latch & release RTTS packer at +/- 60', POOH & LD RTTS packer, and continue to POOH w/ 18 5 -1/2" x 7 -5/8" tandem scraper assembly. 19 RIH 7 -5/8" Premier packer, seal assembly, and 3 -1/2" gaslift completion to +/- 10,411', and set packer at +/- 10,353'. 20 ND BOPE. NU and test tree. 250psi Low/ 5,000psi High. 21 RU Eline. Pressure test lubricator 250psi low/ 2,500psi high. 22 RIH and perforate the Hemlock H -3, H-4, & H -5 sands at +/- 10,586' to +/- 10,602', +/- 10,622' to 10,631', +/- 10,656' to +/- 10,691'. 23 RD Eline. 24 Turn well over to production. SCU 44 -04 CVK 10/17/2011 . • • hevro Swanson River Unit SCU 44 -04 Well SCU 44 -04 Last Completed 4/15/75 Actual Wellbore Schematic Updated 10/10/91 RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB S1 Type Wt Grade ID Top Btm Hole Cmt Cmt Top { , 18" Conductor 104 B Surf 77' Driven 18" 1 , Ia 1 k '" L , 10-3/4" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' # ■ 7 %" 33.7 P -110 6.765 Surf 78' ∎ 73/4" 26.4 N -80 6.969 78' 3,868' 7 %" 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL '-:44, " 7 %" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 -34" 7/" 33.7 P -110 6.765 7,235' 7,927' • ' 2 ow i • 7%" DV Collar 7,927' 7,929' 740 sx 5,075' CBL 10-3/4" . 7 %" 33.7 P -110 6.765 7,929' 10,585' 3,357' 3 ' I' 5/," Liner 23 N -80 4.670 10,406' 11,031' 6 -3" 130 sx 10,500' CBL IIII Tubing Cplg OD AIM CBL TOC 4'` 3 %, ", IBT 9.2 N -80 2.992 Surf 10,324' 4.250" VMS 5,606' 2 % ", EUE 8RD 4.7 N-80 1.995 10,324' 10,825' 3.063" . }' v +, Q` 17 + !'o I SgzPerfs JEWELRY DETAIL MIR 8 p 8,033'- 8,034' No. Depth ID OD Item 1 23.0' - - Tubing Hanger, Shaffer CBL TOC 9 It 2 2,343' - - Gaslift Mandrel, Camco MM 9,840' 3 4,029' - - Gaslift Mandrel, Camco MM 4 5,333' - - Gaslift Mandrel, Camco MM 5 6,340' - - Gaslift Mandrel, Camco MM • 6 6,982' - - Gaslift Mandrel, Camco MM 7 7,484' - - Gaslift Mandrel, Camco MM 8 7,985' - - Gaslift Mandrel, Camco MM 9 8,304' - - Gaslift Mandrel, Camco MM 10 10,324' - - Crossover, 3 -1/2" IBT Box x 2 -3/8" EUE 8RD Pin 11 10,697' - - Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Closed 4/21/75 10 12 10,699' - - Packer, 5 -1/2" Baker FH 13 10,706' Otis `S' Nipple Position #2 14 10,707' - - Blast Joints, 3 jts, 3.062" OD TOL 15 10,768' - - CC Safety Joint, Brown 10,406' i< i 16 10,770' - - Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Open 2/6/78 CBL TOC 17 10,772' - - Packer, 5 -1/2" Baker FH 10,406' ,' 18 10,773' - - Fish, possible gaslift valve covered with asphaltenes 19 10,779' - Camco `D' 20 10,780' Blast Joints, Nipple 3 jts, 3.062" OD 21 10,825' - - Shear Out Sub, Baker 7 -5/8" 10,585' , PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 03/20/75 SgzPerf 8,033' 8,034' 1' 4 Squeezed 04/11/75 UH-8 10,720' 10,770' 50' 4 Open 11 I'.'' 04/11/75 11-1-8 10,782' 10,802' 20' 4 Open a i #' 04/09/75 H-9 10,808' 10,824' 16' 4 Open 04/05/7 5 H -10 10,856' 10,876' 20' 4 P&A 4/9/75 12 ll i IT 13 ` : 14 i _ UH -8 15 16 it LAU I 17 - ti -- - - _e � . 18 '':4 : LH -8 19 } tifti , I <. r 20 : ;r {4 j_ f' H -9 Retainer w/ cmt 21 7.7 1`' r�rr 10,044'40,850' �� �;� � h ti „� 5-1/2" _ :it i H - E tfr 10,964' TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44-04 Actual Well Schematic 10- 10- 91.doc Updated by STP 9 -14 -11 • • hevro 411, Swanson River Unit SCU 44 -04 Well SCU 44 -04 PROPOSED SCHEMATIC Updated 9/08/11 pletion RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB –THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 18" Conductor 104 B - Surf 77' - - Driven 18" ` L 10-%" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' 7 %" 33.7 P -110 6.765 Surf 78' 7 %" 26.4 N -80 6.969 78' 3,868' 2 F t 73/4" 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL ' 7'/," Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 -' /" 3 1 7' /s" 33.7 P -110 6.765 7,235' 7,927' all 7/" DV Collar 7,927' 7,929' 740 sx 5,075' CBL 10 -314" s 4 III= p 7/" 33.7 P -110 6.765 7,929' 10,585' 3,357' illIl 5 %" Liner 23 N -80 4.670 10,406' _ 11,031' 6-%" 130 sx 10,500' CBL 5 Tubing Cplg OD CBL TOC 3'/ : ", EUE 8RD 1 93 1 L -80 1 2.992 1 Surf 1 10,411' j - ' ( `: 5 7. 5,606' 6 i • a 7 o 1 8 1 BI I JEWELRY DETAIL S qz Perfs No. Depth ID OD Item 8,033' - 8,034' 9 , , 1 23.0' Tubing Hanger, Shaffer CBL TOC 10 Mr r 2 +/- 2,200' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 9,840' MEN1111111t 3 +/- 3,900' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 11 4 +/- 5,400' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL - 5 +/- 6,700' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 12 6 +/- 7,820' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL W 7 +/- 8,750' 2.867" 5.313" Gaslift Mandrel, GLMAX -1 .ORSL '``1 r ' 8 +1- 9,600' 2.867" 5.313" Gaslift Mandrel ' MAX- 1.ORSL 13 9 +/- 10,250' 2.867" 5.313" Gaslift Ma • el, GLMAX- 1.ORSL � 10 +/- 10,291' 2.992" 4.500" Chemi njection Sub li I 1 +/- 10,330' 3.250" 4.000" 10' , al Assembly (Bury 7' of seals) 14 12 +/- 10,338' 4.000" 5.250" r PBR 13 +/- 10,353' 4.000" 6.500" Permanent Packer, Premier 14 +/- 10,360' 2.992" 3.50 XO TOL 15 - 4 15 +/- 10,402' 2.813" 3 00" X- Profile(2.813" Min ID) 10,406' 16 +/- 10,411' 2.992" 4.500" Wireline Entry Guide CBL TOC 1 16 -.-- 1. 17 +/- 10,710' Cement Retainer (Squeeze 5 bbl below) 10,406' ` . 18 10,768' .0,- > CC Safety Joint, Brown 0 T 19 10,770' \ /v Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Open 2/6/78 20 10,772 V Packer, 5 -1/2" Baker FH Rotational Set 21 10,773 fl Fish, possible gaslift valve covered with asphaltenes 22 10,779' Camco `D' Nipple 23 10,780' Blast Joints, 3 jts, 3.062" OD 7-5/8" 4 • 24 10,825' Shear Out Sub, Baker 10,585' H -3 • H-4 H PERFORATION HISTORY .` Interval Accum. V' Date Zone Top Btm Amt spf Comments 9, 03/20/75 , SgzPerf 8,033' 8,034' 1' 4 Squeezed 17 !' - Proposed 14-3 +/- 10,586' +/- 10,602' 16' 6 2 -1/2" PJ Omega UH-8 Proposed H-4 +/- 10,622' +/- 10,631' 9' 6 2 -1/2" PJ Omega 18 / \ Proposed 14-5 +/- 10,656' +/- 10,691' 35' 6 2 -1/2" PJ Omega 19 04/11/75 UH -8 10,720' 10,770' 50' 4 Proposed P &A 2011 Ell 04/11/75 LH -8 10,782' 10,802' 20' 4 Proposed P &A2011 20 — 15, = 04/09/75 H -9 10,808' 10,824' 16' 4 Proposed P &A 2011 04/05/75 H -10 10,856' 10,876' 20' 4 P &A 4/9/75 • 21 •''..::,. _ LH -8 22 •-:•.74 23 Retainer w/ cmt 24 a_ ,�r ?'r' + ,;fqd H - °: {: {: 10,844' - 10,850' • L5S7n7:s }iti 't►:-- H -10 5-1/2" " +. s t. 10,964' _ ,.■ TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44 -04 Proposed Well Schematic 9- 26- 11.doc Updated by CVK 9 -26 -11 • • 1JTS SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager ri �j,. 0 Oat Union Oil Company of California "1 P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 44 -04 Sundry Number: 311 -304 Dear Mr. Brandenburg: 4 2.0 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, I� Danie - . Seamount, Jr. Chair DATED this day of October, 2011. Encl. 4 STATE OF ALASKA C i ALASKA OIL AND GAS CONSERVATION COMMISSION 1 , 3EP 2 9 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska ®il & Gas Crisis_ cp 8j,,, 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChangAi ppr tigcbProgram U Suspend ❑ Plug Perforations El - Perforate El - Pull Tubing El - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development - Exploratory ❑ 174 -066 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 133 - 20268 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Soldotna Creek Unit 44 -04 - 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028997 [ Soldotna Creek Unit] Swanson River Field/ Hemlock Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,031 • 10,853 10,773 10,617 10,844' 10,773' (Fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 18" 77' 77' Surface 3,357' 10 -3/4" 3,357' 3,356' 3,130 psi 1,580 psi Intermediate Production 10,585' 7 -5/8" 10,585' 10,439' 6,020 psi 3,400 psi Liner 625' 5 -1/2" 11,031' 10,853' 10,560 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,720- 10,770, 10,782- 10,567- 10,614, 10,625- 10,644, 3 -1/2" 9.2 #/ N -80 10,324 10,802, 10,808- 10,824 10,649- 10,664 2 -3/8" 4.7 #/ N -80 10,825 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): (2x) 5 -1/2" Baker FH and N/A (1) 10,699(MD)/ 10,547(TVD); (2) 10,772(MD)/ 10,616(TVD) and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/13/2011 Oil ISI - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: N/A Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Phone: 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature j��� Phone 276 -7600 Date 9/26/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 - pi ti Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3p00VSk C`Gt.•■.\ \30. A" r cc.c� \ - o s¢.{ v - .&'\ �c t "' it". k0 o � tirC5 c 94F Dt t\i4C.. a S % \\• ( ' Subsequent Form Required: L , 1 APPROVED BY Approved by: 7 � COMMISSIONER THE COMMISSION Date: /0/ 4 p ( ( Or F HBCMS OCT 04 ZO 1 R I[. t N \1 Form 10-403 Revised 1/2010 Su it in Duplicate � 3 ,, '16* • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 %. Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com September 26, 2011 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3572 Re: Soldotna Creek Unit 44 -04 PTD: 174 -066 Workover, Application for Sundry Approval Dear Commissioner, Enclosed is an Application for Sundry Approval (Form 10 -403) for the above referenced well. The outlined workover is to abandon existing intervals and access the Hemlock H -3, H -4, & H -5 sands, scheduled to start October 13 We would like to request a variance from requirements of 20AAC25.112(c)(1)(D) to allow - 7 plugging by the downsqueeze method by setting a cement retainer set +/ -10 feet above the existing top of open perforations and circulate out any excess cement if unable to pump the planned +/- 3bbl cement below retainer. If you have any questions pertaining to this variance, please contact Chris Kanyer 907 - 263 -7831. C. Timothy C. Brandenburg Drilling Manager / 01.' - d Enclosure yregli Cc: Well File /0 W4 r L� r a 1°1 (?,art t o (bl�t- 4 c ( �r e / L 7ON �� � f D i 0 ' t- f wP . vwGtt .A./ , JJ (a ". r 1 10 D f 01 , cli'l 411 r a > Ate o`'�� 'A-e p 'i or i 11N r I D 3 , N Ay o r ii 5 -Ole r Union Oil Company of California / A Chevron Company evro Swanson River Unit Well SCU 44 -04 SCU 44 -04 �� Actual Wellbore Schematic Updi Completed 0/10/91/15/75 RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB - THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 18" Conductor 104 B - Surf 77' - - Driven 18" , • 10 -'4" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' 7'/" 33.7 P -110 6.765 Surf 78' ' 7'/" 26.4 N -80 6.969 78' 3,868' . si 7 %" 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL ' 7s /" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9 -' /" = + 7'/" 33.7 P -110 6.765 7,235' 7,927' MIS ii . y 2 + 7 %" DV Collar 7 III ti 740 sx 5,075' CBL 10 -3/4" .i 7%" 33.7 P -110 6.765 7,929' 10,585' 3,357' 3 OM 11 5%" Liner 23 _ N -80 4.670 10,406' 11,031' 6-%" 130 sx 10,500' CBL I. Tubing Cplg OD CBL TOC 4 i 3 V. IBT 9.2 N -80 2.992 Surf 10,324 � : .'- 4.250" 5,606' 1" 5 f` x 2' /. ", EIIE 8RD 4.7 N -80 1.995 10,324' 10,825' •,, , a .4' 3.063" lr "`I 6 NM i I ' @)1". Q ! , 1 7 �'� a Sgzperfs JEWELRY DETAIL ` 8 8,033' - 8,034' No. Depth ID OD Item 11=1 1 23.0' Tubing Hanger, Shaffer CBL TOC * k " ` _ F '' 9 2 2 , 3 43' Gaslift Mandrel, Cameo MM 9,840' 3 4,' Gaslift Mandrel, Cameo MM yy •, ' 4 5,333 Gaslift Mandrel, Cameo MM ?? r 5 6,340' Gaslift Mandrel, Cameo • .t .> I .,: . ?' �t 6 6,982' - - Gaslift Mandrel, Cameo MM ' 8,304' 7 7,484' - Gaslift Mandrel, Camco MM Mandrel, Cameo MM w 8 7,985' Gaslift Mandrel, Cameo MM 9 - - s 10 10,324' Crossover, 3 -1/2" IBT Box MM x 2 -3/8" EUE 8RD Pin 11 10,697' Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Closed 4/21/75 l 12 10,699' - - Packer, 5 -1/2" Baker FH 10 i 44 13 10,706' - - Otis `S' Nipple Position #2 14 10,707' - Blast Joints, 3 jts, 3.062" OD TOL 'r't 15 10,768' - - CC Safety Joint, Brown 10,406' 16 10,770' Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Open 2/6/78 CBL TOC "' 1 10,7 72' Packer, 5 -1/2" Baker FH 10,406' 18 10,773' Fish, possible gaslift valve covered with asphaltenes , ., 19 10,779' Camco `D' Nipple 20 10,780' - - Blast Joints, 3 jts, 3.062" OD 21 10,825' - - Shear Out Sub, Baker 7 -5/8" 4. 10,585' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 03/20/75 SqzPerf 8,033' 8,034' 1' 4 Squeezed 04/11/75 UH-8 10,720' 10,770' 50' 4 Open g, 11 • t I 04/11/7 5 11-1 -8 10,782' 10,802' 20' 4 Open 1 1 I 04/09/7 5 H -9 10,808' 10,824' 16' 4 Open 12 , = 04/05/7 5 H -10 10,856' 10,876' 20' 4 P&A 4/9/75 13 4 . 6,, 4 - 14 I 1 UH -8 "'4 15 16'tt ' I i I ` I I 17*':- _ _ _� 18 f LH -8 qa 4 19 filtt t? 1:04. ; 20 :4:i, . :Zs Retainer w/ cmt 21 iiiiii H -9 t r r J_g' 10,844' - 10,850' ti t " e , ;" I3-10 5 -1/2" t s R ` + 10,964' ' f TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44 - 04 Actual Well Schematic 10- 10- 91.doc Updated by STP 9 -14 -11 • ' r evro Swanson River Unit SCU 44 -04 Well SCU 44 -04 "4""......00".° PROPOSED SCHEMATIC Proposed Completion Updated 9/08/11 RKB: 150.8' / GL: 133.8' AMSL Casing & Tubing KB — THF: 23.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 4.4 1 18" Conductor 104 B Surf 77' Driven 18" 10 -' /<" Surf Csg 40.5 K -55 11.250 Surf 3,357' 15" 1950 sx Surf. 77' +w,,' 7%" 33.7 P -110 6.765 Surf 78' 7% 26.4 N -80 6.969 78' 3,868' .. 2 SIM 11 7 %" 29.7 N -80 6.875 3,868' 5,759' 1200 sx 5,075' CBL '-` y 11111 7%" Prod Csg 33.7 S -90 6.765 5,759' 7,235' 9-%" ',, °+ 3 111=II it 7'/" 33.7 P -110 6.765 7,235' 7,927' i 41111 7 %" DV Collar 7,927' 7,929' 4 tom• P 7 %" 33.7 P -110 6.765 7,929' 10,585' 740 sx 5,075' CBL 3,357' 11111 51/2" Liner 23 N -80 4.670 10,406' 11,031' 6 - %" 130 sx 10,500' CBL 5 1 11 Tubing C ∎ 1 ' OD CBL TOC al 3' ", EUE 8RD 1 9.3 1 L -80 1 2.992 1 Surf 1 10,411' ^F" 5,606' rn 1 6 11 * "•14 ,---- 7 IMF li +� .;11 8 a + JEWELRY DETAIL ''.. 8,033'- 8 033 Pe,0303 4' No. Depth ID OD Item 9 � 11 1 23.0' Tubing Hanger, Shaffer CBL TOC ` 10 � = 2 +1-2,200' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL 9,840' ''; �' ; 3 +/- 3,900' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL t 11 *11 4 +/- 5,400' 2.867" 5.313" Gaslift Mandrel, GLMAX -LORSL d 5 +/- 6,700' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL R "* 12 ..1' 6 +/- 7,820' 2.867" 5.313" Gaslift Mandrel, GLMAX - I.ORSL '• "• 7 +/- 8,750' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.ORSL it 8 +/- 9,600' 2.867" 5.313" Gaslift Mandrel, GLMAX- 1.ORSL ICI (Al 2 :* a ..: 9 +/- 10,250' 2.867" 5.313" Gaslift Mandrel, GLMAX-1.ORSL 13 -' L- 1 10 +/- 10,291' 2.992" 4.500" Chemical Injection Sub V J k 11 +/- 10,330' 3.250" 4.000" 10' Seal Assembly (Bury 7' of seals) 14 ' 12 +/- 10,338' 4.000" 5.250" 10' PBR t 1 13 +1- 10,353' 4.000" 6.500" Permanent Packer, Premier �' 14 +/- 10,360' 2.992" 3.500" XO N TOL 15 15 +/- 10,402' 2.813" 3.500" X- Profile (2.813" Min ID) 10,406' 16 +/- 10,411' 2.992" 4.500" Wireline Entry Guide i 16 s = ; 4 17 +/- 10,710' - Cement Retainer (Squeeze 5 bbl below) CBL TOC 1-, 10,406' 18 10,768' CC Safety Joint, Brown ' ' . 19 10,770' Sliding Sleeve, (1.997" I.D.), Otis XA (Opens Up) Open 2/6/78 20 10,772' Packer, 5 -1/2" Baker FH Rotational Set 21 10,773' Fish, possible gaslift valve covered with asphaltenes 22 10,779' Cameo `D' Nipple 23 10,780' Blast Joints, 3 jts, 3.062" OD 7 -5/8" 24 10,825' Shear Out Sub, Baker 10,585' 11 -3 11 -4 115 PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 17 ' ► ■ -� 03/20/75 SgzPerf 8,033' 8,034' 1' 4 Squeezed Proposed H -3 +/- 10,586' +/- 10,602' 16' 6 2 -1/2" PJ Omega 1 11-8 Proposed H -4 +/- 10,622' +/- 10,631' 9' 6 2 -1/2" PJ Omega 18 Proposed 11-5 +/- 10,656' +/- 10,691' 35' 6 2 -1/2" PJ Omega 19 04/11/75 UH -8 10,720' 10,770' 50' 4 Proposed P &A2011 04/11/75 LH -8 10,782' 10,802' 20' 4 Proposed P &A 2011 20 _ 1 - - ! . l r 04/09/75 H -9 10,808' 10,824' 16' 4 Proposed P &A 2011 21 04/05/75 11-10 10,856' 10,876' 20' 4 P &A 49/75 • •' c. ▪ t - LI1 - 8 . 22 tfti .' I 'I. . 23 V. Retainer w/ cmt ' 24 ?. ▪ - 11 9 f 5i. : :r f : . 10,844' - 10,850' 1y; } }y };,1;; } }! ,►_- H -10 5 -1/2" t,. ` 10,964' ' 4I ' y TD = 11,031' PBTD = 11,005' MAX HOLE ANGLE = 26.25° @ 11,031' SCU 44 -04 Proposed Well Schematic 9- 26- 11.doc Updated by CVK 9 -26 -11 Chevron • . Swanson River 1%. SCU 44 -04 %N. 9/26/2011 OBJECTIVE: Pull existing completion, abandon existing perfs, replace tubing head, run new completion, thru- tubing wireline perforate Hemlock H -3, H -4, & H -5 sands. Current BHP: 2,680 psi @ 10,633' TVD Max Downhole Pressure: 2,680 psi © 10,633' TVD (Based on SITP = 0 psi, fluid level at 4,451' and a produced water gradient) MASP: 0 psi (Based on actual reservoir conditions and water cut of 98% (0.438psi /ft) with added Safety Factor of 1000' TVD of oil cap) PROCEDURE SUMMARY: 1 MIRU Key Energy Rig # 3. 2 ND tree, NU BOPE & test same 250psi low/ 3,000psi high, test annular to 250psi low/ 1,500psi high. 3 Pump + /- 8.4ppg lease water down tubing and annulus. 4 RU Eline. 5 RIH and punch tubing at +/- 10,682' to +/- 10,688'. 6 RIH and cut the 2 -3/8" tubing at +/- 10,677'. 7 Pull 3 -1/2" & 2 -3/8" production tubing from +/- 10,677'. 8 RIH and fish upper FH packer at 10,699' and 2 -3/8" tubing down to CC safety joint at 10,768'. 9 RIH and set 5 -1/2" cement retainer at +/- 10,710'. Tag cement retainer w/ 10k to confirm set. 10 Unstab from retainer and circulate well with +/- 8.4ppg lease water. 11 Perform charted pressure test casing to 1,500psi. 12 Stab into retainer, perform injectivity test with +/- 8.4ppg lease water. 13 Attempt to pump +/- 3 bbl of +/- 15.3 ppg cement below retainer Contingency: Circulate out any excess cement, if unable to pump +/- 3 bbl cement below retainer. 14 RIH w/ 5 -1/2" x 7 -5/8" casing cleanout BHA to +/- 10,710'. 15 Displace well to +/- 8.6ppg 6% KCI. 16 Pull up hole to +/- 9,000'. PUMU 7 -5/8" RTTS packer, RIH and set at +/- 60'.Release and POOH. 17 ND BOPE. ND tubing head. 18 NU new tubing head and test voids to 250psi low/ 3,500psi high. 19 NU BOPE & shell test same 250psi low/ 3,000psi high. RIH w/ retrieving tool, latch & release RTTS packer at +/- 60', POOH & LD RTTS packer, and continue to POOH w/ 20 5 -1/2" x 7 -5/8" tandem scraper assembly. 21 RIH 7 -5/8" Premier packer, seal assembly, and 3 -1/2" gaslift completion to +/- 10,411', and set packer at +/- 10,353'. 22 ND BOPE. NU and test tree. 250psi Low/ 5,000psi High. 23 RU Eline. Pressure test lubricator 250psi low/ 2,500psi high. 24 RIH and perforate the Hemlock H -3, H -4, & H -5 sands at +/- 10,586' to +/- 10,602', +/- 10,622' to 10,631', +/- 10,656' to +/- 10,691'. 25 RD Eline. 26 Turn well over to production. SCU 44 -04 CVK 9/26/2011 • 'Chevron Swanson — River . SCU 44 -04 08/23/2011 1 . K ey Stripper head assy 1.77' iiiinimriii ii iii iii di isi 0 0 111 11i iii iii Ili iii III ii 3.45' Shaffer 11" 5000 lit lil lit lil lil Shaffer LWS 11" i°i`r - Blind rams _1 - — 2.75' _ = 13.80' 2 7/8 X 5 Variable ra — _ -i _ — ,. �' 0— .0..• i ! f a . ) i ii j i .. ; wig! I!I ili I/l iv , t i ' i ill: 2.00' :M:. - - ' a 14 i 1 1 I , I . Ill 111 111 111 111 � , Choke and Kill lines 2 1/16 5M w/ unibolt connections W111111111 III Crossover spool 13 5/8 5M FE X 11 5M FE UOCD # 2.83' 1246 1i, iii ill limb 0 0 Crossover spool 1.00 13 5/8 5M FE X 9 5M I I 'flip um 1c 1214 Ground level m iii �1' i � ;I ; ii i �i �o obi ��� ■I��� ®' �i ���li.j„ �i� 1 lid in l_ti _ o___._., Chevron Swansoftiiver 2011 Choke Manifold 07/07/2011 Blooey Line To Gas Buster orom alma or ,.1 i.i �.I o i.i ilmmuli 4 ^` 0 O F` E�,Or�4O l 0 /4o p 0 0 IV :I lir ; • ^�, 1r- ^ 0 -\ 0 "�� 0 P V 0'e � > 0 0 , 0 J 0 0 O 0 N I II it !,r .. :,o / � o IiiiMi \/J00 111 0 0 0 ,� 0 0 0 s I� o c X10 Ile4 ° ►� °, �h 0 • 0 [ o� o �; ([o 101' I. ' 0 f o r = _�o _f 0 f - - `� _ mss' II II MI sa_emoss• MI Super Choke III Q w All valves 2 1/16 5M on lel ■ i., manifold 0 j' Unibolt Connection 0; 0 - /.Nor, . August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, -1 44- o Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com ,f AUG 0 o 2009 in s V, F_ rit & r,-, e: Trans: CPi-nm. can Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, 1 J Ct,,.. Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platfonn life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platforrn life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform I ife K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 i parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct4 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of pl form life AILASSA 011L A" GAS CONSERVATION COMUSSION June 22, 2009 SARAH PALIN, GOVERNOR 1 r 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCONE10 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.auberi(aalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 _ Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD Union Oil Company of California 176-032 _ Trading Bay Unit G-24 _ Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 _ Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 _ MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 _ Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 _ Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 _ Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 _ Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 _ Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 ARCO Alaska, i Post OffiCe Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures December 2, 1987 Mr. C. V. Chatterton Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are two Applications for Sundry Approval to perforate the robing in Wells SCU 12A-4 and Well SCU 44-4. The lower zone of Well 44-4 cannot be opened to production without perforating the robing due to sand fill and a solid obstruction at 10,812'. The obstruction at 10,812' is impassible with a coiled robing unit. It is proposed that the robing be perforated at 10,778' with five feet of 1SPF, 1-11/16" perforating guns. The upper zone in Well 12A-4 is isolated behind robing. It is proposed that the tubing in this well be perforated at 10,575' with five feet of 1SPF, 1-11/16" hollow carrier perforating guns. By perforating the robing in this well we will be able to test a zone that has been shut-in for 13 years. With your approval, we would like to expedite this work within the next several days. If you have any questions, please contact Tom Wellman at 263-4304. D. S. Joiner DSJ:JWR:ch:0003 Attachments CC: J. A. Dygas U. S. Bureau of Land Management (For Information Only) R C IYED ,':~, nchora,qo ARCO Alaska. inc. ~s a Subsid*ary ot AtlanticRichfieiclCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ,,~ Amend order ,~, Perforate ]~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 105.8' KB feet 3. Address 6. UnitorProperty name Post Office Box 100360 Anchorage, Alaska 99510 Swanson River Unit 4. Location of wellatsurface 579' North & 620' East of Southwest Corner of Sec. , 7. Well number SCU 44-4 T7N, R9W, SB&M At total depth 455' North & 1,158' West of S.L. 8. Permit number 9. APl number 50-- 133-20268-00 10. Pool Swanson River - Hem lock 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented See Attached Schematic Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth True Vertical depth 12.Attachments Well Schematic Description summary of proposal ~ Detailed operations program :~ BOP sketch 13. Estimated date for commencing operation 12/$/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to'the best of my knowledge Signed ~ (,,¢-¢/_,~.~ ~ ~5c~o¢~,-,~, TitleMgr., Cook In let Engineer lng Commission Use Only Date /z/~/~/ Conditions of approval Notify commission so representative may witness Approval No. . ~ Plug integrity ~ BOP Test ~,' Location clearance Approved by ORI~I~. SIGNED BY LOi~t~[INtE C. SMITH Approved Copy Returned Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate,,,L~ Z 3357 · · h~02~'-~OT ,,~.CO I~'.I',AI~REL, ':""t~i*"52~"~ ,.;Xl, qCO I,i,q ,,A.~DR~ . 6'33:~'6'JT ~L~:CO !~ F~tiDREL 16 J~. ~' £~ b~ 9.3f I~iX) BU?R~L~ lO40&* ].0,6~6.~' 101'~0' 1.3: 371.3:: ]..~. ./ : :' .,3 u~? a~. (~c.33,) .,1.~- OD (~.~ U~ ~ ,,0,,~..~. ',7~.x~, .... a" ~,.*~"~' _. x.~ !/ :,,,o,: . .... _ . i I !~~~ ~or~. ~ ~~b~~d ~. s~, ~ , ',~.u. u'o3x I SECTION ~.~,a.gw. Form 3160--~ 5 {November 1983) (Formerly 9--331) :41TED STATES sus,,zT ia~ mcArn- (Oilier luetru,, ~s on t,'tk DEPARTME'NT OF THE INTERIOR ,er...~do) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS' ON WELLS (Do not tt~ this form for proposals to drill or to de~P% or plug back to a dlfEerelt r~s~rvolr. Use. "APPLICATION FOR PERMIT--" for such propomML) Form approved. Budget Bureau No. 1004-0135 Expires. August 31, 1985 §. LIAII DIIIONAYION AND Ill*iL A-028997 7. UNIT AOSBBMEMT NAiaI 1. So ldotna Creek 2. NAME OF OP~IATOI ARCO Alaska, Inc. So ldotna Creek 9. wm~ NO. 3. ADDUlB OF OPSRATOI Post Office Box 100360 Anchorage, Alaska 99510 SCU 44-4 10. FIELD AND POOL, OR WILDCAT Swanson River-Hemlock 4. LOCATION SIP WELL (Report location clearly and in accordance with any State requi~e;---entm.° Scs also space 17 below.) At surface SL: 579' North & 620' East of SouthWest corner of Sec. 3; T7N, R9W, Seward B&M. BHL: 455' North & 1,158' West of surface location 14. PERMIT NO. 15. EL~VA~ONS (Show whether DF, rr, oR, ets.) 105.8' KB II. 8B~., ~ L, M., OB BLE. AMD 8UIVBY OB ABJIA Sec. 4, TTN, Rgw, SB&M 12. COUiIT! OU PilIIH[ 18. I'Z'A'Zl Kenai I Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTI(~I OF INTENTION TO: IUBIBQUBIPF I,BFOI~ ~: TEST WATRI SHUT-OFF [ [ P~LL OS ALTER CASING FRACTURE TREAT M U LTIPLR COM PI.RTE SHOOT OB ACZDL~B ABANDONS REPAIR WELL CHANG~ PLANS (Other) WATSl SHUTOFF ~ FRACTURE TIBATMENT . SHOOTING OB ACIDI$INO (Other) III*AilING WILL AlAN DON M BM~o (NOTE: Report reeulm of multiple eompl_etion on Well Completion or Reeompletion Report and Lo4r form.) l)E$('RltlE I'ROPOSED OR CO~IPLETED OPERATION-~' (Clearly state all pertlne,t details, and give pertinent dates, lneludlnf ~ttmated date of starting an~ proposed work. If well is dir~ctionally drilled, give stxba~r~p, ce loc~tions and measttred and true vertical depths for all markers all Sone~ peril- neat to this work.) ARCO Alaska, Inc. requests permission to perforate the 2-3/8" tubing tail below the "D" nipple at 10,778' KB in Well SCU 44-4 with five feet of 1SPF, 1-11/16" Hollow Carrier, through tubing perforating guns. Well SCU 44-4 currently has 31 feet of sand in the tubing between the "D" nipple and the tubing tail. A CTU clean- out was attempted on 9/20/87 but an obstruction exists at 10,812' that prevented a successful cleanout of the tubing. Perforating the tubing will allow us to evaluate the potential of the lower sand in this well and possibly return it to production. RECEIVED NOV 5 ]987 Alaska 0il & Gas Cons. Commission Anchorage 18. [ hereby certify that the foregoing is true and correct TITLE (This space for Federal or State o~ce use) APPROVED BY CONDITIOBI8 OF APPROVAL, IF ANY: TITLE DAT~ *See Indmctions on Reverse Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States an}' false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering ADDRESS' LOG TRANSMITTAL FROM: DATE: WELL: Please find the following logs enclosed: Log Blue Line *** Sepia *** Folded Rolled Mylar Tape ARCO Alaska, Inc. ~ ATTN: Judy Boegler AT0-579 Post Office Box 100360 Anc.horage, AK 99510 Recei pt Acknowledgment: Return Receipt to: TRANSMITTAL AN~'\CKNOWLEDGEMENT OF RECEIPT OF ~i~"~RIAL - (ALASKA) PLACE:_ ~, ~_.,). ~o.--. _ FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" 5" I I I00 ~00 COMPLETION REPORT - NEW WELL STANDARD 0IL COMPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS 'AREA: Swanson River Field ..... . LAND OFFICE: Anchorage' 2 . Kenai Peninsula Alaska PROPERTY: Soldotna Creek Unit.. LEASE NO: A-0289.97 " WELL NO: SCU 44-4 . API NO: 50-133-20268 LOCATION AT SURFACE: 579' North and 620' East from Southwest corner of ' Section 3; T7N, R9W, Seward B & M. LOCATION AT DEPTH: ELEVATION: 455' North and 1,~158, West from surface. · DATE: BY: - ~. . ,' R.M. McKinley .'~' ~ ' Area En~ineer- . DRILLED: BY: Kenai: Dril. ling of ~laska. Rig' #2- ..: DATE COMMENCED DRILLING: 3:00 AM,. J .a~'uary 11, 1975 ..~..... f, ~.. ' DATE COMPLETED : 3: 00 AM,. ~ril 15, 1975 D~I'E OF INITIAL PRODUCTION: April 18, 1975 · · ;;;..'_ ""TOTAL DEPTH: 11,031'. "~"'/-"PLUGS: 11,031'-10,844' ..... EZ DRILL at 10,850' EFFECTIVE DEPTH: 10,844 ' - . .... ..,..- ' : " .. ':. - ,.. i-:'.'.'_ ~-.'/;,:..',' · "" CASING: 18" 104# B driven to 77' · .~.' .... : ..... " ' . . . · · . . .... ' LIIiER: . ,. 10 3/4" 40.5# K55 cemented at 3,357.' With 1,950 sacks "G" cement '~' 5/8" cemented at 1.0,585' -. · .. · 625' of 23# N-80, 5 1/2" cemont at.il,031' top at 10',406'. . · ,,. - . . ~ :, -.- , , - '.~. ~ . ...:.:· . ,. . . DIVISION oF OIL AND Gt$ Perforations Cemented off: 10,876'-10,866' 10,866'-10,856' With four .39" jet holes per foot: 10,824'-10,817' 10,802'-10,782' 10,770'-10,720' CP'd at 8,033' Schlumberger Dual Induction LateroLog Borehole Sonic Log Formation Density Comp. Neutron For~. Density Saraband Cement Bond Log Go-International Cement Bond Log Dresser Atlas Acoustic Cement Bond 3,357'-11,021' 10,590'-11,021' 3,357'-11,021' 3,357'-11,021' 10,600'-11,000' 7,790'-10,521' 3,310'-10,529' 9~740'-10,994' 9,740'-10,994' 2"-5" 2"-5" 5" 5" 5" 5" 5" (2 runs) (1 run) (2 runs) (2 runs) (1 run) (1 run) (1 run) Initial Production . - , Method: Oil b/d: Gas mcf/d: Water b/d: GOR cf/b: flowing April 18, 1975 2,020 925 8 457 January 11, 1975 Commenced operations at 3: 00 AM. i-Drilled 15" hole 77'-137' ~Viscosity 150. January 12, 1975 -Drilled 15" hole 137'-1,036' (60') 75 pcf mud (899') 85 pcf mud · January '13, '1975 Drilled 15" hole 1,03'6' 1,664 ' January '14, ' 1975 Drilled 15" hoie 1,664 '-3,017 ' ' Jan%~/"f '15, 1975 Drilled 15" hole 3,017-3,370 ' ~eamed 1,823-1,940' .. Circulated and conditioned mud. (628') 79 pcf mud (1,353') (353') 77 pcf mud Jan.uary 16, 1975 Ran 10 3/4" casing. Fish in holeo Pulled 10 3/4" casing and found fish. Spot reamed 2,028'-2,163'. 78 pcf mud January 17 & 18, 1975 Spot reamed 2,163'-3,370'. Made wiper run and circulated and conditioned mud. Ran 3,362' of 10 3/4" 40.5# K Buttress casing. Float collar at 3,316'. Cemented 10 3/4" casing at 3,357'. Preceded cement with 150 cu. ft. Water, cemented with 2,360 cu. ft. slurry and 300 sacks neat cement, displaced cement with 30 cu. ft. Water and 235 cu. ft. mud. Good circulation and cement returns to the surface. Cut 20.50' off i8" and 10 3/4" casing and installed SOW Cameron head and tested to 2,500 psi, ok. ~anuary 19, 1975 Installed class III 10" 5,000 psi BOPE and tested BOPE to 5,000 psi on kill and choke lines and 2,500 psi on stack, ok. '~ January 20, 1975 Made up 9 7/8" drilling set up. 74 pcf mud ~anuary 21, 1975 Drilled out float collar at 3,316' to shoe at 3,357'. Drilled 9 7/8" hole 3,370'-3,427' (57'~) 78 pcf mud January 22, 1975 Drilled 9 7/8" hole 3,427'-4,033' January 23, 1975 (606') 80 pcf mud Drilled 9 7/8" hole 4~033 '-4,352 ' (319') 83 pcf mud January 24, 1975 Set cement retainer at 2,114'. Cemented plug in 10 3/4" casing through drill pipe hung at 2,114'. Used 100 sacks of neat cement, preceded with 50 cu.ft. Water and displaced with 9 cu. ft. Water and 143 cu. ft. mud. Good circulation. Pulled to 1,900' and backscuttled. Tested casing to 2,000 psi, ok. Found leak in Hydril Bag. Jan~a.ry..25,.1975 Cleaned out cement from 1,935'-2,114'. Drilled out bridge plug at 2,114' and slip to 4,302'. Reamed from 4,302'-4,342'. Reamed and cleaned out bridge plug junk from 4,342'-4,352'. 80 pcf mud -January 26, 1975 Drilled 9 7/8" hole 4,352'-4,767' 'January'27, 1975 Drilled 9 7/8" hole 4,767'-5,230' (415') 79 pcf mud (463') 79 pcf mud January .2.8,...1.9'7.5.. Drilled 9 7/8" hole 5,230'-5,855' Januar~ 29, 1975 Drilled 9 7/8" hole 5,855 '-6,206 ' '.J ~anua.r~. 30.: 1975 Drilled 9 7/8" hole 6,206'-6,382' january 31, '1975 Drilled 9 7/8 ''~ hole 6,382'-6,624 ' '.FebruarY '1~ '1975 Drilled 9 7/8" hole 6,624 '-6,745 ' ; 'February '2, '1975 Drilled 9 7/8" hole 6,745'-6,857 .February. 3, 1975 Drilled 9 7/8" hole 6,857'-7,082' February 4, 1975 Drilled 9 7/8" hole 7,082'-7,239' .F..ebruarY 5, 1975 Drilled 9 7/8" hole 7,239'-7,473' (625 ' ) (351') (176') (242 ' ) (121 ' ) (112 ' ) (225 ' ) (157 ' ) (2 34 ' ) 81 pcf mud 83 pcf mud 91 pcf mud 93 pcf mud 92 pcf mud 93 pcf mud 93 pcf mud 93 pcf mud 92 pcf mud _February 6, 1975. Drilled 9 7/8" hole 7,473'-7,592' FebruarY'7, 1975 Drilled 9 7/8" hole 7,592'-7,780' (119') _ _ (188 ' ) '? 94 pcf mud 94 pcf mud -February 8,-1975 Drilled 9 7/8" hole 7,780'-7,945' February ' 9, 1975 Drilled 9 7/8" hole 7,945'-8,029' 'February ~ 10; -1975 Dyna-drilled 9 7/8" hole 8,029'-8,060 .. (165') (84 ' ) (31 '.) 94 pcf mud 94 pcf mud 93 pcf mud -'Februa.ry'll,'1975 Drilled 9 7/8" hole 8,060'-8,188' (128') 92.5 pcf mud ''February 12, 1975 Drilled 9 7/8" hole 8,188'-8,207' February '13 ~ 1975 Oriented dyna-drill Dyna-drilled 9 7/8" hole 8,207'-8,246' (19') (39') 93 pcf mud 95 pcf mud · 'February'.14~'1975 Drilled 9 7/8" hole 8,246'-8,383' (137 ' ) 95 pcf mud ~Februa~y_ 15, 1975 Drilled 9 7/8" hole 8,383'-8,430' .FebruarY '16, '1975 Drilled 9 7/8" hole 8,430'-8,517' (47 ' ) _ . (87') '? 93 pcf mud 93 pcf mud February'17,-1975 Drilled 9 7/8" hole 8,517'-8,589' February..'18;'1975 Drilled 9 7/8" hole 8,589'-8,807' (72') (218') 93 pcf mud 93 pcf mud February~19, 1975 Drilled 9 7/8" hole 8,807'-9,010' (203') 93 pcf mud ''February 20,'1975 Drilled 9 7/8" hole 9,010'-9,115' - took drilling break approximately 2:20 PM on 2/20/75. Depth 9,115'. Gas surfaced. Started degaser. Mud weight cut at flow line from 93 lbs. to 81 lbs. Started 7 marker. Mixing mud to control entry. Mud weight at suction 95-96 lbs. Completion indicates Water intrusion with Gas. Volume increase approximately 5 barrels perhour. Mud check indicates chloride increase from 300-500 ppm. Viscosity 48-35 indicates Water. Additional gels started immediately. Drilling at no time interrupted. Weight material added for 2 circulations before flow line weight increase added. Bar added as rapidly as possible. Barely possible to maintain system. 95-96 in and 85-84 out. Entry offsetting bar additions. Calculations indicate total gain from 3 - i1 PM approximately 70 barrels ±. 8040 sacks of bar mixed by midnight which would increase volume by 56 barrels. Total increase of 125 barrels by midnight. Total system contains 1000 barrels. Response to weight up were not noted until 3rd circulation at 11:30 PM. Entry under control 8:30 AM. Flow line weight 96. Mark set on pit at this time. Monitored until 5:30 AM. No increase. (Bill Hubbard, IMCO SERVICES). Drilled ahead to 9,238'. 93-96 pcf mud F~bruary 21, 1975 Drilled 9 7/8" hole 9,238'-9,302' (64') 97 pCf mud _February 22,1975 Drilled 9 7/8" hole 9,302 '-9,435 ' (133') February 23, 1975 Drilled 9 7/8" hole 9,435'-9,537' (102') ': 97 pcf mud 99 pcf mud 'Februar~_''24~ 1975 Drilled 9 7/8" hole 9,537'-9,658' (121') 97 pcf mud 'February ' 25; '1975 Drilled 9 7/8'" hole 9,658 ~-9,863 ' (205') .' 97 pcf mud · February 26, 1975 Well started to flow. Ran to bottom and circulated. Had 140 bbls. of 86 pcf Water cut mud then got 92 pcf. Added bar to stop flow. .. Drilled 9 7/8" hole 9,863'-9,980' ~(117') 98 pcf mud February '27, 1975 Drilled 9 .7/8" hole 9,980'-10,020' (40') Started pulling out of hole and well began to flow. Ran to bottom and circulated out 15 bbls. of 94 pcf Water cut mud. Circulated and increased mud weight· 102 pcf mud ' 'February '28, 1975 Hole took 275 bbls mud at 3,300' Circulated and conditioned mud at 3,038' · · , 3,984' and partial circulation and 4,457'· Pulled to 3,984' and had partial circulation. Pulled to 3,228' and added 450 bbls. lost circulation material. Lost 125 bbls. mud so have total loss of 400 bbls. 94 pcf mud 'Marc~l,'1975 Mixed 625 bbls. of 95 pcf mud wi~ mica, nut plug and fiber. Circulated bottoms up at 3,700', 4,167~ , 4,645' , and 5,117'. Increased mud weight to 99 pcf to hold salt water. Lost circulation. 95 pcf mud Ma_rch. 2, 1975 Pulled to 3,228' added 215 bbls. but got no returns. Filled hole with 70 bbls. of 95 pcf mud but hole would not stand full. Mixed 200 bbTs. of 95 pcf mud i with mica, nut plug and fiber. Filled hole at 3,228' got full circulation. Went to 3,700' got full c~rculation and did also at 4,167' and 4,268' 95 pcf mud 'March' 3~ '1975 Circulated at 4,746' adding mud with lost circulation material. Lost 5 bbls. at 5,207'. A~ded lost circulation material. Lost 12 bbls. 95 pcf mud at 5,674'. Lost circulation so pulled to shoe at 3,357'. Mixed 450 bbls. of 95 pcf new mu~ with lost circulation material. 95 pcf mud _March 4, 1975 Mixed 200 bbls. of new 95 pcf mud with lost circulation material. Filled hole with 14 bbls Ran in slowly circulating at 3,357' 3 700' 4 165' 4,645', 5,117';, 5,589', and 7,656' no loss. Circulated and conditioned mud.. 97-95 pcf mud March 5, 1975 Continued to run in hole one stand at a time and circulate to 10,020'. Had no loss. Drilled 9 7/8'" hole, 10,020'-10,027'. Had trouble with sticking so pu/led out of hole and well started flowing at 6,341'. 95 pcf mud March '6, ' 1975 Well flowed 11 bbls/hour. Shut well in. Changed bean. Well dead. 98 pcf mud March 7, 1975 Reamed 8,540'-8,720, 8,772'-8,912, 8,953'-9,052, and 9,547'-9,567' Drilled 10,027'-10,035' (8') 98 pcf mud March 8, 1975 Drilled 9 7/8' hole 10,035'-10,176 ~March 9~ 1975 Reamed from 10,146'-10,176' :Drilled ;10,176'-10,312' (141'.) .~ 99 pcf mud (136') 99 pcf mud '1975 Drilled 9 7/8" hole 10,312 '-10,464 ' (152') 99 pcf mud · March '11; 1975 Drilled 9 7/8" hole 10,464'-10,579' '-March'12,'1975 (115') 99.5 pcf mud Drilled 9 7/8"-hole 10,579'-10,604' (25') Schlumberger ran Dual Induction La~rolog from 10,604'-3,357'. 99.5 pcf mud Circulated and conditioned mud to run casing · March 14, '1975 99 pcf mud Ran 7 5/8" casing as follows: Top 83.26' of 33.?# P-110 Buttress 3789.96' of 26.4# N-80 Buttress 1890.74" of 29.7# N-80 Buttress '~ 1476.24' of 33.79 S-90 Buttress 692.08' of 33.7# P-110 Buttress ..... 1..9 .' of Baker Stage Collar · 2656.28' of 33.7# P-110 Buttress with shoe and float 10590.46' · '- ' 5.46' above table _ · _ 10585.00' (con' t next page) March 14~ 1975 (con't) Cemented around shoe of 7 5/8" casing to 10,585' with 640 sacks of "G" cement mixed with 2.1% gel by weight of water. Followed with 100 sacks of neat cement. Displaced with 2,695 cu. ft. mud. Good circulation. Opened stage collar at 7,926' andlpressured up to 1,500 psi and could not circulate. ''March 15,'1975 Located Baker opening plug at 6,900' but unable to work plug lower. Raised B.O.P. stack cut 7 5/8" casing and installed tubing head, tested to 5,000 psi. March 16, 1975 Reinstalled BOPE and tested. 'March 17, 1975 Ran lead impression block to 6,871', indicates top of stage collar plug. Washed over from 6,881' to 6,888' and slid to 6,893'. 99 pcf mud ~ 'March ~18, 1975 Recovered 7 5/8" casing wiper plug and stage collar trip plug. Drilled out cement from 6,890'-7,021' with 6 5/8" bit. Drilled out cement from 7~021-7,435'. 150 psi annulus pressure. 99 pcf mud March 19; 1975 Drilled cement with 6 5/8" bit. 7,435'-7,980'. With 4 1/2" bit, drilled through stage collar. Attempted to open stage collar but failed. Casing held 1,500 psi, ok. March 20, 1975 Drilled on cement with 6 5/8" bit to 7,993' and pressure tested casing to 1,500 psi, ok.. 99 pcf mud Drilled 6 5/8" hole 7,993'-8,053'. (60') Set cementing tool at 7,835'° Shot four 1/2" jet holes at 8,033'. Pumped 526 bbls. of 99 pcf mud through perforations and up the 10 3/4", ? 5/8" annulus. March 21, 19.75 Circulated and conditioned mud through perforations. Pulled cement tool. Set retainer at 7,959'. Cemented through perforations with 1,620 cu.ft. cement gel slurry, followed by 150 sacks neat cement and displaced with 30 cu.ft, water and 300 cu. ft. mud. Pulled out of retainer and reversed out 6 cu.ft, cement. 99 pcf mud March 22, 1975 Located cement retainer at 7,957' and milled out retainer from 7,957'- 7,959' and drilled out cement with 6 1/2" bit from 7,959'-7,988'. 99 pcf mud March 23, 1975 Drilled cement 7,988'-8,123'. Had fluid entry. Raised mud weight from 92 to 98 pcf. Tested holes at 8,033' and they broke down under 1,900 psi. Raised mud weight to 99 pcf and viscosity to 45 sec. 7 5/8", 9 7/8" annulus dead. Set Retriev-o-Matic cement retainer at 7,835'. Squeezed 150 sacks cement, preceded with 50 cu. ft. Water, to a final pressure of 2,800 psi. 99 pc f mud 'March'24~'1975 Set cement tool at 7,774' to resqueeze holes at 8,033'. Obtained breakdown ~nder 3,750 psi with 12 cu.ft./minute. Squeezed 100 sacks cement, preceded with 50 cu.ft. Water, to a final pressure of 7,000 psi and heldo30 minutes ok. Located cement at 7,809'. Cleaned out cement with 6 5/8" bit from 7,809'-7,962'. 99 pcf mud o- March 25, 1975 Cleaned out cement 7,962'-9,053'. 99 pcf mud 'March 26, '1975 Drilled cement 9,053'-9,235'. Pressure tested casing and holes at 8,033'. Held 2,500 psi for 15 minutes ok. Drilled cement 9,235'-10,540'. 99 pcf mud March 27, 1975 'Circulated and conditioned mud for logging. Ran Schlumberger Cement Bond i Log 3,310~-10,529'. Drilled cement 10,540'-10,604'. Drilled 6 5/8" hole !10,604'-10,617'. ~ 99 pcf mud '!March 28, 1975 : Drilled 6 5/8"' hole ~ 10,617 '-10,687 ' (70') 78 pcf mud .March 29,..1975 Drilled 6 5/8" hole 10,687'-10,995' (30'8') 77 pcf mud 'March 30,'1975 Drilled 6 5/8" hole 10,995'-11,031'. Mud 77 pcf and 40 sec'. Pipe stuck at 10,991'. Spotted 200 cu. ft. lease crude and followed with 332 cu.ft, mud. Pipe came free, circulated out Oil and conditioned mud for logging. Ran Schlumberger Dual Induction Laterolog from 11,021'-10,590'. Compensated Neutron Log 10,590'-11,021', Borehold Compensated Sonic 10,590'-11,021', Formation Density 10,590'-11,021. 77 pcf mud March 31, 1975 Ran 625' of 5 1/2" 23# N-80 Liner unable to hang, corrected and continued , 77 pcf mud Hung 625' of 5 1/2", 23#, N-80 Blank liner. Top at 10,406' and bottom hung at 11,031'. Cemented with 130 sacks "G" cement, preceded with 30 cu.ft. Water and displaced with 495 cu. ft. mud. Good curculation. Pulled to 10,092' and reversed out Water cut mud. Located top of cement at 10,183'. 77 pcf mud April 2, 1975 Cleared out cement with 6 5/8" bit from 10,183'-10,406'. Cleared out cement with 4 5/8" Economill 10,406'-10,952'. Drilled out float at 10,952' and cement down to 11,005'. . 78 pcf mud .Ap]~il_ 3, 1975 Ban Sperry-Sun Gyro from 9,600'-11,005'. Ran Dresser Atlas Acoustic Cement ~ B(~d Log from 10,994'-9 740' Pressure tested 5 1/2", 7 5~/8'' lap to 2,500 ~psi, ok. Perforated 10,866'-1.0,876' with four 1/2" jet holes per foot. ~I~1~ Hall/burton Formation Test HF~ #1 10,866'-10,876' (April 3, 1975) ~an tester on 7061 of 2 3/8" tubing and 3 1/2" drill pipe with tail at ~07826' and packer at 10,806'. Used a 1,000 psi Gas cushion. Open 7 hours and 5 minutes beginning at 11:20 PM and took a 4 hour shut-in. ~ed off gas cushion in One hour and 5 minutes. Light blow declining to ~ery week blow by end of test. Recovered 946' rise of 78-80 pcf mud. ~harts, ok. ~order T~ Inside 5,923 Bottom Inside 5,911 T~p Outside 5,938 B~ttom Outside 5,977 IF FF FSI FH 97 97 827 5,923 98 98 837 5,911 99 99 816 5,938 100 100 852 5,977 April '4, 1975 ~shed up formation test. Bad perforations so reperforated 10,866'- 10.,876' and perforated 10,856'-10,866' with four 1/2" holes/foot. 78 pcf mud Halliburton Formation Test· HFT #2 10,856'-10,876' (April 5, 1975) P~an tester on 2 3/8" tubing and 3 1/2" drill pipe. Set packer at 10,775' with tail at 10,807'. Used 1,000 psi Gas cushion. Opened tool at 5:45 AM for 5 hours and had 4 hour final shut-in. Bled off gas cushion in one ~our and 25 minutes. Light steady blow declining to weak steady blow by ~_nd of test. Recovered 600' rise of Gas cut mud. ' ~0order 'IH IF FF ' FSI FH _ Inside 5,850 243 292 4,992 5,850 B~tom Inside 5,861 247 295 4,975 5,861 Outside 5,840 247 297 5,007 5,840 B~ttom Outside 5,829 25Q- 300 5,012 5,829 April 6~ 1975 'Circulated and conditioned mud to acidize holes 10,856'-10,876'. Pumped in 1,000 gallo~s of 5% HCL and 1,400 gallons 12-10 HCL and~HF with packer !set at 10,779'. Preceded acid with 200 cu. ft. Water and displaced with i480 cu.ft, lease crude Oil. ~ 77 pcf mud 'i Set Retrieva~)le Test-Treat-Squeeze Packer in 5 1/2" liner at 10,779' and opened to surface at 6:00 AM, April 7. ~'April 7, 1975 Production test of perforations from 10,856'-10,876'. (4/7/75) Following acid stimulation, opened for 52 1/2 hours. Flowed acid water at 300-700 bbls/ day rate. ~oovered spent acid Water and formation Water in drill pipe. No pressure recorders run. April 8, 1975 Continued to flow well for 52.5 hours. Pulled tester at 10:30 AM. Had recovered 65.55 bb. ls. acid, 15.39 bbls. left in drill pipe. Reversed out 77.4 bbls. spe~t acid and Water. Lowered mud weight from 77 to 75 pcf, and raised viscosity from 35 to .39 sec. 75 pcf mud A~ril '9, 1975 Ran Go-International Casing and Collar Log. Ran Perforation Log from 10,900'-10,7OO'~. Set cement retainer at 10,850'. Cemented with 100 sacks of "G" cement. Preceded cement with 20 cu. ft. Water and displaced with 419 cu. ft. mu~ and Water to a final pressure of 3,700 psi. Reversed out 16 sacks, es 'timated 83 sacks went into formation. Perforated 10,808'-10,817' with four 1/2" jet holes per foot. Top of plug at 10,844'. April 10, i975 Ran Halliburton Formation Test HFT #3 10,~808'-10,817' (April 10, 1975) Ran tester on 2 3/8" tubing and 3 1/2" drill pipe. Set packer at 10,746' with tail at 10,766'. Used 1,000 psi Gas cushion. Opened tester at 9:00 PM for 9 hours. Took 6 hour and 15 minute final shUt-in. Bled off Gas cushion in one hour and 30 minutes. Light blow of Gas with 0il to surface in 6 hours and 5 minutes. Flowed 35.6°API gravity Oil at 48-96 bbls./day rate, cut .5% W'ater through a 1/2" choke for the rest of test. Recovered Gassy Oil, ~o free Water in d~ill pipe. (con't next page) 'April_ 10,_1975 (con,t) Recorder '' IH IF FF FSI FH Top Inside 5,703 1,239 3,110 4,25'~ 5,605 Bottom Inside 5,689 1,255 3,098 4,234 5,615 Top Outside 5,717 1,283 3,142 4,276 5,614 Bottom Outside 5,730 1,301 3,144 4,266 5,680 75 pcf mud Cleared out fill with 4 5/8" Economill from 10,824'-10,844'. Circulated and conditioned mud. Perforated 10,824'-10,817' and 10,802'-10,782' and 10,770'-10,720' with four .39" jet hol~s per foot. Scraped perforations with 5 1/2" scraper. Ran perforating log before and after. 75 pcf mud April 12, 1975 Completed per~forating and rigged up to run production tubing 'April ' 13, -1975 Ran 3 1/2" on 2 3/8" tubing. See attached tubing detail. Ran Go-International Neutron Log to set packers. Landed tubing at 10,824'. Opened sleeves at 10,769' and 10,696'. Removed BOPE. Installed x-mas tree. Displaced mud with lease crude. Closed sleeves at 10,769' and 10,696'. Set packers. · Apr_i..1 '15, 1975 Put well on production. Released rig at 3:00 AM. J. W. Wilson }18 o . { 3~' X 6" TUBING HANGF' · · 3~? · 73 JTS. 3%" EUS 8rd 9,3~ N-80 SU'r~S 2325.30' ' ' .-_~ ' 5b JTS. 3~' EUE 8rd 9.~ N-UO BU~SS ~676.78, ~ - h~29.hO~' ' C~CO ~4 ~~L 12.78' '~ '-~ :./:'-"~ J ;J :---' 42 J~. 3~' SUE 8rd 9.~ N-80 ~~SS 1290~34' _ 6,33~.66~ C~C0 ~ '~NDREL . ' 12.1%' -- 6,98~,~-- C~CO ~ ~t~REL · - ' ". ' 12.85' ; .~ "' -16 J~. 3~' E~ 8~ 9.3~ N-80 B~~ '489.53' ?,~ 4~.-'~ C~CO ~ MAbeL · 12~88' ' 7,985-~6¢~ ~ JTS. 3~" EUE 8rd 9.3~ N-80 B~TRESS .~88~09' ~ ~.. ~..'l '- ~o ~TS. 3~' ~s S~ ~.3~ ~-~0 SUW~S ~Z'~5' " .J 65 4~. ~,, EUE 8rd 9.3~ N-60 BUT~S~ ~006.79' ~o. ' F~ x ~,, x-o~ ~uz~ss ~.3~, - 6 ,~ ~ OTIS 'x~', SL~zv~' ~.~9, ,o,z~-''"~'~' -~ 2%" OT~ "S" NIPPY,' P0si~ion · '/ ' ~ "~ ~s. c~o.~,) ~.o~z,, o~ . ~o. ee, ' ,o,,~O~768.12,]-- . 10 v6° ~,~~" BRO~ "CC" JOINT - '. · ' '' ~' ~ ~ 2~" ~IS "~" SL~ " 10,772.~1' ~,, ,, . . . 2.88' ID vv~ ~,~2~ x ~ 20~ ~R FH ~AC~R ROTATIONAL SEF 6.15' ,0808 . ' ".. ;.'..~-':'2"3 B~T JTS. 3.~2" OD ' ' hh.61, ·..' / :'~ "~ NO~: 3~' Tubing was pulled from S~ 33-8 · - TOP OF PLUG lO,844 i ~T,-Z DRILL ~) 10,8~0 T.D. 11,031' S.C.U. 44-4 CASING & TUBING DETAIL SECTION 4 T.? N.,R.gW. ELEV. 150' K 4.29 TRANSMITTAL AN! ;KNOWLEDGEMENT OF RECEIPT OF DEPT.: DATE '' FD - Folded R - Rolled S - Sepia F - Film. X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY e- 2.~_~c .... 3~ e4-9 WELL HISTORY LOG 2" 5" - -- -- IOO 2OO ~1 I~' Jl OIL AND GA5 RECEIVED t3Y REMARKS O~/OTH£R biDE, THIS SHE'ET ._ ~2¢"~ ~ ¢"~'~ ¢,'~.~ .... v'~,~L ~ %",~"~ ~'~, /~%~ . ~- ~"~'~- ~ ~%' ~ *'" ~--2/ ~ ~. s ~'-,,,~ S--C ............. ,:d," ¢d4,_ Oil Company of Cai ..4 =--,-¢.,-.~..c,~ ....,.'; ~, w;'Oi "5: '{{:~;L,. ....... ; ...... ~,.:¢¢ A,nchorac:~-o, .Alaska 095] 0 ' 09, r,~ozi, h c-~.i~o !~50 ~',(s~:,t o~. .~t.tl ....... At t:,,ta] ac.l, ltJ.~ 455' Nor'Nh and It58: ... Soc. ...... { I~ 7 7 - 6 6 i 12 - 2 7 - 7 ,:~ I ~ e ~0. ~O'i~l, DE:PI}!, ~i; & 'I'VD ]21.PLUG, BAG}2 T9.. >,(D & TVD {~2 IP MI'I.TIt'LE COMP[,.. ['2~. iN'I'Li(','AI.,- ilf,TA~Y I !0,844 ' }'iD I now xas~* ] ~,m~,u:~, ,v '~q ~',;:' -' O o *m ~ ~-,v- - r"'o ' . . l!,0a.~, mD Iv.c,-;./ ~vD 1 ..--, x .... >. , 0 - Top' ~0,720' MD i0,5~2 TVD Hem].ock Bottom 10~824' MD 10,659 TVD ~l :~ :'~3 ;?~Li¢tl 7 :li.~ ii~Z- (;Til E"[' ii;[%-~i c x DIL, CNT'D, I~NCS, Cement Bend 2S. CASING P, ECO!:D tReport alt ~.l_ri'4g~ sc', m u~cll) .... ~.6!'.' _ ........ 1 04 77 ' [ Driven ~ ¢, -~ . - ...... ~' --~ ...... ~ ~i-~35'7 ...... ~; ........ , .................. ..~d :,/4 ,,0. o ~ o, 3.¢ / 1., ' !1950 sks. G ccmen!:: Nc'nc'~ .... -.::--~ ' ................. }'¢5.:, ;'. ..... L-;- 3.5. :,;~L~.L ( ' :, ~. 29. LINEii }G-?CORD TOP iMD) I BOTTOM SACKS ........................... .... I 82, ACID. SIIOT, FR..1CT'U[,'I,,', C]'23',,i':N3' SQU}';I':ZE. l,/i'C. DEP'I'tt 1NTERYAL (?.iD) AMOf'NT A:C9 KIND (~F, MATEi~i,': 10,720- i0 WT0' - ...................................................................................... r , ~ ~ '79 o~-c, ~1 ,lc,<~ 'c''~ ~,-p~,,. 10,782 - 10,802' Four 1/2" jet ho]es ..... ~x_~.x ................ :~:.._..!:~:.: _h:~::-".'~_.~_~ .... .k:'~.:.:.- ............ in 808 - :::,824' per foot iJ.O.:~2;6_-_2~.:9~_~TfL~lO00 _:~:!.s. 5?,..NgL, ].,100 <::)]., ! ~ ~iJC~[,-II["~ & !,900.g~,:~ ........ ~. 1 (2:85- 6 - s-~-" ~.. "' 7. [J ' ~,b" ._ '-,' s k s. s..". .................................... ".,.a' .... ~. ~., "c' 33.'~ PI{OI)I :CTION DAT~ F!SL~;T ilo -~, ,, , f',,OD[ [ ~ I)N. ....... Mi TrtOD(r;O~ z0 ~t.,~ .~¢t. ........ pt~?ll)' ;~- .... 8['(' O't([ ~t' Of pNi2tp) ~~ "1 Ir ....... ~'"'~TI"* 4--18-75 [ Plowing 'J l"r()c'iucing d,~-!9-75 4 ........... ~ 336.7 , 154.2 ] . 3 I 45'/ FLO~V, TU'BiN0 t'RkS~, ~ CA~:~N{. i'[~;:;~S[,'!ii; j ('At,Oi/I,ATi;D OIL i;i~f,. GAS--, MCF. ~VA'I'I',R--t'{-{~:~ ........... ~ .................. I 200 I .......... ~ ? c', ? 0 99 r:; 8 ] .'~ ILe.:[ri-}:'::ctec~ back 5..nto FSe:i.d I ::57-i::Y:'-: bf:.:.L({-':: q,:k ,,:: ................................................................................................................................................................................... 2 - i 0 OIL AND INSTR UCTIOiqS ....... , ',. / - .,,... ~. i~am ~3: ~'~ubmiL a sep',?.rgte coml~let, h)n ;'epor6 on this form for each f~terval to be separately produced. (~ee i~:structkm for it.e~:ts 215 aud %;[*,',~ AL, It4I'LI~TANT Z()NE~ OF I>OIIOSIWY AND COXTEX~S TIIEIIEf}F Ii¢%'Ki~VAI, TESTED, CUSItlON t'SED, TI~-IE TOOL OI'EN, t,'[,O~VING AND S}IUT-IN }?tlESSURI~;~ AND t~ECOVEi{IE~ ~'.:. ~.~o. ~_ Pe~.~s [0,8o~ ~ ~0,876~. Used Took 4 hrs. f~_na! shut-i¢. Bled of gas cushion in i hr. 5 min. Light blow oflgas declin}ng to very weak blow of gas at end of testJ~ Recovered 946~ rise 78-8~ pcf mud. Charts OK. Press. Recorder Data: Top Inside Bo{tom !nsidel Top Outszae Bottom Outsid~ See a- I .H. 5923 5911 5938 5977 :tachment f( I .F. F .F. 97 97 98 98 99 99 ,-00 100 }r F.T. No. 2 and No. 3 FSI FH 827' 5923 837 5911 8]_6 5938 852 5977 U.S. ,";CV':'TN',~E',J '.-'Ri,N'r,u:¢: OFCFU:': 19Y't--O.-=gb636 : - [ ' "-: Pressure l?ecozder DaCca 5'~50 243 292 4992 To'0 Inside . o Bottom inside 5861 246 295 4975 Top Outside 5840 247 297 5007 58,! 0 Bottozl Outside 5829 250 300 50!2 .~n ~,~,:}, ~..~ .. F.T. No. 3 Perfs. '10,808 -- 10,817:. Used 1000!i~ ga:.: (?.].[{;~).i(B}I. O]p('!]'] 9 hours. Took 6 hoLd. r, 15 m.~nut, e final shut~- .[.n. Bled of.;i gas cushion in ! hot:A~, 30 minutes. Light blew of gas w:i. th oil t© sfc in 6 hours~ 5 minutes. Flowed 35.6° APl gravity oil ah 48 to 96 B/D rate~ cut 0 o% water thzeugh a _/~ choke for balance of test. Recovered gassy ell, no free wat,::r in drill pipe. Pressure Recorder Data I.H. I.F. F.F. F.S.I. F.H. Top inside 5703 1239 311_0 4259 5605 Bottom Inside 5689 1255 3098 4234 5615 Top Outside 571'7 1283 3142 4276 563.4 Bottom Outside 5730 ]_301 3144 4266 5680 Production Test of Perfs. 10,856 - 10,876 following aoid stJmulat:i.o~, o]2on for 52 1/2 hours. Flowed acid water at 300 - 700 B/D rate. Recovered spent acid water and forma- . ~ ~ ~ c~ ~ -- .~ .~ tion water in drill pipe No t. Ze .... ~l..-e ZeO~AF{.[Q..I/S OiL AH'C) GA5 A.NCHORAGI~ SU VSV FOR STKNDARD OIL COMPANY OF CALIFORNIA TYPE OF SURVEY: SURVEY DEPTH: FROM .... 9658 LEASE? ... SCU , FIELD: Swa33s on River Gyroscopic M.1 tishot Fr. To 1100~ · .... WELL NO. FTe COUNTY/~X'~f~/ ,Kenai Peninsula . STATF Rlaska DATE OF SURVEY. A'pril 3, 197~ JOB NO... SU3-]6968 . ,. OFFICE: A~horage ~¢laska 274-6696 ..... "" SPERRY-SUN ;~ELL SURVEYING. CO~4PANY PAGE ....................................................... A~!CHOP, AGE ,._ ALASKA ....................... ]] -~-~'DAR6'-'6i'~--~MPANY OF CALIFORNIA .CATS OF Sb~VEY ~PRIL 3 ~'~u~TISHOT SURVE SCUA4-~ COMPUTA'TION DATE SURWEL GYROSCOPIC. - . .... ~, SU3-16968 S~ANSON RIVER APRI[ 8 1975 JOB NU~B.~.' .......... ALASKA KELLY BUSHING ELEV. = 150.80 FT. ,' ZERO AT INCLINO~iE'TER AND KBE TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES ., .VERTICAL DEPTH DEPTH DEPTH DEG MINm DEGREES DEG/IO0__NORTH/SOUTH__EAST/~<E ST SECTI ON 9658 9552.55 9401.75 18 30 N 73. 0 9700 .... 9592,4,4_ 9_4,51_:_.64 -17 9800 9687.51 9536.7l 18- 1! N 72.28 9900 9782. ~,2 963'1.62 18 30 N 70.81 10000 9877.30 9726.50 18_21 N 10100 9972o2~+ --' 9821.43 18 16 N 68.57 10200 10067.22 9916.42 18 10 '-. N 68. 9 0.00 275.18 N 742.2~ W 791.47 1.31 279.02 N 754.78 W- 8..0~_..._5_6_ 0._64 3_0_9_..15_N , :, 843_,_89 _W 8.98,52 0.12 · 320.56 N 873.16 W 929.9~ 0.18 332.10 N 902.21 W . 961.19 10300 10162.28... .10011.48 18 0 .... N. ___6 6....9 2_w --10400 10257.39 10106.58 18 0 N 66.93 W 10500 10352.44. 10201.64 18 10 N 66.80 W 10600- 10447.51 10296.71 . 17 58__N 66. 9__W 10700 10542.60 10391.80 18 5 .N 63.54 W 10800 10636.35 10485.55 22 3/-+ N 62.76 W 109§0 10728.41 10577.60__ 23.__25__N 61... 9.7_W__ IIO00 I0819.32' I0668.52 25 45 N 59.5I W IIO05 I0823.8I i0673.0i 26 I5 N 59.58 W O~ 40 343_,,.97.__N ..... 930_.,8_9 W ~q2.. 2.3 0.03 356.09 N 959.32 W 1023.11 0.17 ' 368.28 N 987.86 W 1054.14 0.30 380.67 N 1016.29 W 10~5__._1.~ 0.79 393.84 N 1044.28 W 1116.00 4.49 409.54 N 1075.25 W 1150.56 00_90____42_7.,67 _N. . !.1_09~_85 W 11.~.9_._3_8_ 2.54. 448.02 N 1146.11 W 1230.57 10.07 449.14 N " 1148.00 W 1232.73 HORIZONTAL DISPLACEMEMT = 1232.73 FEET AT NORTH, .6.8 DEG. 37 MIN. WEST 'AT MD = 11005 ..... THE__CALCULAT. I ON_PB. OCEDURES ARE BASED ON THE.USE PF, T..,_H_RE_E_D.!ME__N. SJ._O_-N,A_L__R.A_D_!U-S CF CURVATURE . . -.! · ., - .'. -:: - . METHOD, )_.]_. . · . ..y ', ' SPERRY-SUN-~:.ELL SURVEYING COb~,PANY PAGE ' AtqCHFJRAG: ALASKA STANDARD CIL-CCMPANY (DF SCU44-4 · ~ S'~ANSON_RIVER ALASKA ALASKA C.~LIFORNIA CO~qPUTATI ON DAT~, 1.9.75 ........... DATE OF 5UP, V~Y APRIL 3 1975 SURWEL GY;~,OSr. COPIC ~-~ULTISHOT SU~V ....JOB NU.{,BER' ~,' .................................................. SU3-16968 KELLY BUSHING ELEV. = 150.80 FT ZERO AT INCLIHC~'ETER,, AND KBE KELLY BUSHING ELEV. : 159.80 FT ................ .. INTERPOLATED VALUES FOR-EVEN 1000 FEET OF MEASURED DEPTH MEASPS. ED DEPTH TRUE SUB-SEA TOTAL ' __ VE R T I C ~L.____V_E.. RF.I.C ~L RE CT_A_N G U..L.A RC_O0 R D! N AT E S DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL m DIFFERENCE CORRECTION 9658 ~552.55. 10658 10502.68 11005 10823.81- _..~401.%5 10351.88- 10673.01 THE CALCULAT-~DN -'PROC EDURE · . ~88.0] N 10~2.61 W 4~9.1z~ .N 1148.00 W __.= 1.0 5· ,_4_5 m, m 155.32 ,49.86 I8I.I8 .25.86 S ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS CF CURVATURE METHOD. ~o SCU44-4 '.__S.~;ANSON_ R I_V.E R ALASKA SPERRY-SUN'~ELL SURVEYING COMPANY AHCHOR A GE.~ ...~.~ L ASKA C~LIFORNIA " COMPUTATION DATE APRrL '8 197..5 r. PAG~ · DATE OF SURVEY APRIL :3 I975 SURWEL GYROSCOPIC NULTISHOT SURVE _,JOB_ ~,! U..I':~B_ E_i?,__S.U =3--__1 _6~_ 6. 8 KELLY BUSHING ELEV. = 150.80 FT. ZERO AT INCLINONET2R AND KBE INTERPOLATED VALUES FOR EVF:N .100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TRUE SUB=J_EA. VERTICAL m VERTICAL DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD NORTH/SOUTH EAST/WEST DIFFERENCE VEP. TICAL CORRECT ION ' 9658 9656 9865 9972 !0077 10182 955 9401.75 955 9400.00 965 9500,00 975 9600. O0 - 985 9700.00 995 980Q.00 1005 9900.00 1O0OO.0O __1 O100.._O0 0.80 10200. O0 0.80 10300.00 O, 80. 1040Q._O0 0.80 10500.00 10750.80 10600.00 · 10823._8! 1_06~3. ql 10287 1015 10393d .1025 10498 1035 10603 1045 10708 1055 10815 1065 10924 .1 lO05. 2.55 0.80 0.80 0,80 - -" 0.80 0.80 0.80 0.80 0.80 275.18 N 742.23 275.00 N 741.67 28_4.62 294.77 N. 804.23 W 305.98'.N 835.69 W 317_..97__N _ _ _8.66:5.7__W 330.09 N 897.21 W 342.51 N 927.45 W 315_5_~_.25N 957_.3.5 W 368.07 N 987.36 W 381.10 N 1017.26 W . 395.. O? N 412.29 N 1080.59 W 432.22 N. 1118./.1 W 449._15 N !15.8...OQ_W 105.45 105.35 115.84 121.2 _ _126..6 - 131.9 137'.1 142.2 147.46 152.65 157.8~, _. 16/-!, 84 173.60 1.8.!.-.! 8' 8 -0.09 5_._?.9 5.28 5 5.28 5.21 5.14 5.19 5.18 7.00 '8.75 7.58 THE CALCULA T I THE__NEARES ON PROCEDURES USE A LINEAR INTERPOLATION ~ETWEEN T_20._f_OOT MD (FROM RAD_!_U_S____O_F _.CU. RV_A_T__.U.R_E_)__P_OI_NIS -.. - .. ..:...j =,.. -..: STANDARD OIL ,COMPANY OF CALIFCRNIA SCUAA-q SW~NSON__R!VER ALASKA / - . _ · ', SPERRY-SUN WELL SURVEYI,~G COIqPANY , PAGE ~..NCHORAG~ ~ ALASKa, ............................................ . . DATE OF SURVEY APRIL 3 1975 COMPUTATION DATE SUR~,SL GYJZOSC'OPIC ~AULTISHOT SUM APR I L .... 8__1.9_~5 ,JOB_ NLI~4 ~ E,q. _S U3:'_1.69.6. 8 KELLY BUSHING ELEV. : 150.80 F ZERO AT INCLINOMETER ,AND KBE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS MEASURED DEPTH T_R UE S U ?-_S E A. T O_T_A L VERTICAL . VERTICAL' RECTANGULAR COORDINATES DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 10654 10498.87 10348.07 10719- 10560.62 10409,82 10824 _ 10658.5l 10507.71 10838 10671.44 -' 10520.64 10924 10750.43 10599.63 387.48 N 1031i50 W TOP HEMLOCK HS' 396.54 N 1049.68 W TOP HEMLOCK H8 413 ,..7_6_N ' '1_083. ~,4._.W. _ B AS E_H.E~ L O_C_K__8- g ' 416.22 N 1088.22 W TOP HEMLOCK H1G. 432.15- N 1118.27 w BASE HEMLOCK i I GREA'r, I. AiVD DIRECTIONAL DRILLING INC. ~SURFACE DIRECTIONAL SURVEY -- - .. _ SOU ~o~¥~o~ DATE THIS I$ A RECORD OF A SUB-SURFACE SURVEY' OF YOUR WELL Wp hpve. r.et.~ain.ed a copy of your survey report .in our files for your' ~,Prtv~enienc.e; h~owever, should you so desire, all copies of the survey report will ~.e forwarded to you on written request. All surveys are kept in a Io{3k_ed file and are held in strictest confidence. Additional copies of your ~rv.e¥ report can .be made from the original by any blueprint company. AP R 2 '~ 1975 DIVISION OF OIL ~NI) -STANDARD- OIL- CO, OF-CALIFORNIA ........................................... APRIL 14~1975 --SWANSON-R IVER -F I ELD ............................... SCU- 44,-4 -KB--ELEVF-'lSO'eS-FTi .................... DECLINATION 25-DEGREES --MAGNETI¢.,$ I NGLE--SHOT-SURVEY -TANGENT I AL--METhOD-' OF-'-COMPUTAT ZON ~OMPUTED--FOR--GREAT" LAND-DIRECTIONAL DRILLING BY F, Me'--LZNDSEY $ ASSOCe ~ --RECORD- OF SURVEY ..~ AEE-CALCUEA Tt ONS-PERFORHED--BY .... l -B-- ~- ELECTRON l C-~ CONPUTER -'TRUE -MEA$,-DRIFT--*VERTICAL ..... SUB ........ DRIFT ..... --DEPTH-'ANGLE ..... DEPTH ...... SEA ....... DIREC D .... M ......................................................... DEGe .............................................................................................. DOG LEG TOTAL COORDINATES ........... C L 0 S U R E S ............. SEVERITY ...... SECTION DISTANCE ........... ANGLE .......... DEG/iOOFT-~DISTANCl ............................................................ D M--S .... O--'O ....... O .......... O,00 ........ 150,80-*'$' 0 41'3 ..... 0 15 ..... 412,99 ----742 ..... 0 30--: ....741,98 -"591,18 'S 75 --4015--0-'45 .... 1014.96 ...... 864,16-$ 75' · '1222 .... 1 ..... 0 .... 1221,92' i071,12 .... $ "~ 1550---1'-' 0 ..... 1549,87 1399,07 .... S 55 --"1860 ......1 ..... 0--1859,83-1709,03 '-'N ~7 ~136 .... 0 ~0 ....... 2135,82 .... 1985'02'-N 55 '. F~4 ...... 0 ~0 ...... 27~ 7 2582,99 $ 85 -- 30~8---'0""~5 ...... 30~7,77 -2896.97 S 90 .... ~370 ....... 0-15 3369,76 ..... 3218,96" S 20 .... 3711 ..... 0-15 ...... 3710,76--3559,95 .... S 10 -~120--0'-'30 .... 4119,74 ..... ~958,94, N 70 ---,352 ..... 1 ....... 0 .... 4351,71 4200,91-N --~813 .... 1.-30---4812.55 .... ~661.75 .... N --5160- 2 ....... 0 .... 5159.3~ -.-5008.5~ ...... N 59 '--5505-.3 ..... 0 ...... 5503,87 ...... 5~53.07 -N 55 --5915 .... 1"'~5 ..... 5913,~8 ...... 5762,88 '-.N 67 --6226 ...... t ..... 30 6224,57 6401 .....2 .... 1-5-'-.6399,~ ..... 6248,65 .... N 80 : ..... 6638--3 15 ..... 6636,05 ...... 6485,25 ..... -----676~ .... ~--'15--6760,71 ...... 6609,91 .......N 78 0.00 S ............. 0,00 W ........ 0.00 1,27 S ...... 1.27 E .......... 1.80 .............. 2,01 S ......... ~,0~ E ...... 2,94 $ ......... 7.~9 E ........... 8,05 5,9~ S ........ 9,51 E ................ 11.21 ............. 9,22 S -- 14,20 E ............... 16,93 5,53 S ....... 18,16 E ............. 18,98 ............ 4.14 S .......... 20.13 E .......... 20.56 .............. 2,86 S .............. 22.36 E ........... 22*54 3,09 $ ...... 25,00 E .......... 25.19 ............. 3-09 S ....... 29,11 E ...... 29,27 .............. 4,41 S .......... 29,59 E .......... 29,92 ............. 5.88 S ..... 29,85 E ............ 30,42 ............. ~,66 S ......... 26,49 E ........... 26,90 2,28 5 ........... 23.22 E .................. 23,33 6,96 N ........ 15,46 E ................ 16,96 13.19 N ........ 5,08 E ....... 14,1~ 23,55 N ...... 9,70 W .............. 25.~7 28,4~ N ........ 21,23 W ............. 35,49': 30,00 N ......... ~-29,22 W ............. 41,88: 31,19 N .......... 35.98 W ........ ~7,62 35,12 N ............ ~8.83 W ................ 60,15 37,04 N ......... 57,89 W ............ 68,73 S '-'0"-0- 0 W ...... 0,000 S 44 59 59 E ........ 0,061 S 63 30 27 E .... 0,09~ S 68 34, 40 E ........ 0,092 $ 58 2 53 E ...........0,~17 S 57 1 6 E .........0,111 S 73 ~ 57 E ........ 0,406 S 78 21 27 E ........ 0,185 0,00 -1.65 -4.50 -8,05 -11,04 -16.61 -18.92- -20.23 S 82 41 /~0 E ....... 0,015 ............. 21.82 S 82 56 14 E ........... 0.099 ..... 24,3& S 83 55 31 E ........ 0,081 .......... 28.18 S 81 30 32 E ........... 0,219 ............29.11- S 78 51 3 E ......... 0,013 -29,90 S 80 1 13 E .......... 0,162 ................ 26,33' $ 84` 23 9 E- '-0.232 .............. 22,40 N 65 45 55 E ........ 0.126 -11.77' N 21 4` 11 E .......... 0.219 ............... 0, t8 N 22 23 35 W ......... 0,29~ ............17,75 N 44 14 48 W ........ 0,I35 N 49- 4 55 W ............. 0,429 N 54-16-.39 ~,W ...... 0,444 N, 57-23 8 38,27' 58,38 67,5t' ................. RECORD -OF-SURVEY ............................. ALL--CALCULA T l ONS-PERFORMED---BY I --B--M -E. LECTRON I C--COMPUTER --TRUE EASe--DRIFT--VERTIAL ......SUB ......... DRIFT TOTAE- COORD]NATE$ 'TH-ANGLE* -'DEPTH ......SEA ....... DIREC D .... H ...................................... DEG. --- DOG LEG .............. C L 0 S U R E S ......SEVERITY SECTION* DISTANCE ANGLE ..... DEG/iOOFT .... DISTANCI ............... D M- $ --6857- "~-45 -6856,39--6705,59- N --7086--6---30 .7079,93 6929,13- N '---7310---~ 0 ..... 7303.14 .... 7152.36 ..... N ----7529-12---30 7516,95 .... 7366.15 .... N 7759'-t3-15 ..... 7740,83 ..... 7590.03 N --7870-t9--30--:7848.76--7697.96- N ----8024"15'-45 .... 7996,98- 7846.18 .... N 8088-13 0 ..... 8059,34 .... 7908.54 ...... N --8207'-12-45 ........ 8175.41' 8024,61"'N 8307-"t5 ..... 0 ....... 8272,00 .... 8121,20 N --'8'417 15 30 '8378,00 8227,20 N --85t7 17-'15 .... 8473.50'~ 8322,70" N -8589 .... ~5 45 .... 8542,80 ' 8392.00---N ~-~"807 19- 0--8748,92"' 8598,12-N ..0~5 .... 19'45 8972,92 8822,12 :---9252'"t9 30'-'9168,05 9017,25 .... N ..... 9~81"19 0-9290,02 9~39,22"N --9518 18' 45 ....... 9~19,75' 9268,95 N ---9658 1~"30 ...... 9552,51- 9401.71 N ' 9863 .... 18 15 ....... 9747,20 9596.40 N --10020'"18'"30 .... 9896,09'" 9745,29~ N ............. ~ .................................. 78 W ....... 38,66 N 65,51 70 W ....... ~7,45 N -' 89,66 68 W ......... 60,69 N .... 122,43 62 ~ ....... 82,95 N-- ~66.29 60 W ....... 109,31 N .... 209.94 61 W ......... I21.87 N ...... 232,60 60 W ............ 142,77 N 268.81 57 W ....... 150,61 N ...... 280.88 55 W .......... 165,67 N-- ~02,39 65 W ............ 176,61 N ...... 325,85 68 W ....... 187,62 N ........ 353,11 68 W .......... 198.7~ N ..... 380.60 79 W ....... 202.46 N ..... '399,79 8~ W ..... 209.88 N ...... 470,37 81W ..... 222,46 N ....... 569,80 -76 W- .- 239,18 N -616,85 75 W ............ 250,05 N 657,42 74 W ...... 262.19 N .... 699,75 7~ W -- 275,17 N .... 742,23 71 W ..... 296.08 N - 802,93 68 W .......... ~14,74 N..- 8~9.12 ........ W ..... 76.07 N 59 27 W 101.46 N 62 6 W ........ 136.65 N 63 37 W 184.04 N 63 12 W 2~6.69 N 62 29 W .......262,60 N 62 20 W ' ' 304.37 N 62 1 W ......... ~18.71 N 61 47 W ........ 344.81 N 61 16 W ......370,6~ N 61 32 W ' 399.86 N 62 0 W .......... 429.36 N 62 25 W - ~8,13 N 6~ 8 W ..... 515.07 N 65 57 W ......... 59~,11N 67 58 W ........ 661,60 N 68 48 W 703,~7 N 69 10 W ......747.26 N 69 27 W-- 791,60 N 69 39 W-- - 855.78 N 69 4~ - O--W .... 0,532 .............. 75,16 30 W ........ 0.8~3 ............... 100.87 48 W ..... 1.112- 136.22' 37 W 1,676 183.36 44 W .... 0,379 235.52 53 W ....... 0,307 261,23 32 ~ .... 1.470 ........... 302.60 56 ~ ...... 0.429 ~2.~0 ~0 W ......... 3,281 ............. 368,14 55 ~ ....... 0.849 ......... 397.5~ 41 W .......... 1,750 427.19 26 ~ ............. 4,80~ .................. 4~6.38 11 W .......... 1,639 514.68 1~ W ........0,524 593,10 22 W ....... 0,820 661,56 ~1 W ......... 0,464 ......... 703.26 ~.W ........ 0.298 747,08 28 W ........0,290 ................ 791.$4 ~1 W .......... 0,331 ...... 855,46 42 W ...... 0.62~ 905,28 .... FOLLOWING-SHOTS ARE --10100-18--16---9972,06 9821,26 .... N 68 ~ ..........32~,].3 N .... '872,37 --].02'00-.].8 ..... 10--10067,07.-- 9916,27--N 68 ~ ...... 3~5,81 N ...... 901,29 :'-t0300"-18 ..... 0'-10162.18' 10011-~8 ....... N 67 W .............. 347,89 N ....... 929.73 ~10400'18 ...... 0 '"10257.28-'10106,48 ......... N"67'-"W ....... 359,96 N ...... 958,18 "-t.0500'-t8--10'10352,30"-10201,50 ..... N- 67-W .......... I~72,15--N .......986,88 ..... - .............. FROM THE-SPERRY-SUN GYROSCOPIC SURVEY W ..- 930,64 N 69 37 I W ......... 0,288 ............930.36 W ....... 961.82 N 69 33 5~ W .......... 0.100 .............. 961.-5~ W ........ 992,69 N 69.29 ..... 5--.W ....... 0J35~ ............... 992,4~ W .... 1023.56 N 69 24-~5.-W--- 0,000 ........ 1023,33 W ....... 105~,72~.N..69-20 .... 19.-.W ....... 0,170 ......... 1054,51 W ......... 905.58 N 69 39 ................ RECORD OF SURVEY ...... ALL;-*'CALCULAT !OHS '-PERFORMED BY -I-'-B'-M ELECTRON!C · ..................... TEUE .~EA$,-DRIFT'VERTICAL .......... SUB .... DRIFT ........... TOTAL COORDINATES PTH'ANGLE ...... DEPTH ........ SEA" DIREC ................... ............. D M ..................... DEG, --10600 17-58 10447,42 [0296.62- N 66 W --- 384,70 N 10700 ....18 .... 5 10542,47 10391.67- N 63 W ....... 398.79 N -10800-22 34 [0634,8[ 10484.01 ..... N 63 W ........... 4[6,22 N --10900 23 25 [0726,56 [0575,76 N-62 W ...... 434,89 N 1015,07 W 10~2,73 W . 1076.95 W ..... 1154,58 N 68 52 8 W ........ 4,490 1112-05 W 119~,07 N 68 38 27 W ......... 0,936 ...... DOG LEG ...... C L 0 $ U R E S ...... SEVERITY '---- SECTION DISTANCE ANGLE ..... DEG/tOOFT ....... DISTAN¢ D- M S - '1085.52 N 69 14 37 W ....... 0,369 1085.3A '" 1116.39 N 69 4 13 W ......... 0,936 ........ 1116.26 1154.5¢ --11000' 25' 45 10816,63 10665-83- N 59 W ...... 457,27 N ...... 1149,29 W ....... 1236,92 N 68 18-1~-W ........ 2,63&-- 1236,92 --tt031'-26-15 1084.~,4~---10693,$4 -N--'59- W ......... 464,33-N .... 1161,05-W ..........1250,45--N-68 .... 12 ........ 8.-W ...... 1,6-1) .... 1250,~I ~OTTOM-HOLE. CLOSURE ..... 1250,45-FEET-AT-N-~68 --CODE --NAME {NTERPOLATED-TRUE"VERTICAL~DEPTHS~-COORDINATES-AND CLOSURES FOR-GIVEN DEPTHS .................... TRUE MEASURED----VERTICAL .......... TOTAL .... COORDINATES ................. C-L-O*S-U R E- SUB DEPTH ....... DEPTH ....................................................... DISTANCE .......... ANGLE SEA D · -D-1 55?4 -E-lO 8313 -- ~ - 10695 5572.83 ........ 24.37 N ............11.64 8277.78 ........ 177.21 N ........ 327.34 10428.39 .... 382.19 N ..... 1009.43 -~10537o72 ...... 398.09 N 1041.35 --TOP--H-8 .... 10722 10562.79 ........ 402.63 N ..... 1050.26 --BASE H-8 -'10822 ..........10654.99 ......... 420.33 N ........ 1084.67 -TOP-H-10- 10840 ....... 10671,51 ......... 423.69 N .... 1090.99 -BASE-H-IO [0925-----10749.08 ..... 440,49---N----1121,36 W 27.01 N 25 W ............ 372.23 -N 61 W .......1079.36 N 69 W ...... 1114,85-N 69 W .......... 1124,79-'N 69 W .... 1163,27 N 68 W ........... 1170,37--N 68 W .... 120~.78--N 68 ............... : ........ 31 58 W 5422.03 34 10 W -8126.98 15 44 W 10277.59. 4 44 W 10386.92 -1 ~0 W-10411.99 49 2-W 10504.19 ...... 46 33 W-10520.71 -33 ..... 15.--W.-10598.28 .. -'HEASUREDOEPTH-AHD OTHER DATA FOR EVERY-EVEN 100 FEET OF-SUB ,SEA DEPTH, MEASURED DEPTH .... TRUE VERTICAL- SUB ..... HD-TVD --VERTICAL '-DEPTH-*' SEA DIFFERENCE ...... CORRECT,OH ....... TOTAL COORD [/'{ATE~ ............ ": --251 -351 ~ ..:451 : 551 651 ) 751 ' ~ ..... 851 ~,. ! 1051 :~ ,115'I .... J' ~ 1~51 ~ ...... 1551 *-165 ~- ~ 1751 250, .....100, ......... 0 .................... 0 ...... 0,77 350, .....200, ......... 0 0 ............................... 450, .....300, *0 0 ......................... 1,35 550, .....400, ......... 0 0 ......................... 1,58' 650- .... 500, ........... 0 0 .....................1,8i 750, -' 600, ....... O 0 .................... 2,04 -850, :-' 700, ...... 0 0 ........................... 2,38 95'0, ...... 600, .........0 0 ............................. 2,72 1050, ....gOO, ............ 0 ........................ 0 ........................... ~,~6 1150, ........ 1000, .......... 0 0 ........................ 1350, ....1200, ........... 0 ............................... 1450, ....1300, ............ 0 ....................... 0 ............................. 8,22 1650, ..... 1500, 1750, ..... 160'0, ....... - 2251 235t --2.551 265]. 275! 185! ........ 1850, ....1700, .............. i951- 1950, ..... 1800, ................ 0 ...................... 0 .............................. .~.,07 --2051 2050, 1900, ........... O 0 ................................................ ~,.57 2.2:5D, 2~00, .......... 2S50, ...... 2200, ............... 0 .......................... ~ ..................................... ~2~ .. 2.~50, .... 2300, 25'50- -' 2~:00, .......... 265'0. ...... 25.00~ ................ ~ .......... 27'5~. ....... 2600, ......... ....... "- .... '- ......................... :3,, '52 ........................... ---NEASURED--DEPT~-AND OTHER -DATA FOR-EVERY-EVEN 100 FEET OF SUB SEA-DEPTH. HEASURED DEPTH --TRUE VERTICAL --SUB DEPTH SEA DIFFERENCE- -CORRECTION 3751 3851 -3951 4051 .. 4151 4251 - 4351 ' 4451 2; 4 ~ ~ ~. :~ -465! : ,751 ~ --4951 5051 5!.51 3750. 3600, ..... 0 ..................... 0 ........ 5.76 S ....... 29.52 E 3850. 3700. ..... 0 0 ................................ 5.46 S ....... 28*70 E 3950. -3800, ........ 0 0 .............................. 5.16 S .... 27.88 E 4050, 3900, ........ 0 - 0 .................. 4,86- $ ........ 27,06 E 4150, 4000. .......... 0 ........ 0 ............................ 4,34 S ......... 26.05 E 4250,--4100. ......... 0 ............................. 0 ............. 3.31 S .... 24,64 E ............. 4350.'"4200, ............ 0 ............................ 0 ......... : ................. 2,29 S ......... 23,23 E'" 4450. .... 4300. ............... 0 0 .............................. 0.29 S ............ 21,55 4550. .... 4400. ................. 0 ..................... 0 ............................ 1,71 4650,-- 4500. ....... 0 ....................0 .................................. 3.71 4750. -4600, ......... 0 0 ......................................... 5,72 4850.'" 4700* ................ 0 ........................... 0 ...................................... 7.64 --4950,---4800, ........... 5050. ....... 4900, ............. 5150- .... 5000* ............ 5252 ................ 5250,---5100, ............... . 5352 5350. .... 52'00, ....... 1 " : ....... 5452 5450. 5300, ............... 5552 . 5550. ..... 5400. · ' 5652 5650, ..... 5500. - i ..... 5752 ....... 5750, .... 5600, : 5852 5850. .... 5700, ......... -'-5952 .... ~--' 5950.'- 5800, ........... 1 0 ............................... 28.63 6052 6050, 5900, ....... 1 ............................ 0 ................................ 29,13 ...........6152.......... 6150, 6000, ................ 1 ............................. 0 ...................................... 29,63 .... r~'6252'~ .... 6250, ........ 6100, ....... ! 0 30,17 : 6352 6350. ...... 6200. ............ 2 1 ................................ 30.86 6452 6450, .... 6300, ..........2 ............................. 0 .................................. 32,04 6553 6653 ~~--6753 685'3 .- 6954 .'----?055' ....... . ..... 7~5'6 6550, .... 6400. ..........2 6650, '6500. ............. 2 6750,-'6600, .......... 2 · '6850."-6700. .......... 3 6950. ..... 6800. ....... 3 ?050,- 7150, ....... 7000. 1 .......................... 9,4~ 0 ........... 11,24 0 .......................... 13,04 0 ................................ 15.94 0 ......................... 1'8,95 0 ..................................... 21.95 0 ........................ 24,11 0" 25,30 0 26,50 0 ............................ 27,69 0 ................................... 33.70 0 ~ ...... : ................... 35,35 0 ........................................ 36,89 I .......................................... 38,60 -0 ..................................... 42,42 1 ............................. 46,32 1 ...... 51,66 N ....... 19,87 E N ...... 18,18 E N ............. 16,50 E ....... ~ N .............. 14.32 E N ........... 11.32 E .... N .......... 8,33 E N .......... 5.34 E N .............. 1.15 E N .......... 3.13 W N .............. 7,42 ~ N ...... 1~,02 ~ N ...... 13.83 ~ N - ' 16,65 ~ N ................... ~9,46 ~ N ........22,18 W N .............. 24.75 W N ....... 27,32 ~ N ......... 30.23 W N ......... 34,10.W N ............. 38,77 W N ........... 44,20 W ............. N ........ 49,90 W N ........ 57,17 W N ......... 65.22 W N ...... 75,83 -.W N ....... :~ 86,54 W .......................... N ......... IO0,06-W ........................ :- ......... '-'HEASURED-DEPTH--AND OTHER DATA'--FOR EVERY-EVEN- 1OO FEET OF-SUB SEA 'DEPTH, _ _ .-- TRUE............... - ~MEASURED- VERT I CAL SUB ...... MD-TVD VERT I CAL :' DEPTH- - DEPTH -SEA--DIFFERENCE--- -CORRECTION ....... TOTAL ' COORDINATES- - _ . 7250. 7100. .... 6 ....... 7350.- 7200, ......... 8 7450, '-'7300, ....... 10 7550. 7400. ..... 13 7500. ....... 16 ....... 7600, ..... 18 7700.-: 21 7800. ..... 25 7900, ........28 8000. ....... 31 8100. ........34 8200, ....... 38 8300, ......... 42 ............ 8400. ........47 8500. .......... 52 8600. .......... 58 7650.--' 7750.- 7850e ..... 7950.' 8050. 8150.- 8250. 8350.- 8450.- 85500.,- 8650, ..... 8750. .... 8.850, 8950, 57.59 65,65 76.06 86.93 98.71 2 110,47 3 ....................122.15 ~ 136.26 3 149.54 ~ .......................... 162.48 3 ........................ 174.21 4 ................................ 184,80 4 ...................... 196,09 5. 202,75 5 ............................ 206,35 6 ............................... 209099 -~ .....9128 ......... ~ 9050. ! -9340 .... 9250,.. ~-' 9~+~+ 5 .... 9350. .... 9551--.:--. 9~50, ~~ ..... 976~ 9650, 9867 ......... 9750. ~--. 9972-- 9850. - '~ 10078 9950* ~ 10~83 ~0050. 10288 10150, 1 , ' -10393 10250, 1 * " '-10498 10350, '1060~ 10~50, .... t070~ 10550,- 10~00, ...... 158 ~1081'7 ..... 10650, .... 10500, ............ 167 ,,, 5 .................................. 600,:36 8700, ............ 64 6 215.60 8800, ....... 71 ............................. 7 ......................... 221,22 8900. .........77- ----6 ......................... 229,13 9000. ..... 83- 6 237,70 9100. ......... 89 6 246.55 9200, ...... 9~ ......................... 5 ................................. 255,73 9300, ........ 100 6................................. 265,22 9400,- 105 ............................... 5 ......................................... 275,01 9500. ..... 111 ........ 6 ...................... 285.73 9600e ......... 116 ........ 5 296.53 9700, ..... 121 .................... ~ ......... 5 ................................... 309,06 9800, ...... 127 ........................ 6 ......................... i .......... 321.50 9900. ..... 132 5 ........................................ 333,81 0000. ..... 137 ............................. 5 ' '' 346'44 0100. ......... 1~2 5 ........................... 359,14 0200e-- 148 6 ................................ 371.95 0300, ...... 153 ' 5 ............................ 385,20 419,68 N -- 114e75 W N .... 131,76 W N .... 151.34 W N ....... 171.19 W N ..... 191.58 W N ....... 212.03 W N ....... 233.10 W N ....... 257.52 W N ........ 279,22 W N ............ 297.83 W N .......... 320,70 W ..... N ..... 346,11 W N ..... 374,06 W N ........ 402.52 W.- N ......436.77 W N ......... 471.03 W.- N ........ 506,50 W N .... 541.96 W N ............ 576.56 W N ......610.92 W N .... 64/+.37 W N ..... 677.25 W N ......... 709,68 W ......... N .. 741,6B W N .....772.87 W N .... 804,05 W N ....... 835.07 W N .....865 ,,87 W N .....896.33 W N 926e33 W N ...... 956.24 W N ...... 986.43 W ...... N ...... 1016.05 W N ---1045.82 W N ..... 1083,06 .-. W 7257 7359 -- '" 746i '~"7667 ;~: '7769 ,.. -7872 ~~"7976 ~ 8079 . ;! 8182-- :, --8389-- 8493 · -8597 8703 8915 902 ! ---HEASURED-*DEPTH.-,AND OTHER DATA FOR EVERY-EVEN 100 FEET-OF---SUB SEA MEASURED DEPTH 1-0927 DEPTH. TRUE -VERTICAL SUB MD-TVD ........... VERTICAL DEPTH-- SEA DIFFERENCE-, - CORRECTION ........... TOTAL COORD ZNATES 10750.-10600. ....... 176 ........................ 9 ....... z~z~O.9! N 1122.07 W ..... '"~NTERPOLATED-VALUE$ FOR EVEN IO00'FEET-OF MEASURED DEPTH, TRUE --MEASURED ..... VERT I CAL ...... SUB ............................ DEPTH -* DEPTH ........ SEA TOTAL- - ¢OORD [NATES 1000 . ?.. -- 2 000-- 3000 ~000 " SO00 " 6000 ' 7000 -., -- 8006, -'-9000 .-10 000' ];t 000 999, ......... 8~9, .............. 2.89 $ ........ 7.30 E 1999, .......1849, ~,83 S .......... 19,16 E 2999, 2848, .......... 3.09 S '-- 28.~8 E 3999.'- 3848. 5,02 S ....... 27.48 E ~999, ~8~8, ............ 10.32 N ...... 9.87 E ........... 5998, ..... 58~7, ........... 28,87 N ...... 23,~1 W ................................ -6996, .......6845, ............ 4~.20 N ...... 80,72 7973, 7823, ............. 139.51 N ' ' 263,16 8930, ....... 8779. ............ 220.08 N .... 53~.79 W ................ ..... 9877, ............ 9726, 312,36'N .... 8~3.2~ t0816. 10665. ~57.27"N ..........11~9.29-~ ......... · ~ ~ r ~ : ~ ' ................ :.~.- ..... 1... ~ : , , ~ . _~ -' ~ .......................... = .......... ~ , HORIZONTAL VIEW ':LS" , ' SCALE I" = 500'~ ....... * ................. -~ ....... ~ .............. STANDARD OIL O0~PANY OF CALIFORNIA ' SCU 44-4 ' ~ ............ I.' ....... ~ ......... , ....~"""~ ................................................ ;- . .................. j .......... : ......... i ............ 4 .............' .... i .............. , ........~ ........~ ........ ~ .......... , .................... ~ .............. ~ ................... i .............. ..- ~ -~ ~ .. ~ ....... ~ ........ , ................ -. .......... ~ ....... : ....... ~ ...... ~.. ....... ~ -- -~ ...... ~ ........... t .............. --' ..... -' ~ ; ........ ::.-.:'~...".:_:'.:.'j:~:.;.._=' .~:s::._:::-.j:_=: ..... ~ ........ ~ ~ .......... ~ ............ ~ .......... ..... ', ............ .I =- ................... ~ .....T .......... j- ......... ...... ~ ............. i ............. ~ .......... .'-~ ....... 1 ....... - ................... ~ ..... = ..... ~ ......... ~, ........... ~.. ..... .,_-_~ ..... ~--~ ......... t .......................... I ............. ~ ........ ~ .......... ' '~~ ~: ..... ........... .......... , ............................ ., . ' ~ ' ...................... ~ ......... ~ ................. ~ ............... ~ ..... . .... ~.. .........~ ..... L ................... I ........ ~ ............. ! ........... t ........ ~ ......... j ... ....... . .... ~ ........ ~ ............ ~ ........ 4 ......., ............ ................ . '~ ~ _ , · ~ ............ ~ ............. "-'~ ......................... t ............. : ...... T ........ ALL. DEPTHS ~HOWN_ If.-"' · ~ , ....... ~ ................. ~ .......... I ........ ~ ....... ~--: ........ ~ .......... ~ ........ I .... : ..... ..I_, .................... · : ................. l ~ ......... ~ ......... ' ~ .......... ~ .... ......... j ........ : y ~ ............... "--::-: ............ . .... ::::~=:.-...: ,.__.=': ::::_.:-:::=~ :- .:: : _.: ........ , .-.- t , ,. ~ .... / . , .... , ......... ............. . ..................... . ..... : .... ;'~:]tF=;::':";~'.::;2~.._i _ '.. :ti ..: ......... ~ ........ ~ ........ --~ .................... i ............ + ........ ~ ....... ~ ...... ~ ......... ................................ i .......................... ~ .... : ..... t ............ __, ................. , .............................. ' ' ............................... ~ .......... ; .......... i ...... * .... ' .................... : ............ , ..... ~ ......... ~ .... ~ ....... ~ , , : ....... : ......... t~.: L..':t:f] :.'_' L-":":'; ~ Z;::: _L.::.;'.-:L._t;L: .... ~ .......... ~ .......... ...... :-~--. - ~ . .J .......... ; ...... ~ ..................... ~ ......... ; ...... ~ . ............ i ................. -~ ............ ~ ...................~ ........... : ................. ~ .......... ~. ............................ ~ .................. ~:'t ........ ~ ........ t ........... ~ ............ t- ..... ~'--'~ .......... ......... ~ ............. ' ......... ~ ............ ~ ............ ~=~.:LZ'.'~ ............... ::;~:;]= ...... :-~-:---'.---~ .... ~-~ ........... ............ .~ .................... , ..... SCALE = IOO0') ' : .-- .......,i. .................... i ...... ' ............ .' ........ STANDARD OIL COMPANY OF CALIFORNIA ............... .... 24oo ........... 1 .................. ! ..... SCU 44- 4 i ...... ~ ........... ~ ........ ? · i ........ :, ; ................................ [ ........ i lAC' METHOD'..: .......... } ....... ~ ..... j ............. . ...... ! ..................... : ........................... * ........... | ....... T ................ ' '- '-:: : !"'."-'.i :'.: .... ._.i:':.':. ~t~o ...................... ! ...... t" ...... : ........... ! ......... 5---. ............... t ............... .:.": .:":' .-':.: -._ :4 .: ' !_::'_~ .: ':-_-:.L-~::_' !. . . ~ ................ , . . . i .... - ... ...................... t ................................................ . ~' ...... ! ~ .......... , ...... i ! .............. ;. ......................... I r ................. ~ -' ': ................ .'- .......... 1. ........................... .~. 7. : .......... ~ ........ ~ .................... ~ ..... -- .......... { ............................. ~ ~ ........ ~ ......................... .............. · - 4400 ............. '~ ....................... ~ ................................... · ........... ~ ........... ~ ...... -~ --+ .......... · i ...... ', ................. -t --~-'~'-'I' ~ ...... t ; ....... : ............... ~ .................... ! .... :2' ' ...... ~ ....... " ........... · ' PTHS SHOWN.. , ..... .... :: .................. ................. = ............. ........... ' ' i I -- I ................... .._; .............. . .... ~ .............. ~. ........ .-. ..: .... :_.~ ........ :'-}-::., .----..~-~'--.-. ~, , ~....~ ~ * .... ~ ~' , ,' .........--- ................. : ....... . ............................ 4 ............ ~'~ - .... : ; ~ ...... ~_ .................. ........ :'._' ......... ? ": ':..: .'.": "' :._'.-.-';":- :"'_-7_:::: ............. ' ...... '-' ' :.'::.;:'_--_-:':7':.:.-.:: .'::~:] ............ ' i::'::-....-7.-?~-::-_.,._--:¥.2~--:-"!; :':':--_'. :': --' ..... : ................................ ; ....... ~ ........................................ t ,~ ................ ......_ . ~, ........................ ........ , ............. i .................: :-~7'; :-.'; ~':::~[---:::'-- .... , ............ , ............. ~ ........ [ .................... ." ...... ' - --' ................ '. ................................ ; ..... ' ........... , ..................... i ....... ...... ; .......................... ' ....... -t ........ ] ................... ' ..... ~ ......... ~ ...... - ...... .+ ........, ........ ,~ ........ ., ...... ~ ............. ~ ....... - ' ~ ................... ! ' . ............ ~, ................................... ~"t ........... : ............. ,'- .................... ~. .......... I -" ; ................... t---_ .... .'~ 1 ........ ~ ............... : ..... ~ .......... t ............ ? ........... ~ .................. t ' - '.~-" ............................................ ~,, ....... ~ ........ , ............. ~ ...... ~__,.__._ .... .,- ' ' ............ i ....." ............................................ -+- ....... ~. .... -~ ..... -' .... - .............. L ..... : _ ! - ~ ~-~'X Ticket [- F L U I D S/k M P L E Dr ~A Date 4-10-75 Number 607931 Sampler Pressure .F.S.I.G. at Surface Kind Halliburton of Job HOOK WALL District ANCiIORAGE Recover: Cu. Ft. ~s cc. Oil cc. Water 0.3 Tester MR. BOWEN wire,ss MR. GORDON .... cc. Mud 1 · 6 Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY BC S _ Gravity 35.6 . APl ~ 'F. EQU I PM E N T & ~ O L E D A T A ~s/Oil Ratio cu. ft./bbl. Formation Tested 8 Sand ... RESISTIVITY CHLORIDE Elevation 151 ~ Ft. COi~TENT Net Productive Interval 10808' - 10817 ' Recove~ Water 0.3 ~~*F. ppm All Depths M~sured From Kelly Bushi n~ Recove~ Mud 1 . 6 ~ *F. ppm Total Depth 10844 ' Ft. R~o,.w ~,d FUt~ote ~ "F. ppm Mo~, Ho~e/Co~g S,~.... 7 5/'8" Casing 5~" 20~ Mud Pit ~mple ~ ~ *F. ppm Drill ~ Length Pipe 10326' I.D. 2.764" . Mud Pit Sample Filtrate ~~*F. ppm Drill Pipe Length_ Tubi nfl 399' I.D. 1.995" . Packer Depth(s) ] 0746 ' Ft. ~,,d W~ight ,~. 75~/CU..ft. ,is 40 cp D,pth T~t~ W~,e 10720' TYPE ~OUNT Depth Back Surface Bottom c,~o~ 1000~ 9as Ft. P,.,. wi,. Choke ~', ~,, Chok. .62" R~co,ered ???? Feetof Reversed out oil and 9as, no free water recove~ed .... P Recovered Feet of Reco-e~ ~,t of < Recovered Feet of Recovered Feet of R~o,k, Tool opened for a 537 minute flow. Bled off cushion on ~" choke, opened ~" choke in 65 mTnutes. Cushion was bled off at 10'30 PM. 0il to surface at 2-15 AM.' Flowed in Baker Tank on ~" choke; first 60 minutes gagged 4 barrels; second 60 minutes gauged 2 barrels ClOsed tool for 318 minute closed in pressu.re. Reversed out test. No free water recovered .... Gauge No.--~856 Gauge NO. 2858 'Go,ge'No. 2857 T~P~TU,~ __ :: _ ~.p~h: 10728' ' ~. ~,p~h: 10732' . ~t.O.pth: 10758 ~t. ~ ~ Cl°ck 24 Ho,~ Clock ~'4 Ho,~ C'l~k Tool 4-9- 75 Est. ~F. Bbnked~f ~O Blanked~f NO Bbn'['edOff Yes Opened9:00 P.M. --~ 0766~ ........ op~;2~4_ 10 A.~. Actual 180 'F. Pressures Pressures Pre~ures Bypass 11 - 15 ~ ...... ,, [ ...... Field Office Field Office Field Office ~ported Computed Initial Hydrostati~ 5703 5728 5717 5729 5689 5762. Minutes Minutes I~itio~1239 " -1167 1283 1231 1255 1271 ' - ~ Flow ..... mz Final ~ 3110 3042 3142 3121 3098 3i45 ~ Closed in 4259 , , 428] 4272 4274 4234 4287 ,, 31 5 ~3 Initial Sc Flow ~in~l ....... ,.,~ ~ Closed in ..... Initial ...... g~ Fbw Fi'° ....... ~¢i6s~d in .................. FinoiHvd,os,~,ic ~.5 ::' ~,"5640 '56~4 ~' 5633 5615 5640- _ .... ,,, , .......... ,,, ,,,, ~ .... FORMATION TEST DATA rOl~ tlI.I~I--PI~INTI~D IN IJ.G.A, t. ITYklt'l ~881! lam 8/14 ~ Ticket FLUID SAMPLE l]~"xlt', A Date 4-10-75 Number 607931 '?~_ Sampler Pressure .P.S.I.G. at Surface" Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ~,. cc. Oil cc. Water Tester MR. BOWEN , Witness MR.... GORDON cc. Mud Drilling ~/r' ~.nT Tot. Liquid cc. Controctorl~r--I'I/~,t DRILLING COMPANY BC S _ Gravity ° APl @ °F. E Q U I P M E N T & H O L E D A T'A --! Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT I Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From Recovery MUd @ °F. ppm Total Depth Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size Mud Pit Sample @ °F. ppm Drill Collar Length I.D. Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length I.D. Packer Depth(s) Ft. Mud Weight vis cp Depth Te~ter Valve ,,, _ Ft. TYPE ~dWOUNT Depth Back Surface Bottom Cushion Ft] Pres. Valve Choke Choke · · Recovered Feet of ~ Recovered Feet of 3 Recovered Feet of ~ O Recovered Feet of ~ ;;~ m Recovered Feet of · · Remarks FOURTH GAUGE' · ITl Gau~e No. 2859 Gauge No. Gauge'No. z TEMPERATURE TIME Depth: 10762 ' ,t. Depth: Ft. Depth: Ft. , ~-~ 48 Hour Clock Hour Clock Hour Clock, Tool A.M. Est. °F. Blanked Off Yes Blanked Off Blanked Off Opened P.M, ,,. Opened A.M. Actual °F, Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Comp~dfe~-' Initiel Hydrostatic 5730 ' 5760 ~e' M~.~t~ · ~ Initial 13-~1 1256 ' ' ~-~o Flow .... ,-'c Final 314-4 3157 Closed in 426'-6 4303 ~o Flow Initial ~o 'c Final I (./3 Closed in ~ ~ , Initial ._~_g Flow z ~ Final ~-~:losed in Final Hydrostatic 5680 5663 FORMATION TEST DATA Gauge No. 2856 Depth , 10728 Clock No. 8105 48 hour No. 607931 First Il First Second Second Third Third Flow PeriodJ' Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure ,, ,, J Time C-ell. PSIG Time Deft. t -J- ~) PS'IG' Time Defi, PSIG Time Deft. t -J- (~ PStG Time Deft. PSIG Time Deft. t -J- ~ PStG Temp. LOg Temp, Temp. Log Temp, Temp. Log Temp. .0OO" Ccrr. .0OO" (~ Corr. .O00" Corr. .OOO" ~ Corr. .O00" Corr. .OOO" ~ Corr. 0 .0000 1167 .0000 3042 ] (.1~5-0 1620)C .Q_36__2 .1.414 41-~5 2 .14_63 1521- .QZ2_3 1.130 4203 3 .297_6... 2_540 .1_0..8_5 .970 4225 ~ . 4490 320 3 .1447 .8-6'0-'q-~40 5 .6003 33_67 .18__0.~ .778 4249 6 .7517 2944 .2170 ,-713 4254 7 . 9030 3042 ._2.]~3-_~_' .6'6-04~"62 " 8 .2_893_ .615 4264 "'gl '" .3_2~55__ .57 7--'-21.'~-6-0 lo! ,36].6_ .544 -~'~71 ,, ' .. ,39_Z8 ----F515-~"~4 ~ .4..3._4.0_ · 4 8'9--'T4'~'~; · ]3 · 4.7_01. .4G-6'42-~9 ]4 J ,5_0.~_3 · 4~ 5---42-§1 ]5 .. .5750 .410 4284** Gauge No. 2858 Depth 10732' Clock No. 8739 qfl hour 01 .0000j1231 i .0000 3121 ' ' I 1 j (.~7~)i 1617)C, ..[~'~2 1.443 4-i~0 2J -2_9_]]i] 1516'. .l_~-l~ 1.1_5.7. 3! .59231 2563 .2017 .996 4230 ~i ~-§-3-5j '3~5 .2689 .8~'6 ' 4240 5j 1.1946! 3299 Ii .3-~62 .8-0-2 4~1-7 i .7~.1 1 79701 3121I~ .4706 .683 .4257 el J ' .5379 .638 ~9 9j J[ .6051 .59__9 '4_2._62 oj.. .6723 .565 4264 ~]J J .73__9_6 .535._ _4.2.67 ,21 .. I- .80_6_8 .509 42_~_7 i31 .8740 .4~5 ]4269 J tsl . :l1 0690 .428 . 74.** .... I t R~=MARKS: *Interval = 87 minutes **Interval : 38 minutes C: Choke chana~_ , , , , ,, ,,, ,, , , · Ticket 607931 Gauge, No. 2857 Depth 10758' Clock No. 8420 24 hour , No. ~,, First First Second Second Third Third Flow Period Closed ,In, Pressure Flow Period Closed In Pressure Flow Period Closed in Pressure j Time Deft. jPSIG Timeoefl.Temp. Log t -J- ~1 Temp.PSlG TimeDefi. PSIG TimeDefi. Logt-J-{~Temp. Temp.PSIG TimeDef'. PSlG TimeDefl-Temp. Log..t -J-t~ Temp.PStG' Jl'O00" Corr. .000" t~ Corr, .000" Corr. .000" t~ Corr. .000" Corr. .000" ~ Corr. 0290 16_38)C .0_674t 1.4-44 4194 - 2929 1545' .1347 1.1-5-9 4228 31.5959 2582 .20_21 .998 4-~45 ~t .8989 32_46 .2694 8~3-7 42-55 __5~.2019 3329 .3_3~..8 .804 4262 65q,.5050 30_0_5 .404t .7-38 42-67 7,q.8080 3145 f ,4715 .684" 42-72 8 ,5_3_89 .639 4~7 9 ,6.[16..2 .60-0' '4~ 79 ~o .6Z36 .~66 428--2 I ]1t , , .7409 ,,.53'7 4~__8_4 ]21 ,8(}83 .5T0 4287 13.! ,8Z57 .4'8-6-' 42'~'7 ] 4t ,_.9_430 .4-6'5 4287 ~st ,, 1.0710 .429 4287** Cguge No. 2859 Depth 10762' Clock No. 10054 48 hour o] .0000 j 1256 .0000 3157 ' I ~!(.1030 ! 16.5_2)C .0335 1.446 4204 ~i 14511I 1552' .06--70 1.160 4241 aj .2973 i 2601 .10--06 .9-~9 4259 i -- 4! .44_85 t 3264 .1341 .88~ 42-71 ~, .5997 , 3337 ' .1676 .8'0-5 4276 aj .7508 J 3017 .20!lI .7-39 4281 71 .9020 j 3157 .23471 .68-5 4289 81 I 2682I .__ ' Ii _ .640 4291 91 j .3017 .69_1 4294 loi i .3352 .567 4296 Il I l~l t !i '3687 '537 t4299 ]2j ! .4023 ! 51i I 4299 ]3i '" I .4358} .48~ 4301 t ' ,;',, RE,MARKS: *interval = 87 minutes **Interval = 38 minUtes` C = Choke change ... , , ,,, ,,, ,, , ,, , , SPECIAL PRESSURE DATA Liquid Production _ . /~x .. , r ,, " 607931 B.T. Gouge Numbers 2856 2858 Tickc ,umber page 1 . _ PRESSURE; PRE$SUFtE l__n_i_ti_ol Hydrostatic ....... ' "5729' - aevot~or, 1 51 .. _Final Hydrostatic. "5633 ~st Flow .... 48* bb~,./day Initial Time 1"2'31 Indicated 2nd Flow - bbls./day ..- Production ..... 1st Flow F~.o~ 537 31'21 3rd F~ov, - 'Oo.~ed ~" Pressure 31 8 UNABLE 42 74 e.~b~ Length %-~ing -¥99 ~.~t~ol~ ~,~:~ ~.D. T~b-i~fg ' TV9-95' ~n. ........ 2nd Flow Final . TO Drill Pipe Factor .dD742 bb,s./.. C~osed In Press. r~ =~=S~,e CaS ing 7 5/8" & 5~" ' ~.. Initial Time EXTRAPOLA';E Foot°ge Tested 9 3rd Flow - Final " Mud Weight 10.1 . '~:~osed l" Pressure Vi~cosiW, au ~=W~m'~ 1 · 4 ....... Ist 4302 O~ AP~ Grov~W 35.6 -- Extrapolated , Static Pressure 2nd - Water SpecifiC' Gravity - -- 3rd - Temperature 180 ............ ~st --4236 Slope P/! 0 2nd - .. 3rd - Remarks: *Calculations based on last reported 'rate of 2 bbl./hour ..... . . .... I B.T. Gouge No. 2856 B.T. Gauge I~o. 28"58 S U M M A R Y 10728' 10732' Depth Depth PRODUCT EQUATION FIRST' SECOND THIRD FIRST - SECOND THIRD UN I'~S' Production Q _ 1440 R bbls. t 48.0 day ,,, Transmi~sibility Kh 162.6 Q md. ft. ' /J, -- m 118.255 cp ........ Indicated Flow Kh --- Kh Copac~w "/~ /~ UNABLE t,'0 EXTRAPOLATE... 165.557 md. ft. ,, , A~;eroge Effective K Kh --' h - md. Permeability K, Kh -- h, 18.396 md. ...... Damage Ratio DR -- .183 Ps -- Pf ~ 3.275 -- -- , Theoretical Potential Q! '-- Q DR bbls. w/Damage Removed 1 57.1 81 day , Approx. Radius b ~ V' Kt or x/Kto ft. of ........ Investigation b, ~ V'K!t' or v"J<~ to 99.390 ft. .., P'~t'~ntiometric ' --- ft, S~rface ::: Pot. --:. El -- GD nE 2.319 Ps -604.66~ These calculations ore based upon information furnished by you and taken from Drill Stem Test pressure charts, and are furnished you for your irfformotlon. In furnishing such colcu!otion~ and evaluations based th,~reon, Holld)urton is merely expre~,smCl its opinion. You agree that t'f~llib'urton mt~kes no warrcmty express or ~mphed as to the accuracy of such colculf~t,ons or op,n~ons, and that ttGIhburton shall not be hoble for any loss or damoge, whether due to neghgence or otherwise, ,n connechon with such calcuk~tions Qnd opmlons~ INTERPRETATIONS AND CALCULATIONS ooz~ 'IYNI:! qVlllNI 'Obi Liquid Production B.T. Gauge Numbers 2857 2859 Ticke, .amber page 2 PRr~$SUR~' __lp,!t,ial .Hydrostatic .... 5~6~. 5~.~_0 __ Elevotio. 151____ Final Hydrostgtic ..... 5640 5663 ];~10W" '4~* ........... Indicated '" 2nd Flow - --bbls./doy _ Initial ...Time . 1 271 1256 Production ......... 1st Flow Final 31 45 31 57 3rd Flaw - bNs./day Closed In Pressure 537 4287 4303 Drill Collar Length ..... 399" ........ I~t~o~ 3~8 ~a~,:l.D. TUbing ]~gg~ ' "~. .... c'~%d ~ ~,~ ~s~, Casing 7--5~'8'"' ~-~" ..... 2 in. , Initial .... Time ... Footage Tested 9 ft. 3rd Flow Finol Mud Weight ] ~-] lbs./gal. .......... Closed In Pressure Viscosi~, Oil ~~ ~ . ~ cp Extrapolated 1st 4319 4333 .... Oil APl Grevi~ 3'5.6 Static Pressure 2nd _ _ Water Specific Gravity -, 3rd _ _ Temperature 1 80 ]~ ......425.3 '4267 Slope P/]O 2nd _ _ ' ' ~ ,, 3rd _ _ r, ,, .... Remarks: '*CalculatiOns based on last reported rate of 2 bbl./hour ..... ..... ,, ....... , B.T. Gouge No. 2857 B.T. Go,~, No. 2859 SUMMARY Depth 10758' Depth 10762' " PRODUCT EQUATION FIRST SECOND ..... THIRD .... FIRST SECON'D THI'RD UNITS Production Q ~ 1440 R '6bls. ~ 48 0 48.0 Tronsmi~sibility Kh 162.6 Q md. ft. m -- ~ 118.255 118.255 c~ , , Kh Copoci~~ndic~ted Flow Kh :- ~ ~ 165.557 165.557 ~d. f~. Average Effective K KA ~ h - - md. .... Permeability ~ Kh - ~, 18.396 ]8.396 ~a. Damage Ratio D~ ~ .183 Ps ~ Pf ~ 3.256 3.261 -- Th~reticol Potentiml Ql ~ Q DR bbls. ,/D~o;~ R~o,~d 1 56.249 1 56.51 5 , , , Approx. Radius b ~ ~ kt -or ~Kto of - ' ~ ..... Investigation b~ ~ ~ K~ t or ~ K~ t0 ft. 99.390 99.390 "Pot~ntiometri~ ............... ft. S,~foce ,:: Pot.~EI--GD+2.319Ps -591.242 -562.771 ...... ,, ........... ~ , , , , , NOTICE;These calculations ore based upon information furni,hed by you and taken from Drill Stem Te,t pressule ¢t,0,I,. gna ore furnished you loc your -- - information. In furnishing such calculations and evaluahons based thereon. Halhburton i~ merely express,ng ~ts opln,on. You agree that Holhburton makes no warranty exprest or ~mphed os lo the accuracy of such calculohons or op~n,ons, and lhol Holhburton shall not be hoble for any Joss or damage, whether due to ~ghgence or otherwise, In (onnect,on w~th such colculahont and oplllions. , . ,. , . ,, ., , ..., ..... ~ .... _. '°'""' ...... ..... INTERPRETATIONS AND CALCULATIONS .,,....,,,,,, ,. / I IL,,K. ls l NO. 607931 Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Ass~-mbl¥ ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple ClP Sampler ............... EXtension Joint .................... AP Running Case ...... {2.). ........ Hyd,aulic Jar ..B..~ g. John .......... VR Safety Joint ................... PreSsure Equalizing Crossover .......... Packer Assembly .~"..R. TT.S. ......... Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ...(.2). Drill Collars ' Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ' Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Dril! Collars ........... 1 ........... Flush Joint Anchor : Blanked-Off B.T. Running Case ........ lotol Depth ....................... O.D. I.D. 3.75" 1.75It 3.50" 2. 764" 2 3/8" 1.995" 3.88" .87" 3.90" .62" 3.87" 3" .. 3.90" 1.25" 3.88" / .75" 4.40" 1.92" 2 7/8" 1 7/8" 3.87" 3" LENGTH 2.80' 10326' 399' Tubing 64.97" 57.38" 59.20" 60" 30.32" 54.67" m 48.34" DEPTH 10720' 10728' 10732' 10746' 10758' 10762' 10844' FLU I D S^MP LE D(-~ -- Ticket A Date 4- 5-75 Number 607930 ' Sampler Pressure .P.S.I.G, at Surface Kind Halliburton ,, Recovery: Cu. Ft. C~s Of Job HOOK WALL District ANCHORAGE .... cc. Oil cc. Water Tester BOWEN Witness GORDON ,. Cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY NM S .... .... Gravity_ ° APl @ °F, EO U ! PM E N T & H O L E D ~ T A I Gas/Oil Ratio cu, ft./bbl. Formation Tested - ---t RESISTIVITY CHLORIDE Elevation'~-Jb/'"J<, B Ft. CONTENT ' ' Z Net Productive Interval 10,856'-10,876' Ft. Recovery Water ~ ' °F. ppm All gepthsMeasured From Kelly BuShing ... Recovery Mud ---- @ °F. ppm Total 'Depth --Zl¥005', Ft. us> Recovery Mud Filtrate __@ °F. ppm Main Hole/Casing Size 75/8" Csg. 5½" 20//_.Liner_~ Mud Pit Sample @--°F. ppm Drill Collar Length ~'~'/-5' I.D. J' ~" Mud Pit Sample Filtrate @--°F. · ppm Drill Pipe Length 10,069 I.D. 2.764" packer Depth(s)1 O,775' Ft. Mud Weight vis,.,, cp Depth Tester,,.Volve 10 ~ 749 ',, Ft._ TYPE AMOUNT Depth Back Surface Bottom Cushion GAS 1000 PSI Ft. Pres. Valve NONE Choke ~,, & ¼,, Choke ,.62" · · Recovered 600' Feetof gas cut drilling fluid } Recovered Feet of Recovered Feet of ~ " O Recovered Feet of __ ~ !-=-I Recovered Feet of m Remarks Tool opened @ 5-45 AM - bled off gas cushion on ¼" choke. Opened on ½" choke with a very light steady blow. Closed at 10:45. Reversed out the test. No formation fluid - only 600' of net rise... Gauge No. 2856 Gauge No. Z~b~ " Gauge'~o. 2867 TEMPERATURE T'ME - Depth: 10,757~) Depth: 10,761" Ft. Depth: 10,786' Ft. o 48 Hour Clock 2Z~ Hour Clock ~'~ Hour Clock Tool A.M. Est. 'F. ','BlonkedOff' ,,NO ,, glank.e..d,Off, ,~.q Blonke,d..Off ~"~S Opened 5'45 P.M. 10,794' Ca Opened A.M. _Actual 1 7~F. 'Pressures Pressures Pressures Bypass 2: 45 P.M. .... Reporl~'d ' Coml~uted Field Office Field Office Field Office "lnitio-I Hydrostatic 5850 58-8-7~ ~ b889 5840 5909 '" Minutes Minutes '' ~o F~o~ ~n~t~o~ 243 129'3 246 1408 247 1540 . ~. Fin°l 292 316 295 320 297 332 300 ,, 3013 __.. Closed in 4.-992 5025 4975 " 5032 5007 50-49 2z~0 237 > -, Initial r- E~o Flow --- ~'c Final "~=' ~Closed in ........ Initial ,.~.o. Flow Fin'~al ,~ ~ Clos~.d in ?in6mvaros,o,,C__. 48.50 5887 4861 5889 5840 5909_ '"__L--. . ...... FORMATION TEST DATA '"""'"'"'°"'/" FLUID SAMPLE E Date 4-5-75 Number 607930 Sampler Pressure .P.S.I.G. ot Surface Kind Halliburton Recovery: Cu, Ft. Gas of Job HOOK WALL Di, s. trict ANCHORAGE ...... cc. Oil CC. Water Tester BOWEN Witness GORDON .... cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY. NM..S Gravity .... ° APl @ °F. EQU I PM,,,E N T & H O L E DATA" Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. -. Recovery Water @ °F. ppm All Depths Measured From , , Recovery Mud~ @ Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size ......... Mud Pit Sample @ °F. ppm Drill Collar Length I.D. Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length I.D. Packer Depth(s) ,Ft. Mud Weight vis cp Depth Tester Valve Ft. ,,,, ,,, , ,, , TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of ,, Recovered Feet of Recovered Feet of ._ < Recovered Feet of Recovered Feet of Remarks , ..... FOURTH GAUGE Gouge No. 2859 Gauge No. Gauge No. " TEMPERATURE TIME _." Depth: 10,790' Ft. Depth: Ft. Depth: Ft. ,,, , , , 48 Hour Clock Hour Clock Hour Clock Tool AjVL ., Est. °F. Blanked Off YES Blanked Off Blanked Off Opened P.M. '"" '" Opened A.M. Actual °F. Pressures Pressures Pressures Bypass P.M. _. Field Office Field Office Field Office Reported Comp~J'i~d i'~.itiol Hydrostatic 5829 5894 Minutes Minutes ,..~o Initial 250 :Z.r. Flow ..... iZ~. Final 300 _ 331 , , ,, Closed in 501 2 5042 ~'o Initial c o Flow .... u°'c Final Closed in Initial ............ ~ F~ow ,, ~_,~ , , Final ClOSed in Final Hydrostatic 5829 '" 5894 ............. FORMATION TEST DATA '"'"""'"'°"'/" G~ugeNo. 2856 Depth 10 757' ClockNo. 8105 48 hour No. 607930 First I First Second Second J m~ird Third Flow Peric~~ Closed In Pressure Flow Period Closed In PressureI Flow Period Closed In Pressure ,, , T~me Dell., P'SIG Time Dell' ,nL~ PSIG Time Defl. PSIG Time Deli. t~L~ ~SIG Time Defl. PSIG Time Defl. '-~-~ P$'G Temp. Log Temp. Temp. Log Temp. Temp. Log Temp. I 1.000" Corr. .000" (~ Corr. .000" Corr. .000" i Corr. .000" Corr. .000" ~ Corr. o .OOd ']' 1~93 .000 316 ] 1085 470* .0-226 681'* 2 ('.lll0 462C) .0504 22z~6 3 .21-19 26~3 .0 7¥2- 41-93 I 4 .31 53 282 .1 06'0 5005 ............. .S .4186i 299 .1.~-9 ...... 50TO ~ .522-0 316 "'166-7 501-5 . .... ,,, 8 ..... .21 ~ 3 502 0 , , , ~ .... .24 51 5-0-2'0 ,, ]o .2~7-29 5-0-20 ] II .3b-07 5-02-0 ~ 2] .52-86 5-02-0 '" .35'6'4 5-0'2-0 ~4 '. 3g-4--2 .... 5-020 ..... !5] , ..... .4i'20 502-5 [ .. , . . Gauge No. 2858 ' Depth 10,761 ' . Clock No. 8739 hour 24 , ,, , ,,, ~ .2115 480* .0-4'40 6-6-8** 2 (.2170 468C) .0§-83 21-50 3 .412;j 276 t .1-B-~-5 4'08-4 - I 4! 6~42] 291 .2~-7 [5012 1 5j .81561 305 .~-09 , 502-0 ,,)[ ~t 1.0170i 320 .31~1 5-0-2'2 71t .3~93 ....5-025 8 .42-35 5027 ~ .47~7 I 5027 ~o I 53!9I 503-0 ]]l i .5862 5030 ., ~21! .6404 5030 _ 131 .6946 '5030 [ ]4 ! .7488 5030 I I 151 ~ .8030 5032~ I ._~,od~g l.te~o~ 60 JI ' 16 ~ .I , Minutes__ REMARKS: * INTERVAL = 63" MINUIES. ** INTERVAL : 13 ] INUTES.q C : CHUKb CHANIjI-. , , _ SPECIAL PRESSURE DATA Ticket 607930 Gauge No. 2857 Depth ,,, 10,786' Clock No. 13420 24 hour No. First First Second Second 'Pnird Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period .... ~los~,ed In pFe, ssure ............. Time D~fl. PSIG Time Deft. t -lc ~ PSIG Time Defl, PSIG Time Dell. t JI- ~ ~SIG Time Deft. PSIG Time Deft. Temp. Log Temp. Temp. Log Temp. Temp. Log t + {? PS;G Temp. .000" Corr. .O00" ~ Corr. .O00" Corr. .O00" ~ Corr. ,O00" Corr. .000" ~ Corr. 0 .000 1540 .000 332 'f .2'TT7---E07* ' . 0z$-38 658** 2 (.2200 48-8C) .0978 2090 -3 ' 4T3-2 290 ..... 15T7 418'4 ,~ .61 48 30-4 .205'-6 5032 s .8164 31"7.- .2S.g~, 5037 a 1.O180 332 .3i-3-5 50-~9 71 .3675 5b-44 .... 8 .42-1-4- 5044 9~ .4753 5047 ~o ....... .5-2'9'3 5047 ,, ]1 .5882 " 56-47 ~2 .6372 5047 t3 : .6-gll 5047 .... ~4 .7:450 5047 ..... 15 · 79-90 5~49 ....... Gauge No. 2859 Depth 10,790' Clock No. 10054 hour 48 Oi .000 i 1415 .000 331 I ~j 1-o651 49'6* .0-22'0- 7~-4'* ~i( ll201 48'1C) .0491 21'~2 31 2078---2-8-6 .076.1 4i~32 '. ,~i .3092 3-~3 1032 5025 61 .5120' 331 .1574 50-_32, 71 .1844 5_0__3_5 8i .2115 t 5037 ... 9! '" 2386] - ,, I i I ~ol .2656 5040 _. ,Ii I i 29_27 50_.40 i ' i ,3198 5040I I _ 13t 3469 5040 ,,,~I t I! ,3739 5040 :t i _ Is~ .! :I .4010 ! 5042 ' I , I ,, -- RE,~AP, KS: * INTERVAL = 63 MINUTES. ** INTERVAL = 13 MINUTES. C = CHOKE CHANGE. SPECIAL PRESSURE DATA Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIF Valve ................... Dual CIP .Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case ... 2..B.T..'.S ..... Hydraulic Jar ........ B I G..JOHN... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly .... R.T.T$. - .5½!'..20# Distributor Pecker Assembly ................... Flush Joint Anchor .... 2.7/8".. D...P, Pressure Equalizing Tube 2 B.T.'S Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ .o Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth O.D. I.O. .-~ LENGTH 3.75" 1.75" 2.80' - 3½" 2.764" 10,069' 2 3/8"TUB 1.995" 675' 3.88" .87" 64.97' 3.90" .62" · 3.87" 3.00" 59.20" .. 3.90" 1 . 25" 60.00" 3.88" .75" 30.32' 4.40" 1.92" 54.67" · 2 7/8" I 7/8" 105.24' 3.87" 3.00" 48.34' DEPTH 10,749' 10,757' 10,761' 10, 775' IrORM II~/.RI--I'I~INYED IN U.I~.,A, EQUIPMENT DATA i iii ii i iiiii i i L U I D S^M P'L E ~r A Dote 4-3-75 N,,,ber 607929 ,Sampler Pressure .P~l.~.'at S~ace Kind Halli~ , ,r .* ,~u~ ,r, · R~,e~: Cu. Ft. ~ ~*f. J~. ,H00Ki WALL TEST Distri~ ANCHORAGE~ c~. Oil ................. : T~ MR BOWEN wi~ MR 'GORDON ~ C~. W~ · ..... ., , · , ,, C~. ~ Drilli~ ....... T~t~a~ .. ~ ~mcmr KEHAI DRILLING COHPANY' PW ~vi~ ~ rerO! ~ 'F~' ~ EQUIPMmENT & HOLE DATA ~,~ ~ ~.,, . ~s/Oil Ratio ~, ff./~l. Faction Tested ~i~" CHLORIDE , Election · 151 ' K.B. Ft. ~T~T , NetP~cfivelnte~ol 10866' - 10876' F~. R~ove~ Water m m ~ 'F. ~ Ail ~pths M~sured From Kel 1,y Bushing , R~ve~ Mud ,~r ~ . . *F. ~ ~ TOtal ~epth 11005' Ft. R~e~ Mud Filtrate ~ 'F. ~m Main Hole/Casing Size 75/8" Casing- 5l/2"20~Li:ler Mud Pit ~mple ~ 'F. , P~ ~ Length 706' ED. 2,764" Tubing , . - , Mud Pit Som~le Fil~ ~' ~ .... 'F. - ~ :'Drill"Pi.~ L~.~th ]0069' ~.D. 1.995" Packer Depm(s) 1 0806 m.. Ft. Mud Weight 'vis ~ ~pth T~ter Volvo 10780' Ft, ~ ,, ~ ,,, ~, · .. , ~PE ~~ ~pth ~Ck Surface ~om Recovered ~ 946~o~ Drilling flUimd with some gas cut mud. . ~ Recovered F~of · ] , , , , R~over~ ~of ~ m , . - , , , ~ ,, ~,~ Pressured up w~th ~as to 1000 psi. Opened tool for a 425 m~nute f~r~t ..... . flow period, bled off cushion 1/4" choke. Cushion off. Had a l~ht steady blow decreasin~ to a very light steady.blow w~th ~as. Closed tool for a 245 . minute ~nitial closed ~n pressure period. Reversed ou~. Drill~n~ fluid 632 , , , - ~ump strokes. ..... ~, ~o. 2956 ' ~ 2a58 ~o. 2857 TmPE~mRE TI~E ~_ 0~m: 10788 Ft. Depth: 10792 Ft. Depth: 10817 ~". 48 H~rCl~k 24 HourCmock 24HourCl~k T~I 4-3-75 A.M. , .... Est. 'Fi Blank~f 119 r m ,Blanked Off N0 BlonkedOff Yes Opened 11 '20 P.M. ,, I 10825' · .,.i. Opened 4.4.75~.~. Actual t 7~TF. pressures Pressures Procures Bypass 1C ' 30 P'M' ~ Fie~ Office Field Office Field Office Reported Computed Initial Hyd~stotic '5923 5968 5911- 5946 5938 5963 Minutes ~inute, m'' ~.~ ~'~ 97 1034 98 1182 99 1261 . ~7 117 98 96 99 111 425 Ctosed in 827 839 834 818 816 834 245 ., ~, ~ ' ~),, , , , , ~ :Flow .... Initial' ' ' Cl~ in Finoi Hydrostatic J, " 5923 5902 5911 5879 5938 5900 . m ~ FORMATION TEST DATA LITTLI'I Ill?! lam 1/74 · FLUID SAMPLE DA . A Ticket Date 4-3-75 Number · 607929 Sampler Pressure , .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job tt00K Id^LL TEST District .... ¢c. Oil ~:. Water T~te.~.... MR o BOWEN Witness MR o, GORD0~, ¢¢. Mini -_ .l~rilling TOt. Liquid cc. ContractorKE~lAI DRILLING C0r. IPAr4Y PW _ __,G,ovi*_ -^p~ 'F. i . .-~qUlPM~'Nr &. HOUE D'X,T,. ^. · Gas/Oil Ratio cu. ftJbbl. '~:ormation Tested ........ .. . RESiSTiViTY. CHLORIDE Elevation Ft. CONTENT ....... Net Productive Interval Ft. , RecoverY Water __ @ 'F. ppm All Depths Measured From, RecoverY Mud @ *F. ppm Total Depth Ft. Recovery Mud Filtrate (~ ,,,,, ,'F' ppm Main Hale/Casing Size ,,, I Mud Pit Sample __ @ °F. ppm Drill Collar Length I.D,, Mud Pit Sample Filtrate (~) CF. ~~ppm Drill Pipe Length I.D. Packer Depth(s) Ft. Mud Weight , ~ vis , cp ',iDep,t,,h T, ester Valve .... Ft. TYPE AMOUNT Depth Back Surface Bottom ' Cushion -' Ft. Pres. Valve Choke Choke .... ,, . , Recovered Feet .of' ............. . . ,, · Recovered F~t of .................. Recovered Feet of ............. · ..... . . . · Recovered Feet of - .......... RecovenKI Feet of · ,, ~ . Remarks ..... · . , ,, · ........ , ~. ~ ..... ,, , ................... FOURIH ¢^IJGE: ~ , ,, ,, ~, , , ,, Gauge No. 2}359 Gauge No. ~uge 'No. TEMPERATURE TIME Depth: 1 08211F,t. Depth: , , Ft. Depth: . , Ft. , , 48 Hour Clock Hour Clock Hour ~,ock Est.- .F..,"B~o~ke~ o{,#,es , ~l~,.n~e~.O' .... qgk'e~.9" ..O~ened P.U. Opened A.M. Bypass ~Fo P.M. Pressures · ',c;ua, , , Fressures , rressur, es , , Field Office Field office, , Field Office Reported Comp'~ted Initial Hydrostatic b~)// ~D~/~ .. -- Minutes Minutes . .. · .'. initial 100 '1336 I~ o Flow ....... ~.,,-~ ~:~ni, i 100 118 ~. ~,,. ..... Oo,aih "852 .... 835 ..... ......... Initial .. Flow. FinaI Close~l iA' ..... .. , ~.~ Initial -~"c Flow, Final ~-~. _ Closed tn ......... ~inol H~lrost~tic '59'77 5903............ .. , fO~# IIh#I--P#INTED IN U.l.&. :nPMATltqN TEST DATA .,..,....,,,,,,o.,/,, 2 Drill Pipe or Tubing ................ "D 75" Reve~ing S~...Z..~.~ .... ,p... - 3. . 1,75" Water Cushion Valve ................ Drill Pipe .3. :i/.2'.'. IF. ............. Drill Collars 2.3/.8!'..T. ubing ...... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................. 3.50" 2.375" 3.88" .3.90" 2.764" 1. 995" Multiple CIP Sampler ............... Extension Joint .................... AP R.nning Ca. ....(Z) ........... 3.87" 3.87" 3.00" 1.25" .75" 1.92" · 1 7/8" 3.00" Hydraulic Jar .. B.ig .jOhn ......... 3.90" VR Safety Joint .................. Pressure Equalizing Crossover ......... 3.88" 4'. 40" Packer Assembly. RTT.Ss..1./2..2.O~/.. Distributor ........................ Packer Assembly ................... .7 8" .... ~~~r ,2 ./ .... D..P,.P.erf. 2 7/8" Pressure Equalizing Tube ............ Blanked off B.T. Case ,3.87" ~'~, ~C)ff B.T. Running Case 2.7./SDP 3.87" Blanked Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ ' Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ................ ....... Flush Joint Anchor ................... Blanked-Off B.T. Running Case ........ Total Depth ....................... i r--'A1 ! I r-N I ~[ r"' & i'"1"r'N A "1" A TICKET NO. 2,80' 10069 ' 706' §4.97" 59,20" 60.00" , 30.32'' · · 54.67" 105.24" 48.34" DEPTH 10780' 10788' 10792' 10806 ' 10817' 10821' 11005'__ Form ~o. P--.4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT[EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS WI~LL WELL OTHER NAME OF OPERATOR Standard Oil Company of California ~i'AbDRESSOFO~ERATOR P.O. Box 7-839 Anchorage, Alaska WOI 4LOCA~O~ OF'WELL 579' North and 620' East from the Southwest corner of SeCtion 3; T7N, R-9W SB & M AP1 NU'MERICAL CODE 50-133-20268 LEASE DESIGNA~ON A%'D SEHIAL NO. A-028997 IF INDIA]~ ALOTTEE OR TRIBE NAME Soldotna Creek 9 WELL NO eCU 44-4 i0 FLF, LD AND POOL. OR WILDCAT =Swanson River - Hemlock n s~c. T.. R. ~ (nO'SM HO~ SUBMIT IN DUPLICATE Sec. 4; T-7N, R-9W SB & M 74-66 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CENIENTING JOBS INCLUDING DEPTH SET A/Xq) VOLLrNIES USED. PERFORATIONS. TESTS ~tNq) P~ESULTS FISHING JOB~ JLrNK LN HOLE AND SIDE-TP~ACKED HOLE AND A.NY OTHER SIGNIFICANT CI-IA~TG~ IN HOL~ C~ONDITIONS March, 1975 5 '~'~ ? Regained circulation and controlled water flow with 98 pcf mud treated/~th lost circulation materials. Drilled 9 7/8" hole from 10,020' to 10,6~4'./Ran Schlumberger DIL, and CNFD logs. Cemented 7 5/8", 26.4, 29.7, 33.7#, P-110, ~'~0~, and N-80 casing at 10,585' with 740 sacks of Class "G" cement. Unable to open st~-~ collar at 7926'. Reinstalled Class III BOPE and tested OK under 5000 psi. Drilled out cement from 6890' to 8053'. Perforated 7 5/8" casing at 8033' with four 1/2" jet holes and cemented 7 5/8" casing through holes at 8033' with 1500 sacks of Class G cement. Drilled out cement from 7957' to 8123'. Pressure tested and holes at 8033' broke down under 1900 psi. Squeezed holes at 8033' with 72 sacks Class "G" cement under 7000 psi final pressure. ;Drilled out cement from 7809' to 9235'. Pressure tested 7 5/8" casing OK to 9235' under 2500 psi. Drilled out cement from 9235' to 10,540'. Ran cement bond log. Drilled out cement from 10,540' to 10,595', cleaned out to 10,604' and drilled 6 5/8" hole to 11,031'. Ran Schlumberger DIL, CNFD, and BHCS logs. DIV:$10N C,I: OiL AH~ ~A§ AI'4CHOR^G "~4' I hereby certify that t'he f°reg°tng is tru~~~ ........ '"'AA .,GNED R. M. McKinlev ~t-://,'~~Tn~ Area Enai~eer _ NOTE --Report on this form is reguired for .~ calendar month~ regardless of the status of al)orations, and must oil and gas conserveS/on Committee by the 15th of the sueceeding month, u~let~ otherwiss d~r~ctSd. TRANSMITTAL ANL ACKNOWLEDGEMENT OF RECEIPT OF M~ ~RIAL - (ALASKA) DEPT.: PLACE: FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY · HISTORY LOG 2" 5" ! ~ Io--Y ~60 ILIAT~-P ~I~N_6L !~lS 4~P~ ~- ~t Il I! S N 0 HER SIDE, THIS SHE'~T TRANSMITTAL A~CKNOWLEDGEMENT OF RECEIPT OF M,--~RIAL - (ALASKA) ,. ~. Mr. ?. IR. Marshall TO: .~, ~"tate ot Ataska -~ Division of Oil & Gas DEPT.: "':] ~ 'Porcupine Drive ~ ~chorage, Ata~ka 995~ PLACE: t .... FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" 5" ! I o0, o/C o/< RECEIVED BY ARRS OA/~l REM OTHER .,. SI-DE, T"iS sHEeT BY TRANSMITT~3~ AND ACKNOWLEDGE}~NT OF RECEIPT OF MATERIAL - (.ALASKA) i' Mr. T. R, Marshall T0: ~'1 State of NaSka Diviston of O!! & Gas DEPT.: 3001 Porcupine'Drive Anchorage, Alaska 99504 PLACE: TRE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. ClIECKAND ADVISE IMMEDIATELY. SEPIA BLUELiNE ~JNS INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREHOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w/caliper BOREHOLE COP~. SONIC w/gamma BOREHOLE TELEVIEWER CONTINUOUS DIPMETER - High Res. CDM - POLYWOG PLOT CEMENT BOND LOG CASING COLLARLOG - Perf. Rec. COMPENSATED FORMATION DEN. CQMPENSATED NEUTRON FORMATION ANALYSIS LOG FORMATION DENSITY LOG F F FORMATION TESTER FORMATION FACTOR F F GAMMA RA¥ GAFR42% RAY - NEUTRON GAMMA RAY COLLAR LOG MICRO LOG MICROLATEROLOG* MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA COMPARISON PLOT SANDSTONE ANALYSIS SARABAN SIDEWALL NEUTRON POROSITY SONIC TEMPERATU~LOG I I I00 200 COMPLETION REPORT DIRECTIONAL SURVEY CORE DATA SARABAND TABULAR LISTING _-- ," ,/ Received and checked by: / .~~ .. CHEMICAL & £OLOGICAL LABORATO}IIF. ' OF ALASKA. I C. TELEPHONE (907) 279-4014 P.O. BOX 4-1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA 99509 t~ATER ANALYSIS P.~ORT oPm~.~.?oR Standard 0il Company.,,of. Califorj~¥.. Apri_l 10,_ 1975 ~m NO~._2880-1 ~LL No. SCU 44-4 L~A~ZON . ~ImLD' . .S'wA'nson River ~O~MATION Hemloc~"[0' ._._ co~ ~T~AvA~ 10856 - 876 feet ~ATm Alaska ~AM~ ~AO~52 feet above RTTS ~.~k~.~s & coac~-uszoNs: Cloudy brown water, clear filtrate. ,, Sample taken from production test with RTTS at 10779 f6et. Believe this sample to be spent acid water. ~ . .- 8115 ~ ..... 169 · ~ , 166 ~ : 100 353.00 s.~.~ 40 0.83 , 4.33 ~ .. 13000 366.60 8.28 c.~.~t~ .. -- _. --- 8..,,22 _ ~i~.~b~.~ 390 6:40"~ ?~.~ C.~om .... 373.83_ I ii ii iiiJ i II L J I J i IJt I I T~ ~ ~ ~/1 ..... .,21782 .... ~aci ~.~.~m. ~l ....... 21 767 4.5 Olmw~Cl pH .......... Total Anlo~ . . . . .373.83 i i i i ~----- - - ~_ · ......... 0.325 0.32 Ha WATCH ANALYSIS PATTR,',.'IN MEQ l~r Uuit Cl 50 Na HCO~ 5 ' Ca SO,~ 5 Mg CO~ 5 lie (Ns ~ h,t ~ ~ b,dud,q N~. Ir. ~d Li) CI HCO~ COs CHEMICAL & L EO{..OGJCAL LABORATORIES OF ALASKA,, NC. TELEPHONE (907) 279-4014 RO. BOX 4-1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA 99509 WATER ANALYSIS REPORT oP]~?O~ Standard 0il Company of Californ~_Ap~ri] 22, 1975 z~ NO. 2880-2 w~Lz. No- SCU 44-4 . LOC~T~O~ .......... ~z~ ' Swanson River ....... FORMATION. Hemlock i0" _ .... cotmTr ..... mTE~VAT~ i0856''-L ~76 feet .... 8TAT~ Alaska .......... SAMPLE ~o~_'.i.' 2048 feet ab'~-e ~RTTS .... -- ]~m]~.~s & CONCLT~ZO~S: . Cloudy reddish brown water, clear filtrate. Sample taken 'from produc l~tes~ wi~h-R~TS'-at Believe this sample to be spent acid water. _ 8omm= . . · . . . 7600 330,75 ~ ..... . 579 ....... 14 ..82, ...... 2._15_ ~ ..... 236 __ · . 19.40 ~ c~ 367.1 2' ~ i i! .ii ii ~ ~ i LJL I I II ?o~ ~ ~ ~/t ..... 21483 ]~mCl ~m~ =~/x .... 2t704 Ol~d pH .......... ~ ~' ~41]1' ~ ...... 25 0.52 ~ ....... ]3ooo ~ __ Bk~lxmat~ ..... 0 .... H~o~ ..... --- - -- _- --- .Z. - WATF~R ANALysIS PATTR:;.'~t MEQ per Ua~t 8,tmple above descn'bed Ha. Mg C~ 50 HCO= 5 ~¢ S04 5 CO= 5 Fe · . CHEMICAL & GEOLOGICAL LABOR^TORJES OF ALASKA, NC. · TELEPHONE (907) 279.-4014 P.O. BOX 4-.1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA 99509 WATER ANALYSIS REPORT op~,~AToz~.Standard 0il Company of Californi~?~ April 22: 1975.. w~zz Imo... SCU,, 44r4, LOCATION ,, ~~ Swanson River ~O~ATZON- Metal rick ! O , CO~ ....... ~T~RVAT- 10RR6 - R76 f~f __. _ - . _ .- BTAT~ '~laska" ' SAMPLZ FRO~ I ]Lm~S ~ ¢O,¢LUSZONS, _ Cloudy,reddish brown water, clear filtrate Sample takeh f~om production test with RTT~ at 10779 feet. "' B61'~eve this sample to be spent acid water. amtim,a . .. 16670 725.11 f{~tmm ...... 36 ..... 0.75. Pou,.~,m ..... 579 . 14.82 Ch~o~k~ .. 27000 _ 761.__q.0... C4kt=m ...... 40 ..... 2.-'0-0-- C,~~ ...... 0 0 ~L~ -'- 246" ] ..... 20.22 ' ~ C~a, .... 762.15_ r~ ~ .... . .... 762,1.5 _ ............ ii 114 .,. ,. i i 1_-- · ,-- : ; : .... ; :;zc ' ~ Tot,d ~ ,,oU,b, n,~l ..... ---- ,, . 8~.fl,: ,-,~um~ ~ a~.F.: ~,c.~ ~~ m~'~ ..... .."44797. . '- . 0~-~; . O. 1 73 ..... _ ~.~ ob,,,~l pH .......... 4.1 ~ 0.1 68 ~ j~_., , _ ts. ,t, m m ,.~ . - -- W, ikT~R ANALYSlB PATTF.?~N C! 50 Na HCO, 5 Ca 5 Mg C05 5 Fe MOTI{: M~t=l~~ p~ ~ {ifeq/i= ]:f~i~Fr'nm oquJvth,eU 1~, LIMr Cl HCO~ SO4 CO~ ': CHEMICAL & GEOLOGICAL LAGORATOR]ES OF. ALASKA, INC. TELEPHONE (907) 279,.4014 RO, BOX 4-1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA 99509 WATER ANALYSIS ~EPORT OPZ~TO~ Standard 0il Compa..ny of Californ~k?m April 22, 1975 I~,m No 288_ .0-4 ~r~LL NO., SCU 44-4 .,, L~ATION ....... - ~Z=L~ ' Swanson River ~O~TZON.. .'~66~°ck ~'1 0 _ _. CO~ . Z~TERVAT- 10856 - 876 -f6'6t BTATm Alaska ..... SA~P~ F~O~_ 1240 ~eet-abo~-RTTS I~~IB & CONCLUSlONSt Cloudy, reddish orange water, cl ear filtrate. Sample t.a. ken from production test with RTTS at 1077-9 fee-'~=:-. .............. B. el ieve ,this sample_to be.spe_nt..acid wa.te:r.. .... . · ! ! , , , I, I] , aoatm~ -.'---. 5530 ... 240.55 ~ ..... 635 16.26 · ~ ...... 52 2.59 ~ ..... 283 ... 23;'~ _ s~t~, ...... 32 0.67 ~ -. . ! 0000 __ 282-. o_ .Q_ B~m. ~ ....... T ra_c e .. - - - : _ H~~ ...... , _.__ To~d ~ ~ ~ ..... 1 6532 ' ~,~796~ NaCl e~m~m, men ....... , , _ 4.4 O~ pH ........... Ol~a~i .... 0.395 ANALYSIS CHEMICAL & GEOLOGICAL LABORATORIES TELEPHONE (907) 279-4014. P.O. BOX 4-1 276 ANCHORAGE, ALASKA 99509 OF ALASKA, iNC. 2603 ARCTIC BLVD. WATER ANALYSIS REPORT opzl~?o~,,,Standard 0il Company., of Cal iforni~A?m April 22. 1975 l~tm 1~O. 2.880-5 WIILL Ito_,SCU 44-4 LO~A?ION FrmLD Swanson RiVer PORMATZON Hemlock_ 10 ¢olrl~IT ................. n~?~RVAL____]_Q856 - _876 feet.. S?ATm A1 aska ............... sAl~P~z ~o~_~e_t abov_!~_RT_TS - _ I~MA,I~S & CONCLU$IONB: Mudj .dark,quebracho filtrate. Sample taken from production test with RTTS at 10779 feet. Believe this sample to be mud filtrate. I I Il r I I II I Illl I I I I I I I I I I lJl-I - I -- I ~ . ' ..... 245~ Po~ ....... 415 ~ ..... Trace ._~ 125Q 3100 207 26.00 0,80 .... .... 3.39 ?oma ~ ~ ~ltI ..... 7348 'NaCS ~m,~ m~Y: ......... 6683 Ob~m,,,~d pR .......... 9.5 8p~:ifl,: r, etmaz~ @ ~'F.: Obeeswed O. 958 0 .,.9...6 ~m~e above deeen'bed MEQ ~ U~it · .- Na Cl 20 Na Ca HCO~ 2 'Ca Fo CO s 2 Fe C1 HCOs SO.,, COj · . CHEMICAL & GEOLOG]CAL LABORATORIES OF ALASKA, NC. TELEPHONE (907)279-40]4 RO. BOX 4-1276 2603 ARCTIC BLVD. ANCHORAGE, ALASKA 99509 WATER ANALYSIS REPORT oP~t?o~ Standard Oil Company of Califorr~?mApril 22, 1975 ~m NO..28.,80-6 V,r~LL I~O- SCU 44-4 . . .. L~ATZON . ...... ~. ~Z~D,..' Swanson River .... ~O~ATZON. He~do'dk 10 CO~ ~T~Va~- 1'08-5G 876 'f~et ' ' ~A~ Alaska , . aaa~L~ F~o~_.432 fee[' f~0m R~TS -"- -- - ~.~.~S&CONChU~O~S--.-. Mud, .clear light yellow filtrate, Sample taken from production test with RTTS. .... Be.l.jeve this sagple to be predominantly'~o'rh'lation water. i Il I I 311 Il ............ c~, ,,,, ~ .~vi ~ ...... , 5585 242.85 ~ ...... 635 . 16.26 · ~ ...... 205 _ 10.23 ~ ..... _ . . 4. . 0.33 ~ ~ $~ s~ ~ ~ m es 11 ---- ~ , , -- "~ -- ,, 8~t~m ...... 325 6.76 ~ .. 8500 239.70 ~~t, ...... 0 --- B~o~a~ ..... 141 5 23.21 i Il I Il I , I Il I 269 67 i i · i i i ?o~! ~ .... 269.67 _ Xm~l ~ ~ ,,~,1 ..... 15951 ~acl ,~~ ~,'1 .... ~ 5467 ' O~e~l pH ..... 7.7 Sp~ ~ @ ~'F.: Obeerve6 c~ 0.443 0.44 above dee~'b~ Nl WAT~:R ANALYSIS MEQ p~ Unit Cl 20 Na HCO, 2 '~ SO, 2 Mg CO, 2 Fe C1 SO~ CHEMICAL & GEOLOGICAL LABORATORIES TELEPHONE (907) 279-4014 RO. BOX 4-1276 ANCHORAGE, ALASKA 99509 OF ALASKA, iNC. 2603 ARCTIC 6LVD. WATER ANALYSIS REPORT OPBmA?O~_,S,.tandard 0il Company of Californi~&?m April ,22, 1.,975 LAm NO-_~2880-7 VCBLL 1~0.,, SCU 44-4, , , LOCATION .... - I~IBLD Swanson River I~ORMATION Hemlock l0 ~ . CO~ m m mTRRVAT- 10856 - 876 feet ~A?R, Al,,aska ........ ~MPLE ~RO~_ 28 feet from RTTS RBJIAR~ & CONCLUJlOmW0, Mud, dark quebracho filtrate. ................ SamDl.e,,,,,taken from production test with RTTS. : Bel. i~w this, sample to be mud filtrate. 8edbm ...... 2670 PoUmhm . 228 C, kh= l ~-"-- 116.16 5.84 0.80 ~ ~ mo~t 8ulbt. ...... 400 8.32 Cbk,rao -. ' ' 800 ..... .22.56 - Ca~boem~ -. 2520 83.92 H2.lrozide ..... 136 ' 8.0~' ' . _ . 122 80 ~ Caeeeo- - - - 122 80 ~o~ Ankx~ ..... · · j · ~ -- i ..... m m i Total disma~ oemS, mm/1 ..... 6770 Specific r,dm~ ~.~.~.~ N~I ~ ~1 ....... . .... 7224 o~ 0.8~1 ~m O~pH ...... . . . . ~ ,12,~,5 ~ .... 0-90 ~m -. 8amplo above deocribed MEQ per M~ CI 50 Na HCO, 5 Ca SO~ 5 Mg CO · 5 F'e C1 HC03 SO~ per L{Mr Form No. P--4 REV. 9-30-$7 STATE OF: ALASKA SUBMIT IN DEPLIC~TE O~L AND GAS CoNSERVATIO'N COMMITTEE MONTHLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS 2. ~E oF O.P~TOR Standard 0il Company of California, WOI 3, ADDRESSOFOPER2%TOR P. O. BOX 7-839, Anchorage, Alaska 99510 4. LOCA~ON O~ W~LL 579' North and 620' East from the Southwest corner of Section 3; T-7N, R-9W, SB&M ~'~, 50-133-20268 6. LE4%SE DESIGNATION AX'D SERIAL NO. A-028997 7. IF INDIAN, ALOTTEE OR TRIBE 8. I/NIT,FAi~M OR LEASE NAAIE Soldotna Creek 9. WELL NO. SCU 44-4 10. FIELD A-ND POOL, OR WILDCAT Swanson River - Hemlock 11. SEC., T., R., M.. (BO~FOM HOL3~ OBJ~CTrVE) Sec. 4; T-7n, R-9W SB&M 1~.. PEI:UViIT NO. , 74-66 13. 'i{EPOiqT TOTAL D~IPTH AT END OF MONTI-I, CHANGES IN HOLE SI~E, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET A_NI) VOLLrNiES USED, PEi~FO.I{ATIONS, X-ESTS A/VD RESULTS, FtSttING JOt~S, JUI~K IN HOLE A-ND SIDE-/q~ACKED HOLE AND A/XIY OTHER SIGNIFICA/XIT CHAN-~ES IN I-IOL~ CONDITIONS. February 1975 Drilled 9 7/8" hole from 6624' - 10,020'. Set dyna drills No's. 1, 2, and 3 at 8029', 8207', and 8517' respectively. While pulling out. of hole at 10,020' well commenced to flow water cutting mud weight from 101 to 94 pcf. Conditioned mud to 101 pcf pulled out of hole. Cleaned out to 4457 and hole commenced taking fluid. Mixing mud with lose circulation materials. 14. I hereby certify that the foregoing is t NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. N;~B~E OF O~]~{ATOR Standard 0il Company of Ca]ifornia o WOI , 3~ AD~'RESS OF OPEi~ATOR P. O. Box 7-839, Anchora0e. Alaska 9951 0 4. LOCATION O~ WELL 579' North and 620' East from the Southwest .~corner of Section 3: T7N, R9W, SB&M ~.APIN~{E~CAiLCODE 6. LEASEDESIG~ATIONA~DS~IALNO. A-028997 7. IF INDIAN, ALOTTEE OR TRIBE NASIE 8, LFNIT,FA3~%{ OR LEASE NA_%IE SCU 44-4 10. FIELD AND POOL. OR WILDCAT Swanson River - Hemlock ii. SEC., T., R.. M.. (BOT'FOM HOLE OBJECTIVE) Sec. 4: TTN~ Rg~ SB&M 12. PERlVIIT NO. 74-66 "13,' REP~)RT TOTAL DEPTH AT E, ND OF MONTH, CHA.NGES IN HOLE SI~E, CASING ANT) CE1ViENTING JOBS INCLUDING DEPTH SET A/XrD VOLUNIES USED, PERFORATIONS, TESTS AlXrD I{ESULTS, FISHING JOB~, JLrNK IN HOLE A.ND SIDE-TI~ACKED HOLE AND A/WY OTHEI% SIGNIFICANT ~,~ES IN HOI~ CONDITIONS. JANUARY 1975 commenced operations January 11, 1975. Drilled 15" hole from 78'"to 3370'. Cemented 10 3/4" casing at.3357' with 2150 sacks of Class G cement. Cement returns to surface. Install class III BOPE and tested ok under 5000 psig. Drilled out cement from 3316' to 3357' and cleaned out to 3370. Drilled 9 7/8" hole from 3370' ::to 6624,. 14. I hereby certify that the foregoing is ,,, /,~/F, ~ SrGNED R. M. McKinle' Area Enqineer nA',',~~////I. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, anO must be filecl in with the Division o[ Mines & Minerals by the 15th o[ the succeedin9 month, un[ess otherwise directed. : ~-~ .~ .- ~ - .. . ,. , ~ ....... . ... · . ..* ... . -*... · . . ... ~ .-· . . .. ~ .... . . ~'?'?*~:';~.~j:~:.-.;.'.'.. ~.L:~:;_ .~CT.O. _LOT,... F,~ ~,~~_,~- ~..~ ",.' ;.~'. ,~-~.' ' "';:~';:.'/4-' ~ :' '. '.. - . . ?;';'-,:.-, -~=' '- ...... ~ATION, ~ND~~ ~CR~. HAT . . ' DERRICI . ~~ ~ L T £ R II A T E O R S U R V E Y E D L 0 C A T I 0.11 I)E~ I G;qlAT i ON ' , LOP, AT I0# CO01tD I NATES ' ' - HOVE: , , , · , ; , _ ,. , , OF OIL AND !'&,: C:otlPUTiO CHECKED BY ~ SIN Z= '-'CO1 iTA?tON D£1rLECTION ' AZIMUTH DIITANC1 ' COLINE lINE Ill, I~, ~. W. (=O-OR DINATEll d k ....... De.~r 27~ 1974 So1~ Creek SCU 44-4 ~ard Oil C~y d Call.mia P.:O. ac= ?-e'39 ~ra~e, Alaska 99510 ~1~ is the ~~ ~ii~t~ £o~ permit to ~rtll the o~fJ~, D~~~ ~ Fish ~olluti~ ~ ~ waters of' the State iS .~oh~i~d by AS 46, -03, ~clo 7 ~ ~. ~ati~a ~lga~ ~e~- ~~ ~le 18, A~~ ~tst~ti~ C~, ~ap~r 70) ~ bY ~ ~ral Wat~ ~lu~ ConSol ACt, as ~. ~~i~ of ~ ~r~nt of ~ir~tal Coronation. Burrell ..~ Alaska Oil and ~s Conservation Committee ~e. par~t o~ Fish: and ~, Habitat Section ~/o eno1. 'Depar~ o£ l~vi~o~ntal Conservat/on w/o encl. ~r~nt of ~~, Su~.~tsor, ~ ~w C~llance Divistm w/o eno1. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN (l~.ller mstructlot~ reverie side PERMIT TO DRILL OR DEEPEN .DEEPEN .F-I ZONB · DRILL I-] . WBL[, i q.! WELL ~ NAME OF OP~TOR California. WOI 3. ADDRESS (~F OPF_A%ATOI~ Mit I,?IPI,I r"] ~,O N lC APl #50-133-20268 8. ~ DW~IGNATION A~ID ~.tAL NO. A-028997 ?. IF INDIAN. AIJ.~-l-t~ OR TR/BE NAaM~ 8. UNIT, FARM OR LEASE NAblE Soldotna Creek 9. WELL NO. SCU 44-4 lO. XPIEX,~ AND POOL. OR WILDCAT --LOCATION Or WELL Atsurf,~ Approximately 580'N and 620'E of SW Section 3, T7N, R9W, SBM A~p.~o~p~d. zone Approximately 850'N and 500'W of SE ~,",i":';nn -4 T7?I. Rgw: SBM l~. DISTANCE IN MILKS AND D~RECTION FI~OM NEAREST TOWN OR POST OFFICE' '15 miles aoDroximatelv 14. I~OND INFORMATIO~ :- - _ TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LIN~ ~. IAI~ ~o nearest drig. unit. ii anN) 18. DISTANCE FROM PROPOSED TO NEAREST WELL DRILLING. COMPLETED, OR APPLIED FOR. FT. 21. ELEVATIONS (Show whether DF, RT, ~-R, etc.) - -- . ],,. ~,R6POS~ Dn:~' - I 11 r002 ' ' PROPOSED CASING AND CEMENTING PROGR~ corner come ,Swanson River I1. SEC.. T., R. M.. (BO~'rOM HOLE Oe~ECT~VE, Section 4, T7N, 12. Amount 17, NO, ACRES ASSIGNED TO THiS WELL ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START' December.20~ 1974 SIZE OF HOLE SIZE OF CASING VFEIGHT PER FOOT ~ GRADE SETTING DEPTH quantity 'of cement · · ~ i . , R9W, propo~'~ ' ~ / ~,~ ~t: "1 produCing well per attached program. . ~ .: ~:, : IN A~OVE SPAC'~ DESC?,/BE P'ROPOSL"D PRO~R.~M: If ~1 is to d~n 'give ~m on p~nt p~u~ive zo~ ~d P~ new p~u~lve ~ne. _1~$~1 IS ~ drill or a~n a~c%ionaily, give pe~ent ~' on s~bsu~a~ ~t~ ~d mea~d ~d ~ue ~ical gepL~. Give bio--ut preventer', p~ram. .~'=,. ~.~~~,~/ ' D,~ December 5, 1974 (~ s~ ~or S~te offi~ u~; CONDI~ONS OF APP~V~, IF A~: .. ] [ S*M~ *~ CO~ Cm~ .m~ [ MUD Leo - L~,~ / , , ,, , , d Area ~n~l~le~_~-" SEE TRANSMITTAL LETTER 50-13~-20268 APPROVAL DATE , ,, December 27, 1974 December 27, · Oha i rman *See Inslmcflo., On Reverse Side . ,,, 1974 · PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Swanson River ~ro~erty and Well:' Soldotna creek Unit 44'4 Surface Location: Approximately 580' north and 620' east of southwest corner of Section 3, T7N, Rgw, SB & M,~ Existing sur~face pad for SCU 14-3. "' Proposed Bottom Hole Location: Approximately 850' north and 500' west' of ~ 'i . Southeast corner of Section 4',T7N, Rgw, Elevation: 133.5'~G,L&;'-estimated 150'- K.B~ Blowout Prevention Considerations: 1. Potential Problems: A. Gas and Water Entries: Gas sands~may be·encountered at any -depth below the shoe of the surface casing. No gas or water entries were reported while drilling wells SCU 14-3 and SCU'43-4 with. 96-99 pcf mud. Caution should be exercised not to swab the hole on trips.. Gas and water entries can cause severe problems, and the mud system should be carefully monitored at all times. B. Lost Circulation: Circulation was-lost at 6567' in Well 43-4 while drilling with 96 pcf mud; in the'same well 100 bbls of mud were lost at 7315'. There are no reports of lost circulation in the other two nearby wells 14-3 and 34-4. However, lost cir- culation has occurred in other SRF wells while drilling the Hem- lock with +98 pcf mud. In SCU 44-4 casing will be cemented above the Hemlock zone before mud weight'is reduced to penetrate the interval. 'C. Precautions: Any kicks should be handled by our normal procedures. ' Drilling crews should be made aware of these methods. Care should be exercised at all times, but e~Decially not to hydraulic the formation and lose circulation while running in the hole nor swab the hole while pulling. An adequate supply of weight and lost circulation material should be at the well site at all times. 2. Maximum Anticipated Formation Pressure: 5100 psi at -10300' VSS datum (H10) 3~ Maximum Anticipated Surface Pressure: 3800 psig .. ~'--' -'~!' Proposal for- Well.: ~ Operations Pro~316'1 ..... -~,.Drilling Program Blowout Prevention' Equipment ' ,1, Class:'iI1 5000 psi on 10' 3/4" and. 7 5/8" casing. 2. .Install. and test per "Operating I~structions D-17." I -. 1.' Drive.18".--conductor pipe to +80~..or as.dee~.as, possible during rig up. .2. -Drill 15" hole to 3400'+. Maintain drilling fluid per the attached drilling fluid program. 3..~Cement 10 3/4",.-40.5#/foot, K-55, buttress casing at 3400'. ...a. Use-float-shoe and stab induplex collar one joint up. b. Lock bottom five joints of casing. c. ..Centralize the casing abovethe shoe. Cement.through the shoe in one stage.as.follows: 1) Use-sufficient Calss "G" cement premixed,with2.4% gel. by : .weight of.water to obtain cement returns to surface. Basis: ~ield of Class "G"~+ 2,4% gel by weight of water = 1.86 ft3/sk. ~ 2) If. cement returns are not received at the surface, do a top job. -e. '-'~:Have stage.collar on location in case lost circulation occurs -while drilling top hole. ~4. -Cut off 10 3/4',, 40.5#/ft., K-55, casing 'below .the top of the cellar ~.~ ~ '~' ..... tO allow the tbp flange of the tubing head to be above ~;~~1 .~~fter completion. Proposal for Well Operations PRO 316-1 Drilling~ Program ~ 5. Install 10" -5000 psi, '10.3/4", SOW casing head. Test welded lap to 2500 psi +. 6.. Install Class ii1, 10" -5000 psi,'-BOPE 'asper the attached BOPE design.~'' Test BOPE, kill line, blow line, and manifold to 2500 psi per "Operating Instructions D-17." 7.. Drill out the cement in the 10 3/4" casing..with a 9 7/8" bit to within 10' of the shoe. Pressure test the 10 3/4" casing to not over 2500 psi. If test is ok, drill out the 10'3/4" shoe.. 8. Drill a 9 7/8" hole to a true vertical depth of 10,450', estimated 10,574' MD, estimated top of the Hemlock sands as follows: _ a. Follow mud specifications per the attached mud program. b. Take single shot surveys to the estimated KOP at.a minimum of every 480'. Should conditions warrant, reduce the survey in- terval to every 240' or less. Always take a survey on a dull bit. C~ Beginning at approximately 7000', KOP, build 2°/100' to 19°. Lead well for a 10"+ right-hand turn,. Along course of N77"W section' is approximately 1148'. Target is the base of the Hemlock No. 8 sand at a location approximately 500' west and 850' north of the southeast corner of Section 4, T.7N, R.9W. 9. At effective depth, condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run the following Schlumberger logs: a~ Dual Induction - Laterolog from drilled depth to the shoe of the 10 3/4" casing. Use linear scale for the 2"=100' and logarithmic scale for the 5"=100'. Use 10+ MV SP scale and 0-50 ohm-meters for the linear resistivity scale. b. Have Sonic Log, and Compensated Neutron-Density Log on the location. 10. Drill ahead as indicated by log run to set 7 5/8" casing shoe at the top of the Hemlock (H-i). 11. Cement 7 5/8" casing at the top of the Hemlock as follows: a. Bottom 3520' 33.7# P-110 Buttress Next 1200' '33.7# S-95 Buttress ~~ ~ ~. ~ ~ ~ .~,lt~ Next 1900' 29.7# N-80 Buttress ~' Next 3874' 26.4# N-80 Buttress Top 80' 33.7# P-110 Buttress NOTE: For deeper TD add 26.4# N-80 buttress as required. Casing program based on pipe availability, which exceeds design criteria. Proposal for Well Operations PRO 316-1 Drilling Program ~- .... b.. Run differential fill-up shoe and collar. R%m stage collar at approximately 7900'.-- Have triplex shoe on the location in case it is necessary to set the 7 5/8' casing above the drilled depth. e. Centralize the bottom 700' and above and below the stage collar at 7900'. - -- . . .f. Cement in two stages using Class','G" Cement mixed with 2.1% gel · . by.weight.of water as follows: 1) Shoejob - Use sufficient cement-gel mix followed by 100 sacks of neat cement to reach 8700'~. 2) Stage collar - Use sufficient cement-gel mix through collar at 7900' to reach 4500'+. 12. Remove BOPE and land the 7 5/8" casing. Install a 10" -5000 psi bottom flange x 10"-~-5000 psi top flange tubing.head.' Test secondary packoff to 5000 psi.~-Install 10" -5000 psi BOPE' Test BOPE to 3000 psi per "Operating Instructions D-17." 13. Drill out cement and stage collar and clean out to within 10' of the 7 5/8" shoe. 14. Run Variable Density-Cement Bond Log from the effective depth to above the top of the cement from the stage collar job. 15. Based on CBL, squeeze for WSO above the Hemlock as required. 16. Pressure test the 7 5/8" casing to 3000 psi. 17. Condition mud weight to 74-76 pcf. (75 pcf mud. provides a hydrostatic pressure of 5442 psi at 10,574' MD versus 5175 psi est. reservoir pressure). 18. Drill a 6 5/8" hole to true vertical depth of 10,855' , estimated 11,002' MD. (Total depth is projected 50' below the base of the Hemlock 10 sand). 19. Condition hole for logs. Take a 1/2 gallon sample of mud prior to ....... pulling for logs. Run and tape the following Schlumberger logs: ~ it~' ~" - a. Dual Induction -. Laterolog from TD to the shoe of the 7 5/8" ~ casing.-Use same scales as before. b Sp-BHC Sonic from TD to the shoe of the 7 5/8" casing. . Proposal for Well Operations PRO 316-1 Drilling Program ..... c. ' Microlog from TD to the shoe of the 7 5/8" casing. d. Compensated Neutron-Density Log. 20. Condition hole for 5 1/2", 20'9, N-80 LT&C liner. . - 21. Cement approximately 630' of-5 1/2", 20#, N-80 LT & C at TD as · '~ follOws: - a. Run float shoe and float collar..~ Do not use centralizers 'b. Allow for approximately '200' of special clearance P-110 couplings .... in'lap below-, the liner hanger. :.~,- ..... c. .. Use. sufficient Class "G" cement treated with 3/4% CFR-2 to .,,'-..7--reach to above the top of the liner. 'Mix a heavy slurry to 118-122 pcf. 22. clean out cement to the top of~ the, float collar. Run Variable . Density Cement Bond Log from' effective depth to above top of the liner hanger .... . ~ . 23.Pressure test the-7 5/8" casing, 5 1/2" liner, 7 5/8" x 5 1/2" lap to 3000+ psi using the rig pumps. 24. Jet perforate selected Hemlock 8 sand intervals for production. Use33/8" OD carrier guns loaded with four 1/2" holes per foot. 25. Run tandem casing scrapers and scrape the entire 5 1/2" liner. 26. Run and hydrotest to 5000 psi, approximately 10,800' of 3 1/2" x 2 3/8" tubing and gas lift mandrels. Run 2 3/8" OD tubing and jewelry in the 5 1/2" liner. A detailed completion program will be provided after TD logs have been run. 27.. Remove BOPE and install x-mas tree. Pressure test tree to 5000 psi. Displace the drilling fluid down the annulus and up the tubing string using lease crude oil. · 28. Set the production packers and release the rig. Place the well on production as directed by the Production Foreman. O/S November 18, 1974 RMM ~ ~r.~a Engineer ~ ~ ~ ~0~ ~i~er 18, 1974 JLR ~ ~ A~ Supervisor B. A. Dakessian DRILLING FLUID PROGRAM SCU 44-4 ........ ~:~,.-. .... i;.,,: ....... SWANSON RIVER FIELD Medium treated lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES M~d Properties -(Vertical Depts) Weight - pcf '~-Max. 75# pcf Viscosity-sec/qt., API. As:Required F. luid loss -CC, A~I "i~:i... ~...:~c~'." .-'.'...'LU-~:.::.-'~--. ~.~!:Xield, Point - lb/100ft2 ~el .--,~ ~ n~/i oof t2 -. 1 o -m in; ' ~ ~ "-' ~--~ -~-~ '~ <'~i-'i!~'/' ~- "' ~.'~- ¥,i~ -~-~i . ' PH ", _Calcium- PPM ..... SOlids Content - -% 'Vol 1 2 ,:'~0--'3,-400' ':3,-400'--6,000' 3 4 6,000'-10,574' 10,574'-TD 72-80 93-95 74-76 40-60 43-48 43-47 7--10 7-10 4-7 '-~J~,O-20 20-30 10-14 '5-10 8-12 8-12 ~'10 max. 10 max. 0-5 :8.5-9.0 8.5-10 9.5 5max. 50 max. 8-1'2 10-18 6-10 1. Drill .'top -hole to 3,400,+_.~with-salvaged~-mud, if .available. 2..~onvert top 'hole-mudto-gel--mud--whiledrilling :from 3,400' to 6,000'. At 6,000', increase~weight~--and-have mud:propertiesas listed in Column No. 3. 3. Use medium treated lignosulfonatemud below 6,000'. 4. Limit dry.jobs to 20 sacks of bariteorasdirected by Drilling Foreman. 5. Maintain an adequate supply of lost circulation material at the rig. 6. Make a High Pressure- High'TemperatureFluid ..Loss determination every third d~y. -Make fluid loSstests .arc, estimated bottom hole temperature 170"F.- 7. Maintain'total hardness underl0O ppm and report all versenate titration as CaC12. :: ...... CASING REQUIREMENTS AND PRODUCING E UIPMENT · ~/LOCATION NO SCU 44-.4 FIELD Swanson River DATF 11/11/74 FORWARD BUYING NO. ' .. TOTAl. DEPTH. 11002 . METHOD OF P~,ODUCTION gas T.±ft :ESTIMATED'O/W/G1500/ - /15OC~uIP. FOR-STEAM "CASING Gross Footage APl Size :>.- ""weight -': i Grade C~mducfor 80 ' 18" 104 B , , ,, .ESTIMATED SPUD DATF_~l;~;_ember Z5; 197~ MAX. ESTIMATED SURF. PRESSUR~ 3800 INJ PRODUCER x Threads ,Coupling Computer Dos;gn For: Line Pipe. 0.562" WallThis Well Standard Design For Field ~u~face 3400' 10 3/4" 40.5 K-55 Buttress Well No. "'Requires= F10at. shoe, stab-in' duplex collar and stage collar w/buttress ~4ax. Dri{fAngle Thrds; 15 - 10 3/4" x 15" centralizers, 2 - 10 3/4"' 'stop 'rings, Baker Loc. Water String: Design based on mud density 95 lbs./cu, ff. and above max. surf. pressure 3600 - 7 5/8" ' .33.7 . P-110 Buttress . 1200 7 5/8" -33.7 . S-95 .Buttress .. 1900 . 7 5/8" 29.7 N-80 Buttress 4 X-overs 25 9 7/8" X 7 5/8' Centraliz~ 25 Stop rings. - 3874' 7 5/8',.-- ;. ~._26.4 ' N-80 Buttress " '- '' " ' -' "Z' .. :' . . · :'. u~aenz: nq.: - "x' 33, 7~ P-iiO' ~d~1' G .dlffe~ential fill-up shoe. &.. collar; stage coll~-& ~essorzes 7.5/8. .;. : p&ugs for s%age cementzng. '"... -'-' ."~.':-~-~R 2OO' 5 1/2"-'.<.' '::. ~20--;'. -/.. P-ZlO ~T&C Special clear,Ce coupling - 430' 5 1/2" ..;~-';' ~'~'.~.--2~ ./.'" .- ~80 LT&C :~~ 5 1/2" 209 'LTC x 7 5/8".' 33,:-7~ P,110 b~s. plain liner h~ger graved for .cemen~ng "'...... - float' sh0e, collar, plugs ~d. centralizers. ..'. . ~.~ P~ora~e8 --" ' . .... ', ~o ,~ -- M~ , .Rows, 51o~s, Cen~ers, }~ ~./: ,:-~ :;j,_ .. CASIN~D}'UNITI H~D: To 5~n . PSj'CwP./:/~Off°m'Conn."lo 3/4 SOW, ~eKD ~ ' p , ~Q" 5000 ~ ~qe 2 x 2 - sa~e~e~ ' ~ffings. ~ - sc~e~ed 3000 ~.~__~~ ~.~~.gg...~ ~e.~ '~_~e_: ......... ' L .......... - - , .outbfs TUBING HEAD. 5000 PSI CWP. Bottom Conn. 10" 5000 psi RJ Flange, type 59L Top Conn. 10" 5000# RJ Flange __" cufJets · Shatter 59L 3 1/2" Buttress up & ~own full b~re, bored for 3 1/2" '- Typo Suspenslon.-~,,~a~c:o' TUBING Feet APl Size Weight Grade - : l~of}om 650' 2 3/8" 4.7' - N-80 Nea~ 10350 3 1/2" 9.3' N-80' 11000 · 9 - 3 1/2" Camco MMG Mandrels w/R-20 valves 4 - 5 1/2" Ba~er FH Packers (20#) 3- 2 3/8" Otis "XA" Sleeves T~al 3-2 3/8" otis "s" Nipples, Pos #2,3 & 4 Thr;ads Type Remarks {Cross-overs, etc.1 8RD EUE 2 3/8" EUE x 3 1/2" Buttre£ Buttress (both N-80) 3 - 2 3/8" Brown CC Joints 1 -2 3/8" Camco "D" Nipple 1 - 2 3/8" Shear-out sub ' 100' - 2 3/8" Baker Blast Joint 3.062" Tubing Catcher " .typo. Pac~er "x "' w;~ ....... # wt. XM/~.TREF 3 ". ,, 2 Arm ' - Tubing Bea~,s " Casing Beans H~der Stuftlng Box PUMP: RODS: Grade PUMP~ UNff. APl S[zo .... '· Arm . Csg.'Size " Wt. Install at " ' .T~;po with ' "stroke at . ' Other Fittings.. ~ X ' x ' Type of · of "' ' of "' ' of. Type. __ Max. Stroke ~ . _" Set at . "Stroke and. Engine_. _ - - Motor. HP. .Remarks .... . .. PS! CWP. Dwg. No-'AP-C-174-.0 and AP-.~-175-0 .Type 1 - 3 " 5000 psi Willis Type 1 Bean ,Type " PSi CWP. Dwg. No.. ,Type. Polished Rod - Note: Ail casing and liner 5eing .skip~~~.~ka, w. ee~ ,of 11/il/74 per-.HLD'-SF 11/8/74. B~ '1'1/11/74 Approved'by Dist. Supt .... ' TY~. .Type · Lorg ? , .. L~ ., o .. ~ CU'. ~.~..~ t . o · I I j I t ' · L,_ . ' . ¶~U -_ !fl '~ ~ .-.,- ...... ~ -~. o 7. ~ . ' .- ._ .~ ~ ,, . ' . ,-y~ ~~~ .~ .~'. -;'.- ' ~: P~OPOS~O /~ . , .- ~: ~O~P~EnON': /..g : ,nb, ·~ ~ - - . ,__' :~ .~ ~E~V~T ~ ~. ~- , - · ~ -- - . ._ .,.. ~ ~u .-~.~ :. '.~"':'--: . ~ · .. '~ ~ _ .. ~ * ' . -. ~ .' . ,~- .'~ . ~ , _ . ' t r. ~ . · . . ~--~ , · _ · .. .. ~. · .~-~ ,~.~~- . . .. .~L '~:'. · -:' 'i ~- - . -.~ - . ~,' . (~ . . ~ - ~ ~ ..... ..... - . · i ~ . * ' . ~ ' 0 ~ - · '_ ~' · ~2, ~ ;~ - ' Y- - ........ ~ .... ~-I- ' ~ ...... ~~ ~~, ~. ~ ~, .... . · ~ ~~ .. -~~' ~. ':':.. ,:"', ~---._, -~__r[ '~"b' lES LO' OF SCU ~, ~i~ .~_:,_ ~ ' SHOWING PROPOSED CONPLETION . . ALASt~ 01L AND GAS CONSERVATtON COMMITTEE November 27, 1974 A DM t N i S T R A T I V E A P PRO V.A L N O. 123.2 · Re: App!lcatton of Standard Oil ComPany of Callfornta Swanson River Unit Operator', to drill the SCU 44°4 well as part of the pressure maintenance proj~t approved by ConserVation Order· No. 123. The location lies tn the S. E. I/4 of section 4, T7N, R9W,. S.M. Mr. J. L. Rowland Area Supervisor · . Standard Oi t' ~mpany of California .~ Box 7-839 .. Anchorage, Alaska 99510 ~ . . Dear Mr. Row I and: .......... · · On November 26, 1974 the referenced appllcafton was received whlch stated that the proposed well ~ould result. In addltlonal ultimate recovery of oil from the Hemlock 8 sand Inte~at, The referenced ~etl will be the thlrd completlon in a quarter section. .~. The 0tl and Gas Conservation Committee hereby authorized the dr!ltlng and completion of the referenced well pursuant to Rule 7 of Conservation Order 123. Very truly yours, Thomas R. Marshall, Jr Execut I ye Secretary ~' : .... TRM: cha P.O. Box-7-839, Anchorage, AK 995]0 · Phone (907) 279-9666 J. L. Rowland Area SuDervisor Producing Department November 21, 1974 Administrative Approval Well SCU 44-4 Swanson River Field Mr. Thomas R. Marshall, Jr. Alaska Oil & Gas Conservation Committee . Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Marshall: Standard Oil Company of California, as Operator of the · Swanson River Oil Field, proposes to drill a new development well, SCU 44-4, .in the SE 1/4 of Section 4, T7N, R9W, SB & M. The well is to be completed in the Hemlock 8 sand intervals, thus increasing the nuumber of completions in the quarter section from two to three for an equivalent reduction in spacing. The justification for the proposal is an estimated 423,000 STB of new reserves and 332,000 STB of accelerated reserves. By provisions of Conservation Order NO. 123, we request your approval to drill SCU 44-4. Very truly yours, BAD:da CC: Mr. J. P. Johnson, Atlantic Richfield Company Mr. E. F. Griffin, Union Oil Company Mr. B. G. Howard, Marathon Oil Company Mr. R. A. Smith, U.S.G.S. 0 · e~ K.~. to TUBING HANGER ( '-~BOR RIG ) 3~' x 6" TUBING HANGER 73 JTS. 3~' EUE 6rd 9°3# N-80 BUTTRESS 32 JTS. 3~' EUE 8rd 9e~ CAMCO;: ,~ .MANDREL, · 2~ JTS. ~' ~UB 8rd 9.3~ N-80 Bu'mBa~ 12 JTS. 2" EOE drd N-~O 2325.30' Y.02' 1676.7b' 12. ?d' 1290.3J4 ' 12.85' 994.29' 12.15 ' 630°30' 12o85' 259.53' 305o9O' ...r. .... ,¥.:~ 20~.79' 1;31' 37~.32' 2.09' $. 20' 60.99' 1.~1' 2.~' .60' T.D. 11,031' TOP OF PLUO 10,844 ~-Z DRILL @ 10~8~O No'r~: 3~' Tubing was pulled from SOd S.C.U. 44-4 CASING & TUBING DETAIL SECTION 4 T.T N.,R.gw. ELEV. I~0' KS 4.29 3~' x' 6'~ T~BZN,.3 ~ 73 J~., ~' E~ 8rd 9.3~ N~ BU'~~ 2~2~.~' .~'~" s... 3~' SUE 8~ 9.~ ~-~ ~ 6, 337,66 '~.. ',"' ' -" ' <"- .~ ' : . .~ C~CO ~" F~NDREL ' 12, lb' '[ ~ , ., ~'~ ..- "-~ ,. ~: 6S a~'. ~,, gus ~d ' --. ~' ,o4os' ~ 2~ x ~ X-o~r su'~ ' ~'~' :~'2%" OT~ ,,S,, N~P~, P~ition ~2' ' 1. Sa' ~ -1~- ~ e.~,i~__[ ~" ~ ~CC" JOINT 1.~1' · '~' '~ % 2~" x ~ ~ ~ FH PAC~ ROTATIONAL SET · '°~aa. - . , 2~ JAM~."U'" NIPPLE _ - ~oa.o~ . ' . 3 B~ST JTS. 3.~ OD h~.61' '""" "' 2~,, a Io1~-~0,82~,~0~ e, B[ER. SH~ S~B o, ,,,o s.c.U 44' 4 ~ cASIN6 & TUBIN6 DETAIL T.~. ~,o~, sECTION 4 T. 7 H.,R.gW. 4 '~ - Company ~L-L~ 0.~ / CHECK LIST FOR NEW WELL PERMITS Yes Ilo Remarks Is well to be located in a defined .pool ................. :~)/< Do statewide rules apply ........................ ~ ~ Is a registered survey plat attached .................. Is well located proper distance from property line ........... Is well located proper distance from other wells ............ Is sufficient undedicated acreage available in this pool ........ __ Is well to be deviated ......................... Is operator the only affected party ................... Can permit be approved before ten-day wait ............... ~0, Does operator have a bond in force ................... /,no< I, Is conductor string provided ...................... 12, ts enough cement used to circulate on conductor and surface ...... i3, Will cement tie in surface and intermediate or production strings 14. ''' ~l! cement cover all possible productive horizons [5, Will surface casing cover ali fresh Water zones ' ' ' .......... ~6, Will surface csg, internal burst equal 17, Wilt ail casing give adequate safety in collapse and tension ...... i8, Does BOPE have sufficient pressure ragin5 ............... Additional Requirements: 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 APPE .NDIXi ,, No special'effort has been made to chronologically organize this category of information. .o APR ~)~ 1975 DIVISION O~ OJI, 4NJ) CREEK UNIT #44-4 SWANSON RIVER 0, 0, 0, 0. 0.00 0.00 0o00 0,0 0,0 0o0 0,000 0.000 0.000 O, O, O, ............. "'" ':"-: .... O':'d'::"6:':i"':"O::"O':":'i':"':b .......... O' .......... '6"0 .... o:-'0 o o o t o o o o ~ :~;:.~:?:.~: ::::~:~: .:~:.:: _::. ~...::~ :'~:'. ,~.. _- _: 75" 1.00[ 0.995 0.600 NOT USF~D IN CO'RR~fT]ON OF DOUBTFt, L POROSITY DATA t:, '~¥' ~;~=':~':~ io:~:'':'~'~:: ' :o ...... '~"::":'::::::::::::::::::::::::::::-' :~:: : ~:? APR 2 ~ 19~ AN~ORACE ,.:.~ ~.:~::~ .:T,... :~. - ~:~. ~ SAT .' DENS ~: i6~:~~-~ ' .... ............ ~ ' ........ i ...... ~ ~'~' ~'~ 'g i ' ' ........ ' 10657,0 ]0 14,q 2~ 0,8~ T ......... "' ..... '~-'~'~i~~'' -':'~ 'o;s ~.~..... ~.~ ~.. ....... ~.._..-..~:.. ~=.. ~-. ~, .~. ...... ~:'~ ..... ~ =. .. ~-' i~':~'i:;::~''~ .............. ....... ~:~'~'~'~ ..... ':i:~:'~ ~:~"~ ....... '~- ":0'~'~:'* ~: ......... ::"'~:::~:~;:"~: ....... ....... ~'~-~'"-':"-:~>i? ~'~':'~ ~ 0;',. i~$"~;'~~-~' ...................... i~O''~. ~ ......... i~Z-~'' ............... ....... ~-'i:~'' CUM, POROSITY F'EE'i' 51.65 51.50 $i,12 51,03 50,93 50.81 50.60 50.54 50,49 50.]2 50,19 50,03 49088 49.73 49,56 40.40 49,25 49,12 48,98 48.85 48,73 49.59 48,43 48,27 48.i2 47.97 47,82 47.68 47,53 47.36 47.t8 47,00 46.82 46.6~ 46.44 46.26 46007 4~.87 45-65 4~.44 45023 45,05 44,8~ 44.65 44,45 26. 26. 26. 26, 26. 26, 26.,. 26, 26. CUI~, HYCARB I~EET 49 4i 36 2'/ 2! 16 26.01 25,ql 25080 25.68 25.55 25.42 25,30 25.20 25,09 24.99 24,89 24,77 24,64 24.50 24,38 24.25 24.i3 24.01 23,89 2].76 23.62 23,4'/ 23,33 2],18 23,04 22.00 22,75 22,60 22,43 22.27 22,il 21.81 21.65 21.49 f/ CUM. POROSITY FEET 44,25 44.06 43,81 0o00 0,00 43,68 43,67 43,42 43,30 43.20 43.09 42.97 42,86 42.75 42,43 42,32 42,18 42.02 41.86 41.?0 41,53 41.33 41,11 40.ql 40,70 40.51 40,31 40.10 39.91 39.70 39,50 39.30 39,10 8,39 a'23 38,05 37.86 37.4? 37,29 37.10 36,92 36.75 36.,58 21 21 20 0 0 20 20 20 20 20 20 20 20 20 HYCARB FEET . ]4 ,00 .00 66 ,,63 ,47 ,,42 20,42 20.37 20,30 20,2i 20.11 20,0i 19,9! lq.77 19,62 19,47 19,33 19.19 19s05 1R.90 t8,76 18.62 18.47 18.33 i8,18 18.05 17.93 17.81 17.70 17,60 17,48 1.7,35 i7,22 tT.Oq 16,97 16,86 16,74 16..63 le.52 , 10759,0 I00 ~4,3 36 ~ 20 10765.0 ]0 t8,4 4] 20 107b~,O 20 17,~ 44 26 1076~,0 40 19,2 4i o,8+ i ~ ~'"~ ;'6" i~ i6~ ~ i:-~'~'~;O ~-~'~ ...... ..... ~0 '~ '~'0~*' ~7 i,~OV-{~;,O~,:,~ ......... ....... ~;'~' ........... ":~],~ ~0 s ':':i ~20::':-"-":::':':~:~":'"~'~i-'~0'': ....... '¥" g:'-'-:' CUM, 36,21 ]6.02 ]5.54 35,30 ]t5.05 34,82 34.58 34,34 34.14 33,95 33075 33.56 33.37 33, t9 33.02 32,84 32,65 32,46 32,29 32. i ] 3J.94 3t.'74 3t.5B 31.21 3t.05 30.88 30' 67 30,46 30.05 29.85 2~,65 29.45 2q,25 29,02 28,7R 28,55 28.32 28.09 27,68 27.68 27,~0 27,31 27.13 26.94 CUM. HYCARB FEET 16,39 i6,27 16,14 15.98 18.7~ t6.60 15.43 15,27 i5.i2 i4,g? 14084 14.73 14.61 14,50 14.39 i4.29 14.20 14,09 I 3..q8 13,87 13.77 13.,68 13.57 i3,45 13.34 13,23 13.13 13,03 12,q3 12,80 12.6"/ 12,55 12.42 ! 2.29 i2.17 12,04 11.92 11,?? ti.6i 11,46 it.Ii 11.. 16 I1.0] lO,gl I0.79 10:.68 t0.57 10.47 I. IYC ~t~B 10.37 10,27 10.17 10,08 10.02 lO~O0 9.98 9,91 9.82 9.72 9.62 9,53 q.44 9.12 9,05 8.q9 · 8~94 8,90 8.84 8.77 8,69 8.59 0,00 0.00 0o00 0.00 0,00 0.00 0.00 0,00 0.00 8.51 8.46 8~42 8,30 8.23 ~.11 8.04 7.q6 7.87 7 cuM, PORO$~.TY FEET 21.35 2i.17 20.98 20 20.60 20.i9 19,70 t9.60 i0.42 i9.22 lq.02 18,80. 18.57 18.35 18.12 i7.90 i7.69 17,47 17,25 17.05' i6.84 16.65 16.46 16.28 16.13 i6.0i 15.63 i5.50 i~.37 15.25 I5.Oi 14.87 i4.69 14,48 14'28 t4.0~ 13'87 13.66 13.46 13.26 13007 i2.0i 12.78 HYCARB FEET 7,?? 7 68 7,59 7,49 7.40 7,29 7.18 7,06 6.96 6,86 6.76 6,67 6.,56 6,45 6,32 6,20 6,08 5,96 5.86 5,75 5.64 5.53 5,43 5,34 5,25 5,16 5.09 5.,03 4.97 4.93 4.88 4,83 4.79 4,75 4.6g 4,63 4.~6 4,47 4,37 4p28 4.2t 4.14 4.06 3,98 3.. O0 ],83 3.77 3.74 L'~nillsb].I:]~ [:1:!i CUM. PORO&ITY FEE? J2.68 12,59 t2.46 12'.29 12.12 $1.94 It.73 11,20 t1,00 10.84 10,64 i0.44 10,23 10.02 9.81 9.42 9.~4 9,07 8.89 8.72 0.56 7.g2 7.77 7.60 7.42 7.06 6.86 6.67 6.48 6.29 6.11 5.94 5.77 5.60 5.42 5,05 4.87 4.6~ 4.48 4.28 _ 4,10 0.00 0,00 CUM: HYCARB 3,74 3,71 3.66 3,59 3,52 3.45 3.37 3,29 3.1.9 3.10 3.0i 2,94 2,86 2.79 2,?! 2.63 2.54 2~46 2.19 2.32 2.25 2.18 2.i2 2.03 1.98 1.93 i,89 1,84 1.8t 1,78 1.75 1,71 1.67 1,63 1.58 1,54 1,48 1.43 i.3q 1.36 1,34 1,33 1,29 0.00 0.00 CUH. POR08I?¥ FEET 1,61 3,44 3,00 2.82 2,65 2,48 2,32 2,i5 1,OB 1,81 1,67 1,55 1.40 to24 ~.0~ 0,86 0067 0,47 0,28 0,09 cu,~: HYCARB ~.FEET. t.21 1.,15 1,10 1.00 0.94 0.88 0.77 0.72 · 0.66 0~61 0.57 0~53 0,48 0,44 0,37 0.30 0.24 0.16 0,09 0,03 GAS -., *'00 O0 0'0 O0 000000 dO0000 O0 ~ O0 :0000 0000 O0 O0 O0 O0 GO O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 o00000 000000 o00000 O0 O0 0000 0000 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 00:46:00 APR ~"~ 1975 DMSION OF OIL AND ~S /INCHORACE // ~.-. ...... fi:i~--?~.. ....... . .~::~.'.~ .......... ~-- ~ ~ Illlll 333333 77 555555 ~ ............ .... .... · :.::..:~:...>::;<...:~:_:<~.:_>: ::.... :..<-. :> : = :: ::::::. ::': :.?: :,:, ~::i ilit ~ [ .................. :j'¥~'"~'~i'~j" ~:: ~'<~:~"::' ::: :'::~'":::~6'~: ............. :::i 'ii"i'~ i i i i i i. 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 00- O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 000000 000000 O0 O0 OO O0 00 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 o00000 DIVISION OF OIL ANO (;AS
