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182-097
RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 1 2020 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Opera ions s o LJ Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erfomte New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: N2 ❑� 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ Stratigraphic❑ Service ❑ 182-097 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20357-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028142 Kenai Unit (KU) 11-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field / Sterling 3 Gas 11. Present Well Condition Summary: Total Depth measured 5,364 feet Plugs measured 4,185 feet true vertical 4,879 feet Junk measured N/A feet Effective Depth measured 4,185 feet Packer measured N/A feet true vertical 3,804 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 132' 20" 132' 132' Surface 2,000' 13-3/8" 2,000' 1,903' 3,090psi 1,540psi Intermediate 5,362' 9-5/8" 5,362' 4,877' 6,870psi 4,750psi Production Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SS 3-1/2" 9.2# / N-80 4,030' MD 3,666' TVD Tubing (size, grade, measured and true vertical depth) LS 3-1/2" 9.2# / N-80 4,086' MD 3,716' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 40 55 Subsequent to operation: 0 0 0 35 15 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-564 Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkremerlrDhilcom.com Authorized Signature: Date: t:—ze I 20 Contact Phone: 777-8420 Form 10-404 Revised 4/2 ({/ Submit Original Only ,� ��,� � �� RBDMS_ FEB 2 4 2020 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date KU 11-08 E -Line 50--133-20357-00-00 182-097 1 1/20/20 1 1/20/20 Daily Operations: 01/20/2020 - Monday Arrive at location, PJSM and PTW. Identified we needed a 3.5" BIRD EUE to Bowen crossover and procured one from Clint Chanley. Rig up Halliburton E -line with weight bar for pressure test. Pressure test lubricator to 250psi low / 2,000psi high - TEST GOOD M/U and RIH with Gamma, CCL, and TT HCS Scallop SemiExp - 6 SPF GeoDynamics 2-3/8" x S' Razor guns. Log and correlate with Ben Siks. Tried to pressure up well to desired 400psi. We tied it into the production header and found a blanked vapor flange in the flowline preventing flow. Production disassembled the flow line and removed the vapor flange. Pressure tubing up to 330psi, correlate on depth and perforate from 4,053-4,058ft, POOH. No pressure change over the entire POOH. Remained constant at 330psi. All shots fired, guns didn't appear to be wet. (330 psi did not communicate to the short string or the inner annulus) M/U and RIH with Gamma, CCL, and TT HCS Scallop SemiExp - 6 SPF GeoDynamics 2-3/8" x 10' Razor guns. Log and correlate with Ben Siks. Pressure tubing up to 345psi, perforate from 4,007-4,017ft and POOH. Pressure increased: 5 min - 367psi, 10 min - 396 psi, 15 min 405 psi. (Pressure did not communicate to the SS or the inner IA initially. After perforating the IA slowly climbed to 200psi). RD Halliburton E -line. Production put the well in test, it flowed for a few minutes and the pressure dropped to zero and the flow stopped. IA held 200psi of pressure and SS was at 40 psi. Hilcorp Alaska, LLC Prop. Des: FEDA- 028142 KB: 21' AGL (47.7' KB Elev) Spud Date: 8/13/1982 Rig Released: 19:00hrs 9/1/1982 X: 275,167.14 Y: 2,361,621.14 KU 11- 8 Pad 41-7 755' FEL, 515' FNL Sec. 7, T4N, R11 W, S.M. J�j Active Perls Sterling Pool 3 As 4,007'-4,017' MD 3,646'-3,655' TVD 6spf 1/20120 A7 4,053'-4,058' MD 3,687-3,691' TVD 68pf 1/20120 All 4,158'-4,178' MD 4,158'-0,178' TVD 6spf 1/14/07 Isolated Paris Sterling Pool 4 TOP Bottom B1 4,224'- 4279' MD 8spf (8/82) B2 4,336' - 4,358' MD 8spf (8/82) B3 4,394' - 4,424' MD 8spf (8/82) B4 4,467'-4,522'MD 8spf (8/82) (B-3 & B-4, 85' net, Sgz'd 10/23/97 w/ 186 bbl Maraseal) Sterling Pool 6 C1 5,063' - 5,093' MD 6spf (11/97) Dump Bailed Cement 5022' RKB to 4981' RKB Sand fill 5160' RKB to 5022' RKB Fill @ 5160' ELM (03/15/06) 4 5 PBTD: 4,185'MD / 3,804'TVD TD: 5,364'MD / 4,879'TVD SCHEMATIC Drive Pine 20" H-40 94 ppf Production Casing TOP Bottom 47 ppf MD 0' 132' MD 0' TVD 0' 132' Surface Casino Cmt w/ 1,500 sks Class G 13-3/8" K-55 61 ppf BTC Top Bottom MD 0' 2,000' TVD 0' 1,903' Cmt w11,275 sks Class G Production Casing KU 11-8 9.5/8" N-80 47 ppf Top Bottom MD 0' 5,362' TVD 0' 4,877' Cmt w/ 1,500 sks Class G 1 Short String 3 1/2" 9.2# N-80 Hyd 511 Otis XN Nipple @ 3,997' (4,012' ELMD) (No-Go=2.635") WLEG @ 4,030' RKB (4,045' ELMD) Coiled Tubing tailpipe to 4145' ELMD 3 Long String 3 1/2" 9.2# N-80 Mod BTC Otis XN Nipple @ 4,053' (4,067' ELMD) (No-Go=2.635") WLEG @ 4,086' RKB (4,100' ELMD) EZSV Cement Retainer 4,323' 10 Bbl Cement Plug squeezed through Retainer w/rig. Cement Plug 4,185- 4,323'(B-1 sand) 19-1-2006 Baker Model F-1 Prodn Packer @ 4,361' 6 Otis XN Nipple @ 4,380' (No-Go=2.635") Well Name & Number: KU 11-8 Lease: A-028142 County or Parish: Kenai Peninsula St te/Prov.:1 Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: 08/13/82 1 1 Ground Level (above MSL):F 26.7' RKB (above GL): 21' Revised By: Donna Ambruz I Last Revision Date: 01/29/20 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Sterling 3 Gas, KU 11-08 Permit to Drill Number: 182-097 Sundry Number: 319-564 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, re M. Price ai DATED this`day of December, 2019. RMS L�DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 R.R W1 M. �i�& DEC 12 2019 /-7-s rif,'311 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Repair Well Q Operations shutdown Suspend Q Perforate Q Other Stimulate❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 El 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 182-097 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 S. API Number: Anchorage, Alaska 99503 50-133-20357-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 510A , Will planned perforations require a spacing exception? Yes ❑ No Lal Kenai Unit (KU) 11-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028142 Kenai Gas Field /Sterling 3 Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,364' 4,879' 5,007' 4,433' —141 4,185' 4,155' Casing Length Size MD ND Burst Collapse Structural Conductor 132' 20" 132, 132, Surface 2,000' 13-3/8" 2,000' 1,903' 3,090 psi 1,540 psi Intermediate 5,362' 9-5/8" 5,362' 4,877' 6,870 psi 4,750 psi Production Liner Perforation Depth MD ft) : Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / N-80 4,100' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary .r Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory 11 Stratigraphic ❑ Development El Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 23rd, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: ctwo od@hilcorp.com 11 t C- q> lI Contact Phone: 777-8443 Authorized Signature: Date: % 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity Q BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: RBDMS'(NEC 19 2019 Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: III/ I " ( 0 tJ APPROVED BY d by: l ApproveI COMMISSIONER THE THE l COMMISSION Date: 7!1 Z• is Submit Form and Form 10- d 11/201 Approved app. r n i f r N from the date of approval. / ttachments in Duplicate n Hilcom Alaeku, M Well Prognosis Well: KU 11-08 Date: 12/11/2019 Well Name: KU 11-08 API Number: 50-133-20357-00-00 Current Status: Shut -In Gas Producer Leg: N/A Estimated Start Date: December 23rd, 2019 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 182-097 First Call Engineer: Christina Twogood (907) 777-8443 (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Current BHP: - 293 psi @ 3,773' TVD (Calculated from Static BHP Survey on 3/7/2013) Max. Expected BHP: - 520 psi @ 3,798' TVD (Based on offset well RFT data from 04/04/2017) Max. Potential Surface Pressure: - 141 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Brief Well Summary In 1982, KU 11-08 was drilled as a grassroots well and completed in the Sterling Pool 4, B Sands. The Sterling C was added in 1997. The well was shut-in in 2006. ' The purpose of this work/sundry is to add perforations in Sterling A8, A9 and A10 sands. Notes Regarding Wellbore Condition • The well is currently shut-in. • Minimum ID is 2.75". • Last tag @ 4,155' KB w/ 2.49" GR on 3/7/2013. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to pert. 4. RU perf guns. 0 Hiloow Alaska, LL 5. RIH and perforate the following interval: Well Prognosis Well: KU 11-08 Date:12/11/2019 Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling A8 +4,007' +4,017' +3,646' +3,655' +10' Sterling A8 +4,026' +_4,033' +3,663' +3,669' +7' Sterling A9 +4,053' +4,058' +3,687' +3,690' +5' Sterling A9 +4,085' +4,092' +3,715' +3,721' +7' a. Discuss with Operations Engineer pressuring up well to 400 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling 3 Gas Pool based on Conservation Order No. 530A. 6. POOH. 7. RD a -line. 8. Turn well over to production. (Test SSV with -in 5 days of stable production on well —notify AOGCC 24hrs before testing) E -line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,500 psi High. 3. RIH and set 3-1/2" Casing Patch or set 3-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure—N2 Operations /voTi C-7— / rel � q I tt c` 'mit #: 182-097 #: 50-133-20357-00-00 1�erty Des: A - 028142 21' AGL (47.7' KB Elevation) td Date: 8/13/1982 Released: 19:00hrs 9/1/1982 275,167.14 2,361,621.14 Active Paris: Sterling Pool 3: A11 4,158'-4,178' MD 2-3/8" 6spf (1/14/07) Isolated Paris: Sterling Pool 4: B1 4,224' - 4279' MD 8spf (8/82) B2 4,336' - 4,358' MD 8spf (8/82) B3 4,394'- 4,424' MD 8spf (8/82) B4 4,467' - 4,522' MD 8spf (8/82) (B-3 & B-4, 85' net, Sqz'd 10/23/97 w/ 186 bbl Maraseal) Sterling Pool 6: Cl 5,063' - 5,093'MD 6spf (11/97) Dump Bailed Cement 5022' RKB to 4981' RKB Sand fill 5160' RKB to 5022' RKB Fill @ 5160' ELM (03/15/06) KU 11- 8 Pad 41-7 755' FEL, 515' FNL Sec. 7, T4N, R11 W, S.M. jr I S ti MD: 5,364' TVD: 4,879' 1%) MARATHON Drive Pioe KU 11-8 13-318" K-55 20" H-40 94 ppf MD 0' LOU Bottom MD 0' 132' TVD 0' 132' 08/13/82 Ground Level (above MSL): 26.7' 1 RKB (above GL): 21' Surface Casino KU 11-8 13-318" K-55 61 ppf BTC Two Bottom MD 0' 2,000' TVD 0' 1,903' Cmt w/ 1,275 sks Class G Production Casino KU 11-8 9-5/8" N-80 47 ppf Top Bottom MD 0' 5,362' TVD 0' 4,877' Cmt wt 1,500 sks Class G XN Nipple @ 3997' (4012' ELMD go=2.635") i @ 4030' RKB (4045' ELMD) :d Tubing tailpipe to 4145' ELMD Uus AN Nipple @ 4053' (4067' ELMD) (No-go=2.635") WEG @ 4086 RKB (4100' ELMD) Cement plug 41851- 4323'(B-1 sand) 19-1-2006 EZSV Cement retainer4323' 10 Bbl Cement plug squeezed through retainer with 5. Baker Model F-1 Prodn Packer @ 4361' 6. Wireline Re-entry Guide @ 4382' 7. Otis AN Nipple @ 4380' (No-go=2.635") Well Name & Number: KU 11-8 Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs:1 Angle @KOP and Depth: KOP (TVD): Date Completed: 08/13/82 Ground Level (above MSL): 26.7' 1 RKB (above GL): 21' Prepared By: Kevin Skiba I I nef ao.a.r..., n�f Permit #: 182-097 API #: 50-133-20357-00-00 Prop. Des; FEDA-028142 KB: 21' AGL (47.7' KB Elev) Spud Date: 8/13/1982 Rig Released: 19:OOhrs 9/1/1982 X: 275,167.14 Y: 2,361,621.14 KU 11-8 Pad 41-7 755' FEL, 515' FNL Sec. 7, T4N, R11W, S.M. Proposed Perfs 1 3 Pool 3 Bottom i A8 ±4,00T-t4,017'MD ±3,646'-±3,655'TVD 8spf A8 34,026'-±4,033'MD ±3,663'-±3,669'TVD (8/82) A9 ±4,050'-±4,058' MD ±3,687' -±3,690' TVD f A10 ±4,085'-±4,092'MD ±3,715'-±3,721'TVD i 4 Cl 5,063' - 5,093' MD 6spf (11/97) � a. _fl Proposed Perfs ? Sterling Pool 3 Bottom i A8 ±4,00T-t4,017'MD ±3,646'-±3,655'TVD 8spf A8 34,026'-±4,033'MD ±3,663'-±3,669'TVD (8/82) A9 ±4,050'-±4,058' MD ±3,687' -±3,690' TVD f A10 ±4,085'-±4,092'MD ±3,715'-±3,721'TVD E Active Perils 'JC Sterling Pool 3 All 4,158'4,178'MD 2-3/8"6spf (1/14/07) m Isolated Perfs 9-5/8" N-80 Sterling Pool 4 Toe Bottom B1 4,224'-4279- MD 8spf (8/82) B2 4,336' - 4,358' MD 8spf (8/82) B3 4,394'- 4,424' MD 8spf (8/82) B4 4,467' - 4,522' MD 8spf (8/82) (B-3 & B-4, 85' net, SgzV 10/23/97 w/ 186 bbl Maraseal) Sterling Pool 6 Cl 5,063' - 5,093' MD 6spf (11/97) Dump Bailed Cement 5022' RKB to 4981' RKB Sand fill 5160' RKB to 5022' RKB Fill @ 5160' ELM (03/15/06) E 7 MD: 5,364' TVD' 4,879' 5 11 Hilcorp Alaska, LLC Drive Pipe 20" H-40 Toe MD 0' TVD 0' Surface Casino 13-3/8" K-55 TOR MD 0' TVD 0' 94 ppf Bottom 132' 132' 61 ppf BTC Bottom 2,000' 1,903' Production Casing 9-5/8" N-80 47 ppf Toe Bottom MD 0' 5,362' TVD 0' 4,877' Cmt w/ 1,500 sks Class G Otis XN Nipple @ 3,997' (4,012' ELMD) (No-Go=2.635") WLEG @ 4,030' RKB (4,045' ELMD) 2 Coiled Tubing tailpipe to 4145' ELMD 3 Long String 3 1/2" 9.2# N-80 Mod BTC Otis XN Nipple @ 4,053' (4,067' ELMD) (No-Go=2.635") WLEG @ 4,086' RKB (4,100' ELMD) EZSV Cement Retainer4,323' 10 Bbl Cement Plug squeezed through Retainer w/ng. Cement Plug 4,185'- 4,323'(B-1 sand) 19-1-2006 5 Baker Model F-1 Prodn Packer @ 4,361' 6 Otis XN Nipple @ 4,380' (No-Go=2.635") 7 Wireline Re -Entry Guide @ 4,382' STANDARD WELL PROCEDURE fmrorP.%IaskaAlk NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • M Marathon MARATHON OI! Company August 29, 2007 ~~~ Np~ ~ ~ ~fl07 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~ AUG ~i ~ 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-407 Sundry Notice Field: Kenai Gas Field Well: KU 11- 8 Dear Mr. Maunder: Alaska Oil & Gas Coos. Commission Anchorage ~~ ~~j~ ~ ~~ Attached is the Sundry Report 10-407 for work performed on well Kenai Unit 11-8. The well was completed into the Sterling Pool 3 after the Pool 4 perforations were isolated with a cemented plug. This effort did not develop gas production. Marathon is not submitting a Test Report 10-421 since there is no gas flow. Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Production Technician Enclosures: 10-407 Sundry Report cc: Houston Well File Well Schematic Kenai Well File Operations Procedure DMD KJS STATE OF ALASKA 9_~ AL~ OIL AND GAS CONSERVATION COfv~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil^ Gas Plugged ^ Abandoned ^ Suspended ^ zoanczs.ios zo.4aczs.iio GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1 1b. Well Class: Development 0 Exploratory^ Service ^ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date Comp., S ~ o~ Aband.: 12. Permit to Drill Number: 182-097 3. Address: PO Box 1949, Kenai Alaska, 99611-1949 6. Date Spudded: .~ 8/13/1982 13. API Number: 50-133-20357-00-00 4a. Location of Well (Governmental Section): Surface: 755' FEL, 515' FNL, Sec.7, T4N, R11W, S.M. 7. Date TD Reached: 8/20/1982 14. Well Name and Number: Kenai Unit 11-8 Top of Productive Horizon: 731' FWL, 934' FNL, Sec. 8, T4N, R11W, S.M. 8. KB (ft above MSL): 21' Ground (ft MSL): 26,7' 15. Field/Pool(s): Total Depth: 1,257' FWL, 1,072' FNL, Sec. 8, T4N, R11W, S.M. 9. Plug Back Depth(MD+TVD): 4,198' MD 3,816 TVD Kenai GaS Field / Sterling POOI 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 275,167.14 y- 2,361,621.14 Zone- 4 10. Total Depth (MD +TVD): 5,364' 4,879' 16. Property Designation: A - 028142 TPI: x- 276,645.61 y- 2,361,173.05 Zone- 4 Total Depth: x- 277,170.40 y- 2,361,025.90 Zone- 4 11. SSSV Depth (MD +TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes ^ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): CCL, Gamma Ray 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD E SIZE HO CE R AMOUNT FT TOP BOTTOM TOP BOTTOM L MENTING ECORD PULLED 20" 94# H-40 0' 132' 0' 132' Driven 0 13-318" 61# K-55 0' 2,000' 0' 1,903' 17-1/2" 1,275 sks "G" 0 0 9-5/8" 47# N-80 0' 5,362' 0' 4,878' 12-1 /4" 1,500 sks "G" 0 0 23. Open to production or injection? Yes 0 No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" w/ 1-3/4" tail 4,029'! 4,127' tail NA 4,158' - 4,178' MD 3,779' - 3,789' TVD 3-1/2" 4,086' NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4,224' - 4,358' gross 1,666 sks cement 26. PRODUCTION TEST Date First Production: No Production Method of Operation (Flowing, gas lift, etc.): NA Date of Test: NA Hours Tested: NA Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. NA Casing Press: NA Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No^ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and lapboratory analytical results per 20 AAC 25.071. ~F~.. SEP `~ 81DD7 coMPLETtON l-~~D.~ Form 10-407 Revised 2/2007 NTINUED ON REVERSE ~ `.} ~' ` ORIGINAL ~l~o~G 28. GEOLOGIC MARKERS (List all formations and rs encountered): 29. FORMATION TESTS NAME TVD Well tested? Yes {f yes list intervals and formations tested briefly , , summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost -Top detailed test information per 20 AAC 25.071. Permafrost -Base Sterling A11 Sand 4,152' 3,773' Formation at total depth: Upper Beluga 5,253' 4,758' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Dennis DOnOVBn Title: Production En ineer Signature: ~ Phone: (907) 283-1333 Date: ,29 ~AO'~' ~~ ~, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Class cation of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 rGnuu n: ion-vyr API #: 50-133.20357-00-00 Property Des: A - 028142 KB: 21' AGL (47.7' KB Elevation) Spud Date: 8/13/1982 Rig Released: 19:OOhrs 9/1/1982 X= 275,167.14 Y= 2,361,621.14 KU 11- 8 Pad 41-7 755' FEL, 515' FNL Sec. 7, T4N, R11W, S.M. Active Perfs: Sterling Pool 3: A11 4,158'-4,178' MD 2-3/8" 6spf (1/14/07) Sterling Pool 4: 61 4,224' - 4279' MD 8spf (8/82) B2 4,336' - 4,358' MD 8spf (8/82) 63 4,394' - 4,424' MD 8spf (8/82) B4 4,467' - 4,522' MD 8spf (8/82) (B-3 & B-4, 85' net, Sgz'd 10/23/97 w/ 186 bbl Maraseal) Sterling Pool 6: C1 5,063' - 5,093 'MD 6spf (11/97) Dump Bailed Cement 5022' RKB to 4981' RKB Sand fill 5160' RKB to 5022' RKB Fill @ 5160' ELM (03/15/06) Drive Pipe 20" H-40 94 ppf T~ Bottom M D 0' 132' ND 0' 132' Surface Casing 13-318" K-55 61 ppf BTC Two Bottom MD 0' 2,000' ND 0' 1,903' Cmt w/ 1,275 sks Class G Production Casino 9-5/S" N-80 47 ppf Toe Bottom MD 0' 5,362' ND 0' 4,877' Cmt w/ 1,500 sks Class G XN Nipple @ 3997' (4012' ELMD @ 4030' RKB (4045' ELMD) Tubing tailpipe to 4145' ELMD XN Nipple @ 4053' (4067' ELMD) WEG @ 4086 RKB (4100' ELMD) Cement plug 4185' - 4323' (B-1 sand) 19-1-2006 EZSV Cement retainer 4323' 10 Bbl Cement plug squeezed through retainer with rig. 5. Baker Model F-1 Prodn Packer @ 4361' 6. Wireline Re-entry Guide @ 4382' 7. Otis XN Nipple @ 4380' (No-go=2.635") Well Name & Number: KU 11-8 Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: 08/13/82 Ground Level (above MSL): 26.7' RKB (above GL): 21' Prepared By: Kevin Skiba Last Revision Date: 08/29/07 MD: 5,364' TVD: 4,879' c: Marathon Oil Company Page 10 of 15 Operations Summary Report -- LegalltVeN Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8!13!1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 I Date ~ From - To Hours ~ Code ~ Sub Phase I Description of Operations Code, 12/162006 09:00 - 10:00 1.00 SAFETY MTG WRLN Arrive on location uptain work permit and discuss operations. Held PJSM. 110:00 - 11:10 1.17 RURD_ ELEC WRLN RU wireline unit. PT to 500 prig, Mll 2.5" GR. 11:10 - 12:30 1.33 WORK ELEC WRLN Run correlation log with CCL and 2:5" GR. RIH tag fill at 4302' KBD, WEG at 4099' KBD and XN nipple at 4066' KBD. POOH 12:30 - 13:15 0.75 RURD_ ELEC WRLN RD unit. Expro IeR lease. 12/19/2006 07:00- 08:00 1.00 SAFETY MTG_ CTBG ArcNe on location uptain work permit and discuss operations. Held PJSM. 08:00- 16:00 8.00 RURD_ COIL CTBG Spot and RU coiled tubing unit and cementing equipment. 16:00 - 18:00 2.00 TEST ROPE CTBG Full 250 / 4500 test on surtace lines and complete BO P test. 18:00 - 19.:00 1.00 RURD_ COIL CTBG Rig back for night and leave location. 12/20!2.006 i 07:00 - 09:00 2.00 SAFETY MTG_ CTBG Arr'Ne on location obtain work permit and discuss operations. Held PJSM. Start equipment ~ 09:00 - 10:45 1.75 RURD_ COlL CTBG Stab injector on well. 10:45 - 11:15 0.50 TESTY BOPS CTBG Shell test to 1000 psi. ~~ 11:15 - 12:20 1.08 R'UNPU COIL CTBG RIH CT and tag at 4301' CTD. Flag pipe at 4150`. ;12:20 - 13:15 0.92 PUMP_ CMT_ CTBG Mix 11.5 BBIs class G at 15.8 ppg. ;13:15 - 14:00 0.75 PUMP_ CMT_ CTBG PUMP 10 bbls cement and la~from 4203' to 4177. 114;00- 14:50 0.83 RUN'PUL COIL CTBG POH CT. ~ 14:50 - 16:00 1.17 RURD_ COIL CTBG Rig back for night and leave location. WOC. 12/212046 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment 08:00 - 13:00 5.00 RURD_ COIL CTBG Thaw surtace lines and BOP. 13:00 - 13:25 0.42 RURD_ COIL CTBG PU injector. Ice in tree: Set injector back down. 13:25 - 15:50 2:42 RURD COIL CTBG Thaw tree. 15:50 - 16:15 0:42 RURD_ COIL CTBG MU tailpipe BHA and stab on well. RIH 11T CT. Total tailpipe length is ~I I I i I 130'. i - - _ _ PnnteC: 8/29/2007 ^~..1'.51:28AM • • Marathon Oil Company Page 11 of 15' Operations Summary Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8/13/1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To ~ Hours Code .Cad Phase II Description of Operations e 12!212006 16:15 - 17:15 1.00 RURD_ COIL CTBG PU injector and cut CT. MU tailpipe hanger onto CT. 17:15 - 17:45 0.50 RUNPUL SLIK CTBG PU tailpipe with Expro and hang off in tree. 17:45 - 18:00 0.25 RURD_ COIL CTBG Secure well for night and leave Location. 1222/2006 07:00 - 07:45 0.75 SAFETY MTG_ CTBG Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment 07:45- 10.:30 2.75 RURD_ COIL CTBG Move BOPfrom short string to long string 10:30 - 12:00 1.50 RURD_ COIL CTBG Stab injector on well. 12:00 - 12:30 0.50 TEST_ ROPE CTBG Shell test to 3000 psi. 12:30 - 13:30 1.00 RURD_ COIL CTBG Displace 50/50 from CT with N2. 13:30 - 15:30 2.00 RUNPUL COIL CTBG RIH while Pumping N2 to reverse out water. 15;30 - 16:00 0.50 RUNPUL COIL CTBG Tag bottom at 4159'. Perf interval is 4158' - 4178'. N2 pressure is 1500 psi ancle holding. PU to check CT flag. Depth appears to be accurate. 16;00 - 16:40 0.67 RUNPUL COIL CTBG POH CT. Leave 4500 psi on well. 16:40 - 17:00 0.33 RURD_ COIL CTBG Secure well for night and leave location. 12/23!2006 07:00 - 08:00 1.00 SAFETY MTG_ SLICK Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment 08:00 - 09:00 1.00 WAITON OTHR CTBG Muster during fire alarm. Wait on all clear from production to continue. 09:00 - 10:45 1.75 RURD_ SLIK CTBG RU end p test lubricator with 50/50. 10:45 - 15:50 5.08 RUNPUL SLIK CTBG Meke 5 runs with 2.25" bailer. All bailers full of contaminated cement. Made 5'. 15:50 - 47:30 1.67 RUNPUL SLIK CTBG Made 2 runs with 2.60" LIB. First run could not pass XN. Redressed damaged lead and reran. Passed 2:635" XN. 17:30 - 18:00 0.50 RURD_ SLIK CTBG Rig down Expro slickline. Ready to RU CT for underreaming. 12282006 08:00- 09:00 1.00 SAFETY MTG_ CTBG Arrve on location obtain work permit and discuss operations, Held PJSM. Start equipment 09:00 - 10:20 1.33 RURD_ COIL CTBG RU and stab injector on well. 10:20 - 10:45 0.42 RURD_ COIL CTBG Load CT with 50/50 10:45 - 12:00 1.25 RURD_ COlL CTBG PT 80P 200 ! 4000 psi. 12:00 - 12:45 0.75 RURD_ COIL CTBG SD operations due to wind conditions and secure location. Wind is 30+ sustained with 45 gusts. 1..2;45 - 14:00 1.25 RURD_ COIL CTBG Bullhead 108 Bbls water down long string to fill well. 1.4:00- 15:00 1.00 RURD_ COIL CTBG Secure location and leave. 12292006 07:00 - 08:15 1.25 SAFETY MTG_ CTBG Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment 08:15 - 09:15 1..00 RURD_ COIL CTBG RU and stab injector on well. 09:15 - 10:00 0.75 TEST ROPE CTBG Perform full BOP test 200 psi low ! 4000 psi high. 10:00 - 10:45 0:75 RURD_ COIL CTBG Displace CT to water. 10:45 - 13:00 2.25 RURD_ COIL CTBG LD nozzle andc PU motor and 2.625" underreamer with blades to drill 6" hole. 13:00 - 13::15 0.25 TEST_ ROPE CTBG Shell test bop. 13:15 - 14:30 1.25 RUNPUL COIL CTBG RIH and tag at 4069' CTMD (4067' ELMD). 14:30 - 15:15 0.75 RUNPUL COIL CTBG Work to pass through XN with and without pump. Unable to pass. 15:15 - 15:45 0.50 RUNPUL_ COIL CTBG POH CT. 15:45 - 16:30 0.75 RURD_ COIL CTBG Displace CT to 50/50 and freeze protect surface lines. 16:30 - 17:00 0.50 RURD_ COIL CTBG Secure location for night. Leave location. Order 2.70" mill to ream XN. 12/30/2006 11:00 - 12:40 1.67 SAFETY MTG_ CTBG Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment. *"late start due to high winds in AM.. 12:40- 13:10 0.50 RURD_ COIL CTBG RU and stab injector on well. Displace coil with water. 13:10 - 14:25 1.25 RURD_ COIL CTBG Make up motor, 2.7" tapered mill to BHA. PU and go to well with injector. 14:25 - 15:15 0.83 TEST_ ROPE CTBG ~ Shell test low at 200 psig, high at 4000 psig. Good test. 15:15 - 15:30 0.25 RURD_ COIL CTBG ~ Open well, RIH with cal tagged up on ice in the tree. 15:30 - 17:00 1.50 ~ RURD_ COIL CTBG + Rap tarp around tree and heat with heater. Open up back side and load Punted: 8/29/2007 11 :5128 AM ~, • • Marathon Oil Company Page 12 of 15 Operations Summary Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8!13/1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date j From - To Mours ~ Gode ~ Code ~aSe ~ Description of Qperatipns ~i 1 , 12/302006 15:30 - 17:00 1.50 RURD_ COIL CTBG hole with fresh water to help desolve ice plug. 17:00- 18:25 1.42 WORK COIL CTBG Ice gone, RIH and tag at 4062' CTMD (4067' ELMD). Flag iron with blue paint. 18:25 -20:30 2.08 WORK COIL CTBG Work mill, stalled motor, drop off pump, PU hole a few feet. Stag up pump. PIP free spin at 2550 prig, 1.5 BPM, RIH work mill several times stalling motor, from 4060.9' down to 4062.8' CTM. 20:30 - 20:32 0.03 WORK COIL CTBG SD pump, RIH fo make free fag still not able to wale 2.70" mill past 4062' CTM. POOH CT. 20:32 - 21:15 0.72 RURD_ COIL CTBG OOH with coil, Displace CT to 50/50 and freeze pr~ect surtace lines. 21:15 - 23:00 1.75 RURD_ COIL CTBG Lay down mote anal mill. Secure location for night. Leave location. Ordered 2.70" more agressive mill from Baker. 12/312006 09:00- 09:45 0.75 SAFETY MTG_ CTBG Arrve on location obtain work permit and discuss operations. Held PJSM. Start equipment. 09:45 - 11:45 2.00 RURD_ COIL CTBG RU and stab injector on well. Displace coil with water. 11:45 - 12:40 0.92 WAITON EOI P CTBG Make. up motor, hold for 2..70" mill to arrive from Baker. PU and go to well with injector. 12:40 - 14:30 1.83 WORK COIL CTBG Circulate fluids fo tank, flow line from choke to FB tank froze. Break out all chicksan from choke toflow back tank and replace with new flaw back line. Ice plug in chicksan lines and choke work on removing ice. Ice clear on all ground lines. 14:30 - 15:30 1.00 WORK COIL CTBG Cool pressured up froze on the coil from the reel to the goose neck. Made reveal attempts to pressure up and release pressure to move the plug. Pumped Methanol on the back side of the coil, to the flow back tank, to desolve the ice plug. Still frozen. 15:30 - 18:00 2.50 RURD_ COIL CTBG Decide to lay down the injector break dawn the BHA and cover the cdl with tarps. Heat coil with two indirect fired heaters and trunks. 18:00 - 18:25 0.42 RURD_ COIL CTBG Had Vac truck make up to the coil connector to be ready to when coil freec up and we could displace the coil with Methanol. 18:25 - 18:20 0.92 RURD_ COIL CTBG Stated pumping Methanol to displace coil, pumped total of 28 BBLS accross the coil Finish RD coil unit. BJ crew left lease. 1/4/2007 07:00 - 08:45 1.75 SAFETY MTG_ CTBG Arrive on location obtain wak permit and discuss operations. Held PJSM. Start equipment. 08:45 - 10:30 1.75 RURD_ COIL CTBG RU and stab injector on well. Displace coil with water. 10:30 - 12:00 1.50 RURD_ CO1L CTBG Makeup motor end 2.7D"tapered mill. PU and go to well with injector. 12:00 - 12:25 0.42 TEST_ ROPE CTBG Test BOP 200/4000 psi. 12:25 - 13:15 0.83 RUNPU COIL CTBG RIH motor and 2.70" tapered mill. Tag at 4059' CTMD. (4067 ELMD) 13:15- 14:25 1.17 MILL_ PLUG CTBG Ream XN from 6.35" to 6.70". Ream up and down several times. 14:25- 14:55 0.50 RUNPU COiL CTBG POH. 1455 - 15:15 0.33 RURD_ COIL CTBG LD 2.70" mill and PU 2.35" underreamer body with 6" cutting blades. 15:15 - 16:25 1.17 RUNPUL COIL CTBG RIH and tag at 4160' corrected depth. 16:25 - 18:25 2.00 DRILL_ CMT_ CTBG Underream cement from 4160' - 4198' corrected depths. Stall morot at 4198' and circulate well clean. 18:25 - 20:00 1.58 RURD_ COIL CTBG Freeze protect all lines and CT and secure location for night. 1/5/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG Arrive on location obtain work permit and discuss operations. Held PJSM. Start equipment. 07:30 - 15:15 7.75 REPAIR EQIP CTBG Repair brakes on N2 pump. 15:15- 16:15 1.00 RURD_ COIL CTBG Cool down n2 unit. 16:15 - 17:00 0.75 PUMP_ N2_ CTBG Displace CT to N2. 17:00 - 20:15 3.25 RUNPUL COIL CTBG RIH while reversing N2 and taking returns fran CT. Stop Ct at 4190'. Returns are sporadic and partially frozen. 20:15 - 00:15 4.00 RUNPUL PLUG CTBG Returns stopped. Start thawing surface lines while moving CT. Printed: 8/29/2007 11:51.28 AM I ~' • • Marathon Oif Company Page 13 of 15 Operations Summary Report Legal Well Name: KENAI UNIT 11.8 Common Well Name: KENAI UNIT 11-8 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date ~ From - To ~ Hours ~ Code ~ SUb Code ~ Phase 1/5!2007 00;15- 02:00 1.75 RUIVPUL COIL CTBG 02:00-03:00 1.00 RURD_ COIL CTBG 03:-00 -06:00 3.00 RURD_ COIL CTBG 1/6/2007 46:00 - 06:15 0:25 SAFETY MTG_ CTBG 06: t5- 11;15 5.00 RURD_ COIL CTBG 11:15- 12:15 1.D0 RURD_ COIL CTBG 12:15- 13:00 0.75 RURD_ COIL CTBG 1/112007 07:00-07:45 0.75 SAFETY MTG_ CTBG 07:45- 10:45 3.00 SAFETY MTG CTBG 10:45- 11:50 1.08 RURD_ COIL CTBG 11:50- 12:35 0.75 RURD_ COIL CTBG 12:35- 13:20 0.75 WORK COIL CTBG 13:20- 13:40 0.33 WORK COIL CTBG 13:40 - 14:35 0.92 WORK COIL CTBG 14:35- 14;46 ~ 0.18 WORK~GOIL CTBG 14:46- 15;20 0.57 WORK COIL CTBG 15:20- 15:45 0.42 WORK COIL CTBG 15:45- 16:30 0.75 WORK COIL CTBG 16:30- 18:40 1 2.171 WORK_jCOIL CTBG 18:40 - 19:30 0.83 RURD_ COIL CTBG 1/122007 07:00-OT.45 0.75 SAFETY MTG CTBG 07:45 - 09:30 1.75 SAF€TY MTG CTBG 09:30- 11;00 1.50 WORK COIL CTBG 11:00 - 11:30 ~ 0.50 ~ WOR K ~ COIL ~ CTBG 11:30- 12:00 1 0.501 WORK CCOIL (CTBG 12:00- 12:10 ~ 0.17 WORK (COIL CTBG 12:10 - 12:20 1 0.17 ~ WORK~jCOIL (CTBG 12:20 - 15:00 ~ 2.671 WORK_I COIL ~ CTBG Spud Date: 8/13/1982 Start: 3/7/2006 End: Rig Release: Group; Rig Number: 1 Description of Operations POH Ct while thawing lines. Call for steam truck. Continue thawing lines. Start thawing lines with steam: Keep reel warm with heater and tarp. Held PJSM. Continue thawing. lines with steam unit and heaters. Reverse circulate 50 /50 MEOH into CT. Freeze protect ground lines. Secure locatioon and leave. Held PJSM. Uptained permit, disucssed procedure. Remove cal cover, PU injectorand go to well with nozzle. Test BOP's, 200psig low pressure/ 4000 prig high. Test good. Displace coil to Methanol tank, open well. WHP= 610 psig RIH with coil, cal at 2540' CTM, N2 at 550 SCF going down the back (side. No returns to flrna back tank. P1P=1'090 psig Continue down hole with coil, coil. at 418T, PIP ~ 1635 psig on the back side. Return pressure at 0 psig. 'Back side pressure continue to pressure up with no returns to flow back. Back side pressure at 2000 psig. Appears like coil plugged or frozen. PU cal to 3430 psig still no retums to Sow back tank. WHP= 2230 psig. S:/D N2 pumping: Open coil to pump, pump 3 bbls Methanol into coil, open back side to cal to push Methanol in coil to try and contact ice plug. Equilize cal to WHP to try and move ice plug. Pressued up on coil to 1977 psig, Bled down the back side to 900 psig. Plug did not move. POOH with coil. OOH with coil SI well. Cal pressure at 1924 psig, WHP= 769. psig. Bled down cal and back side pressure. PU injector and -pull off of well. Check nozzle to verify ifplugged no plugging around nozzle, ran cable up coil 6` to verify if plugged above nozzle, no ice plug or solids. Rack up injector to craddle and pulled jet nozzle and replaced with a cap. Covered up the cal and injector. Displaced ground lines with Methanol and pump coil with as much Methanol as it would take with out pressuring up against the plug. Secure site and cover all flow lines and tree to keep heated over night. BJ cal crew left tease. Held PJSM. Uptained permit, disucssed procedure to reverse fluid off of well. Remove coil cover, PU injector, MU different nozzle with large ports to flow through. Shell test to 3000 psig high. Test good. Displace coil to Methanol tank. Pressured up to 3800 psig on coil. Plug moved pressure down to 1400 psig while pumping.. Pumped total of 45 bbls. Shell test to 3000 psig, test good. Open well, WHP= 600 psig. Start N2 at 550 SCFM dawn tubing while running in well. Choke closed to flow back tank. Continue down hole with coil, coil at 3571', PIP ~ 2400 psig down coil. WHP= 1530 psig. Displace Methanol out of reel down well while running in hole. Switch pumping N2 down coil to the back side and reverse flow up the coil. 41, 000 SCF of N2 pumped down tail. Parked cal at 4181' KBD. Start N2 at 550 SCFM to displace coil to the flow back tank. PIP down back side= 1960 psig. Return pressure at 10 psig. Pressure up back side to 2150 psig, maintain 2100 psig on back side Punted: 8!29/2007 11:51 28 AM ~' • • Marathon Oil Company Page 14 of 15 Operations Summary Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8/13!1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date i From - To I Hours ~ Code i Code ~ Phase i Description of Operations -- ~-- 1/122007 12:20 - 15:00 2.67 WORK COIL CTBG of well. Returns at 1 BBPM, N2 rate up to 850. SCFM. WHP= 140 psig. 15:00 - 15:30 0.50 WORK COIL CTBG Pressure on back side at 2090 psig, cal pressure up to 260 prig, no fluid to flow back tank, Shut down N2. Continue to blow down well to flow back tank. 15:30 - 16:00 0.50 WORK COIL CTBG POOH with cal, while blowing down N2 off of well, teal of 110 bbls produced to flow back tank. 16:00 - 16:30 0.50 WORK COIL CTBG OOH with coil, blow down well to flow back tank, 1500 psig on well. Short suing has same pressure as long. 1630 - 17:55 1.42 WORK COIL CTBG Continue blowing down well to flow back tank. Well has400 psig. Have vac truck pull all fluid off of flow lines while waiting to finish well head blow down. 17:55- 18:00 0.08 RURD_ COIL CTBG Shut in well, WHP= 250 psig. PU injector off of well, take to cradle. RD unit. 18:00 - 19:00 1.00 RURD_ COIL CTBG Secure site and cover all flow lines and tree to keep heated over night. BJ cal crew left lease: 1/152007 08:00- 09:00 1.00 SAFETY MTG_ WRLN Held PJSM, discussed safey concerns and envirionmental issues. Uptained work permit and reviewed procedure. 09:00 - 10:00 1.00 RURD,_ ELEC WRLN MU 1 3!4 tool string with CCL and gammy ray. PU lubricator and get ready to arm gun. 10:00 - 11:00 1.00 SAFETY MTG_ WRLN Held explosive safety meeting prior to arming gun, went to communication black out. 11:00 - 11:05 0.08 WRLN Armed gun, PU in lubricator and PT to 500 psig. Good test, open up the long string side. of well,. RIH with 2 3/8" X 20" perrorating gun with 6 SPF. 11:05 - 11:45 0.67 WRLN Tagged fill at 4186' KBD. PU and run correlation log. Corrrelate well to Dresser Atlas DI focus lag dated 8-21-82 to Expro CCL log tied into the gammy ray. 11:45 - 12:00 0.25 WRLN PU hole and perforate from 4158' - 4178' KBD (20'1 WHP=.240 psig when perforated. POOH with gun. WHP= 230psig after pertor'ating. 12:00 - 12:20 0.33 WRLN OOH withgun; all shots fired. Lay down pertorated gun. PU 1.75" tool string, that consist of 10' stem, oil jars, spang jars, & 3.5" GS. 12:20 - 12:25 0.08 WRLN Move to short side of tree. PT lubricator to 500 psig. Open well, RIH to top of master valve. Latch up on 1.75" X 1.30' piece of coil, hand spang to latch into top of th a coil. 12:25 - 12:45 0.33 WRLN Latch top of coil, Open bottom master to release the cal, weight increased 300 lbs. RIH with coil to set in XN nipple at 3997' KBD. 12:45 - 13:00 0.25 WRLN Coil sat down at 3895', work coil several times up and down felt through to 3998' KBD. Work spangs several times sheared. off of coil. 13:00 - 14:30 1.50 WRLN PU hole and work tool string down 10 times ko make sure cdl seated in XN nipple. POOH with GS. 14:30 - 15:00 0.50 WRLN OOH with GS, RD E-line unit. 15:00 - 15:30 WRLN Expro left lease. Opened up well to production. WHP=180 psig on long string, 60 psig on short string. Opened up short went to 0 psig. Long string had 180 psig, opened up long. started dropping, short string went up to 100 psig, switched back to the shat side. Both sides down to 5 psig, no water no rate. Left shut in to see if builds over night. 1/20/2007 08:00 - 08:30 0.50 RURD_ ELEC WRLN An-ive at KGF office and sign in and obtain work permit. 08:30 - 09:00 0.50 SAFETY MTG WRLN Arr"Ne on 41-7 Pad, hold PJSM with JSA and RU on Short String 09:00 - 09:15 0.25 TEST_ BOPE WRLN ' Pressure test lubricator to 500 psig 09:15 - 09:45 0.50 RUNPUL ELEC WRLN RIH w/jars, hydraulics and GS pulling tod 09:45 - 10:15 0.50 RUNPUL ELEC I WRLN Tagged CT ~ 3990'. Jarred w/ 1600# overpulf. Pulled out of rope socket. POOH i Pnnted~, 8l28f2C07 11.51 -.28 AM t Y ~ • Marathon Oil Company Page 15 Of 15 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: KENAI UNIT 11-8 kCENAI UNIT 11-8 WORK~VER GLACIER DRILLING GLACIER DRILLING Date 'From - To f Hours.. ~ Code i4 Sub i Phase 1/20/2007 10:15- 10:25 0.17 SAFETY MTG 10:25 - 10:40 0.25 RUNPUL ELEC 10:40- 12:30 1.83 WAITON EOIP 12:30- 13.:00 0,50 RURD_ SLIK 13:00- 13:30 0.33 RUNPUL SLIK I 13:20- 13:45 0.42 RUNPUL SLIK j 13:45 - 14:10 0.42 RUNPUL SLIK 14:10- 14:25 0.25 RUNPUL SLIK 14:25 - 14:45 0.33 RUNPUL SLIK 14;45- 15x.0 0.42 RUNPUL SLIK 15:10 - 15:25 0.25 RUNPUL SLIK 15:25-16:00 0.58 RURD_ SLIK 46:00- 16:30 0.50 RURD_ SLIK 16:30 - 17:00 0:50 RURD_ SLIK 17:00- 17:15 0.25 RURD_ SLIK 1/252007 07:30- 08:00 0:50 RURD_ ELEC 08:00-09:40 1.67 RURD_ ELEC 09:40 - 10:08 0.47 TEST_ ROPE 10:08 -11:05 0.95 LOG_ CSG_ 11:05 - 11:12 0.12 LOG_ _ CSG_ 11:12- 11:24 0.20 LOG CSG_ 11:24- 11:34 0.17 LOGr CSG ! 11:34 - 1'2:04 0.50 _ LOG CSG _ 12:04 - 12:14 0,17 LOGS CSG_ 12:14 - 13.:00 0.77 RURD_. ELEC 1126/2007 11:50- 12:15 0.42 SAFETY MTG 12:15 - 12:30 0.25 TEST ROPE 12:30 - 12:57 0.45 RUNPUL ELEC 12:57- 13:07 0.47 RUNPUL ELEC 13:07 - 13:08 0.02 RUNPUL ELEC 13:08-13:58 0;83 RUNPUL ELEC 13:58 - 13:59 0:02 RUNPUL ELEC 13:59- 14:09 0.17 RUNPUL ELEC 14:09- 14:15 0.10 RUNPUL ELEC 14:15 - 15:00 0.75 RURD_ ELEC 15:00 - 15:30 0:50 RURD_ ELEC 2/8/2007 07:00- 11:45 4.75 SAFETY MTG 11:45- 12:30 0.75 SAFETY MTG_ 12:30- 13:00 0.50 WORK SLIK 13:00- 13:05 1 0.081 WORK_1SLIK WRLN WRLN WRLN SLICK SLICK SLICK SLICK SUCK SLICK SUCK WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN LN LN 13:05- 13:30 0.42 WORK COIL WRLN 13:30- 14:15 0.75 SAFETY MTG_ WRLN 14:15 - 15:30 1.25 RURD SLIK WRLN Spud Date: 8/13/1982 Start: 3/7/2006 End: Rig Release: Group: Rig Number: 1 Description of operations Hold JSA to discuss pulling line out of hole OOH. WOO to fish tool string and rehead WO fishing tools from Expro Shop RU slickline unit and fishing tools to retrieve GS string Test lub to 500 psig. Start inhole w/ overshot Latch onto fish and POOH OOH. Returned w/fish. Rebuild GS tool Test lub to 500 psig. Start in hole w! GS pulling tool to attempt to fish CT Latch CT fish and jar (10 times} Fish pulled out of XN nipple CT BHA hanging upon WEG, unable to jar through Set down and sheared off (3902' KB} POOH OOH. RU e-Iine and W00 Decided CT tail is hanging on long string nipple RD equipment. Leave location and sign out. Arrive at KGF Office sign in and obtain work permit Arrive on Pad 41-7, PJSM, and RU Pickup PLT tool sti-ing pressure test to 500 psig Start in hole 90 ft/min logging ~, Stop ~ 4100' S min bench Set up tool 10 min bench ~ 4100' (in fluid} 'end bench POOH Start bench ~ surface End bench ~ surtace, RD mare to next job Arrive on Pad 41-7, Hold PJSM and RU Pick up PLT tool string and pressure test to 500 psig Start in hde (152 psig} SITP Start 10 min bench ~ 4100' end bench Start up pass 90'/min, POOH end up pass Start 10 min bench ~ surface end 10 min bench Shut in well RD Sign out, turn work permit in. Uptaihed work permit, started PJSM. All personnel shut down and were summoned to office for safety sand dauun and drug serach. Drug search over. Personnel were permitedd back to work. Spat equipment. Held PJSM and discussed procedure. PT lubricator to 500 psig. Good test. Open well. RIH with 1 3/4"tool string with oil jars, spang jars, stem and 3.5" GS. WHP= 150 psig, water tagged at 2171' KBD. Tagged fish at 3936' KBD. PU and latch fish. RIH with fish. Sat down at 3999 KBD, locate in XN nipple. Sheared GS, PUH, RIH several times to locate the coil extension in profile. POOH wdh tool string. OOH with tools, RD wire line unit, clean up around well head. Move to next well. Punted: 8/29/2007 11:51 28 AM . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AlU) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, Alaska 99611 \ tt5'J-- oq 1 Re: Kenai Gas Field, Sterling Gas Pool, KU 11-8 S d N be 306 331 ~~ ~'< 41 ¡pm' un ry urn r: -,~CANh~Er) Oc! ,;) J. ...~...~ Dear Mr. Mullin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisb" day of October, 2006 Encl. . /It ~~?)Þ6 . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 Marathon Oil Company September 22, 2006 Reference: 10-403 Sundry Notice Field: Kenai Gas Field Well: KU 11-8 RECE'VED SEP 2 7 2006 Alaska Oil & Gas Cons. Commission Anchorage ,,' 0 9 7 \ ~'ð\ Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Dear Mr. Aubert: Enclosed please find a Sundry Well Operations Notice Form 10-403, along with the associated attachments for the KU 11-8 well in the Kenai Gas Field. We have been unable to flow gas from Pool 4 in well KU 11-8 since the 2006 workover. We plan to cement plug the Pool 4 B-1 sand perforations and perforate Pool 3, A-11 sand. / Please refer to the attached operations procedure and proposed well bore diagram for more information. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, ~Ø~4tdL Michael A. Mulfu, '-'1 Senior Production Engineer Enclosures: 10-403 Sundry Well Schematic Operations Procedure cc: AOGCC Houston Well File Kenai Well File MAM ORIGINAL 20 MC 25.280 4hll!tlt~ nil A GAl r.nn~ ... 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate [] Waiver CAnchorage Other 0 Alter casing 0 Repair well 0 Plug Perforation&-8- Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool Œ1' j JG.~-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development [] Exploratory 0 82-97 ..........- 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20357/' 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 0 No [] KU 11-8 ../ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kenai Unit A-028142 21' Kenai Gas Field / Sterling Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5364' 4879' 5217' 4750' 4380' NIA Casing Length Size MD / TVD Burst Collapse Structural 132' 20",94#, H-40 132' 132' Conductor Surface 2000' 13-3/8",61#, K-55 2000' 1903' Intermediate Production 5362' 9-5/8",47#, N-80 5362' 4877' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4224' - 4279' 3840' - 3890' 3-1/2" 1 3-1/2" 9.2# N-80 4030' 1 4086' Packers and SSSV Type: Packers and SSSV MD (ft): None in current completion NIA 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program [] BOP Sketch 0 Exploratory 0 Development [] Service 0 15. Estimated Date for ,f;)t-06 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas [] Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael A. Mullin Printed Name Michael A. Mullin Title Senior Production Engineer .I Signature f~?:,~4~~~one (907) 283-1337 Date 22-Sep-06 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: <~ ()In - 3'3) Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8Ft 0 CT 0 9 2006 Subsequent Form Required: lO- 407. fíj. /rzt~ ~ ~~Sf'ONER APPROVED BY /ð,I-lIþ Approved by: THE COMMISSION Date: V '-'\LX ..J '\..I~--"L.. , . . , , t:.!µ ~\04. STATE OF ALASKA _ _ð~ /yr~v (f\ \1)) ALASW'OILAND GAS CONSERVATION COMMW'ON % V\ APPLICATION FOR SUNDRY APPROVALs=-r Form 10-403 Revised 06/2006 ~¿EivED(, 5ËP 2 7 2006 n Submit In Duplicate 132' 3 3/8" 61# K-55 BTC 2000' Cmt 1275 sks of Class G RT-GL=29' Detail Perforations 2' ELMD EZSV Cement retainer 4323' 5 10 Bbl Cement retainer with 5, Baker Model F-1 Prodn Packer 4363' 4380' 7. Wirel ine Guide 4382' Bailed Cement RKB to 4981' RKI Sand fill 5160' RKB to 5022' RKB Fill 5160' ELM 95/8" 47# N-80 5362' Cmt wi 1500 sks of Class G TD=5364' . . . , Marathon Oil Company Alaska Region KU 11-8 Kenai Gas Field, Pad 41-7 Plug back Pool 4 and perforate Pool 3 WBS # WO.06.13356.EXP History: KU 11-8 has been worked over (2006). All zones below the Pool 4 B-1 sand have been plugged back. The well was recompleted with dua13-1/2" tubing, no packer, both producing the same zone. We have been unable to produce gas from pool 4 after several weeks of unloading the well by cycling another well down the short string and flowing the long string. Objective: Cement pool 4 B-1 sand. Perforate Pool 3 A-II sand. Add a coiled tubing tailpipe to the bottom of the new perforations to keep the well unloaded. Procedure: 1. Contact Kenai Gas Field Office dailyfor work permit, discuss safety and environmental concerns. 2. Hold safety meeting each morning and discuss safety checklist. Establish e-line depth of TD: 3. RU Slickline on long string. Run 2.75" drift. Run TEL and locate tubing tail. Tag TD to establish a correlated TD depth based on the LS tubing tail depth of 4100' ELMD. Cement Pool 4: 4. RU BJ coiled tubing on Short string. 5. Tag TD. 41SÇ 6. Circulate cement from TD to ~ELMD (corrected to TD tag). NOTE: final / abandonment of the well will require more cement be placed above the B-1 sand. ¡µ 6A-- 7. POH CT Hang of CT tailpipe at surface: 8. Attach CT tailpipe BHA to bottom of 1.75" CT. 9. RIH 133' CT tailpipe. Space out will be measured from WEG to Nogo shoulder. 10. Cut CT tailpipe and attach X-lock hanger. 11. Hang off tailpipe in tree. 12. WOC minimum 12 hours. ORIGI~J . -, . . Reverse well dry: 13. Rig CT on to Long string. 14. RIR CT and tag cement top. 15. Pressure annulus and long string to 1500 psi with N2, taking returns from short string.. 16. Reverse circulate N2 down short string taking returns from CT until well is dry. Trap 150 psi on well. NOTE: all pressures should be equal on tubing strings and annulus. 17. POR CT. Perforate Pool 3: 18. RU E-line on long string. 19. RIH 2-3/8" 6 SPF guns. 20. Tie in to open hole logs. 21. Reduce pressure as per perforating instructions. 22. Shoot Pool 3 A-II sand as per perforating instructions from 4139' - 4150'. 23. POR. 24. RD e-line unit. Hang tailpipe with slickline: 25. RU slickline on short string. 26. Latch tailpipe in tree and PU tailpipe weight. 27. RIR tailpipe, hangoff on XN Nipple at 3997' RKB 28. Shear off tailpipe and paR 29. RD slickline. 30. Flow well through short string to unload any water. Contacts: Operations Geologist Reservoir Eng Mickey Mullin Jennifer Enos John Ozcan Work Phone (907) 283-1337 (713) 296-3319 (713) 296-2388 Cel 398-9954 ORIGINAL He e ðT/Í.3/0b e Alaska Region Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1305 Fax 907/283-1350 ,JuI11,2006 Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 RECE\VEO JUL 1 3 2006 I, 0'\ & Gas Cons. commission A\asr.a I Anchorage d: 0 q1 ,ct Reference: Report of Sundry Well Operations Field: Kenai Gas Field Well: KU 11-8 Dear Mr. Aubert, Enclosed please find a Report of Sundry Well Operations Form 10-404, along with the associated attachments for the KU 11-8 well in th Kenai Gas Field.. We have cemented all zones in Pool 6, Pool 5, an Pool 4 except for the B-1 sand as per our 10-403. We have recompleted the well as a d aI3-1/2" producer to a single zone. We have been unable to flow gas from the Pool 4, B-1 and. We will be submitting a 10-403 in a few days to plug back the B-1 sand and recomplet the well in Pool 3. If you require further information, please contact eat (907) 283-1337. Telephone: 907-398-9954 Email: MAMullin@MarathonOil.com Attachments: Form 409 Current wellbore diagram Operations Summary Report 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: Marathon Oil Company a STATE OF ALASKA _ ALASWOILAND GAS CONSERVATION COMM.ON JUL 1 3 2006 REPORT OF SUNDRY WELL OPERATIONS , . Alaska Oil & Gas Cons. Convnlsslon Repair Well Plug Perforations..¡ Stimulate Other Anchorage Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 4. Well Class Before Work: 5. Permit to Drill Number: Development 0 Exploratory 0 82-97 Stratigraphic 0 Service 0 6. API Number: 50-133-20357 RECE\VED 3. Address: PO Box 1949, Kenai Alaska, 99611 7. KB Elevation (ft): 9. Well Name and Number: 28.7' KU 11-8 8. Property Designation: 10. Field/Pool(s): Kenai Unit A-028142 11. Present Well Condition Summary: Kenai Gas Field 1 Sterling Total Depth measured 5364 feet true vertical 4879 feet Effective Depth measured 5217 feet true vertical 4750 feet Plugs (measured) 4323 Junk (measured) N/A Casing Structural Conductor Surface Intermediate Production Liner Length 132' Size 20",94#, H-40 MD TVD Burst Collapse 132' 132' 2000' 1930' 5362' 4877' 2000' 13-3/8",61#, K-55 BTC 5362' 9-5/8",47#, N-80 Perforation depth: Measured depth: 4224-4279 True Vertical depth: 3840-3890 Tubin9: (size, grade, and measured depth) Dual 3-1/2" 9.2# 4030' 1 4086' Packers and SSSV (type and measured depth) None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4336'-4358',4394'-4424',4467'-4522',5063'-5093' Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after work: Exploratory 0 16. Well Status after work: oilD Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl o o Tubing Pressure o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Development 0 Service 0 x WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or NIA if C.O. Exempt: 306-704 o Contact Michael A. Mullin Printed Name Michael A. Mullin Title Senior Production Engineer Phone (907) 398-9954 Date 11-Jul-06 Form 10-404 Revised 04/2006 ORIGINAL Post2006 workover Drive Pipe: 20" 94# H-40 @ 132' 133/8" 61# Casing @ 2000" Cmt wi 1275 sks of Class G Perforation Record Short $trinq Pool 4: B-1 4224'-4279' (8spf, 8/82) Squeezed Lonq Strinq Pool 5.1 : B 3 -1394' 4121' (8spf, 8/82) B 11167' 1522' (8spf, 8/82) *(B-3 & B-4, 85' net, Sqz'd 10/23/97 wi 186 bbl Maraseal) 5 RT-GL=29' Tubing Detail Otis XN Nipple@ 3997' (No-go:;::2.635") WEG @ 4030' RKB EZSV Cement retainer 4323' 10 Bbl Cement plug squeezed through retainer with rig. 5. Model Prodn Packer @ 436.3' 6. Otis XN Nipple @ 4380' (No-go:;::2.635") 7. Wireline Re-entry Guide @ 4382' Fill @ 5160' ELM (03/15/06) 9 5/8" 47# N-80 Csg @ 5362' Cmt wi 1500 sks of Class G TD:;::5364' e e Marathon Oil Company Pag~.1 of 10 Operations Summary Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8/13/1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Description of Operations CQ(f~ .. 3/8/2006 08:00 - 10:00 2.00 SAFETY MTG_ WBPREP Discuss JSA in great detail after standdown. Move to site and have prejob safety meeting. 10:00 - 14:30 4.50 RURD - SLlK WBPREP Spot equipment and wait on electricians to finish working close to wellhouse. 14:30 - 15:10 0.67 RURD SLlK WBPREP Finish rigging up Slickline. PT Lub 1 BOP with well pressure. 15:10 - 16:00 0.83 RUNPUL SLlK WBPREP RIH 2.72" gauge ring. Tag XN at 4185' corrected to RKB. Confirm we are on short string. 16:00 - 17:00 1.00 TAG - BOTM WBPREP RIH 2.15" gauge ring. Tag fill at 4280' RKB. Bottom B-1 perf is at 4278' eline. POH. 17:00 - 17:30 0.50 RURD - SLlK WBPREP Rig off short string and LD for night. 3/9/2006 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP Prejob safety meeting, Discuss crane interaction with slickline ands all topics on checklist. 08:30 - 10:10 1.67 RURD_ SLlK WBPREP Start equipment and RU slickline. PT Lub 1 BOP with well pressure. 10:10-11:00 0.83 BAIL_ FILL WBPREP RIH 2.5" drive down bailer. Tag fill at 4260'. Bail down to 4269' and POH. Dumped full bailer of sand. 11 :00 - 16:30 5.50 BAIL_ FILL WBPREP RIH 2.5" drive down bailer 6 times. Bail down to 4304' RKB. Dumped full bailers on each trip. Mostly sand, occasional silt. 16:30 - 17:00 0.50 REPAIR EQIP WBPREP Pump gasket failed. No Spill. Parts are not available until tomorrow morning. 17:00 - 18:00 1.00 RURD - SLlK WBPREP Rig back and LD for night. 3/10/2006 11 :00 - 11 :20 0.33 SAFETY MTG_ WBPREP Prejob safety meeting. Discuss all topics on checklist. 11 :20 - 11 :50 0.50 RURD - SLlK WBPREP Start equipment and RU slickline. PT Lub 1 BOP with well pressure. 11 :50 - 12:20 0.50 BAIL_ FILL WBPREP RIH 2.5" drive down bailer. Tag fill at 4306'. Bail down to 4309' and POH. Dumped full bailer of sand. 12:20 - 17:10 4.83 BAIL_ FILL WBPREP RIH 2.5" drive down bailer 7 times. Bail down to 4337' RKB. Dumped full bailers on each trip. Mostly sand, occasional silt. 17:10 -18:00 0.83 RURD - SLlK WBPREP Rig back and LD for night. 3/11/2006 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP Prejob safety meeting. Discuss all topics on checklist. 08:30 - 10:10 1.67 RURD_ SLlK WBPREP Start equipment and RU slickline. PT Lub 1 BOP with well pressure. 10:10 - 10:50 0.67 BAIL_ FILL WBPREP RIH 2.5" drive down bailer. Tag fill at 4337'. Bail down to 4340' and POH. Dumped full bailer of sand. 10:50 - 12:00 1.17 TRIP - TOOL WBPREP RIH 2.85" wire brush to 4298'. Clean area around sliding sleeve. POH brush. 12:00 - 13:00 1.00 TRIP - TOOL WBPREP RIH 2.75" shifting tool. Passes through sleeve indicating sleeve is closed. POH. Shifting tool is very dirty. 13:00 - 17:00 4.00 BAIL_ FILL WBPREP RIH 2.5" drive down bailer 5 times. Bail down to 4351' RKB. Dumped full bailers on each trip. Mostly sand and water, occasional silt. 17:00 - 18:00 1.00 RURD - SLlK WBPREP Rig back. Cut 100' of wire and retir head. LD for night. 3/12/2006 08:00 - 08:20 0.33 SAFETY MTG_ WBPREP Prejob safety meeting. Discuss all topics on checklist. 08:20 - 09:40 1.33 RURD_ SLlK WBPREP Start equipment and RU slickline. PT Lub 1 BOP with well pressure. 09:40 - 10:30 0.83 BAIL_ FILL WBPREP RIH 2.5" drive down bailer. Tag fill at 4352'. Bail down to 4355' and POH. Dumped full bailer of sand. 10:30 - 16:00 5.50 BAIL_ FILL WBPREP RIH 2.5" drive down bailer 8 times. Bail down to plug at 4374' RKB. Dumped full bailers on each trip except last trip came out empty. 16:00 - 17:00 1.00 RUNPUL SLlK WBPREP RIH 2-1/2" JDC. Latch equalizing prong at 4374'. POH prong. SITHP increased from 20 psi to 120 psi. 17:00 - 18:00 1.00 RURD - SLlK WBPREP Rig back. LD for night. 3/13/2006 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP Prejob safety meeting. Discuss all topics on checklist. 08:30 - 09:15 0.75 RURD SLlK WBPREP Start equipment and RU slickline. PT Lub 1 BOP with well pressure. 09:15 - 10:00 0.75 RUNPUL SLlK WBPREP RIH 2.5" drive down bailer. Tag plug at 4378' RKB. 10:00 - 10:40 0.67 RUNPUL SLlK WBPREP RIH 2.72" GS pulling tool. Tag sliding sleeve at 4297' RKB. Unable to pass SS 10:40 - 11 :30 0.83 RUNPUL SLlK WBPREP RIH 2.75" BO shifting tool. Tag sliding sleeve at 4297' RKB. Unable to Printed: 7/11/2006 9:44:05 AM e e Page 2 of 10 Marathon Oil Company Operations~Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/13/2006 3/14/2006 3/16/2006 3/21/2006 KENAI UNIT 11-8 KENAI UNIT 11-8 WORKOVER GLACIER DRILLING GLACIER DRILLING Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: From - To Hours 10:40 - 11 :30 0.83 WBPREP 11:30-12:15 0.75 WBPREP 12:15 - 13:00 0.75 WBPREP 13:00 - 15:10 2.17 REPAIR EQIP WBPREP 15:10 - 15:40 0.50 RUNPU SLlK WBPREP 13:00 - 15:10 2.17 RURD - SLlK WBPREP 09:15 - 09:45 0.50 SAFETY MTG_ WBPREP 09:45 - 10:30 0.75 RURD - SLlK WBPREP 10:30 - 11 :20 0.83 RUNPU SLlK WBPREP 11 :20 - 12:00 0.67 RUNPU SLlK WBPREP 12:00 - 12:30 WBPREP 12:30 - 12:50 WBPREP 12:50 - 13:10 0.33 WBPREP 13:10 - 13:35 0.42 WBPREP 13:35 - 14:30 WBPREP 14:30 - 15:10 WBPREP 15:10 - 15:20 WBPREP 15:20 - 16:00 WBPREP 16:00 - 17:00 WBPREP 17:00 -18:10 WBPREP 18:10 - 19:00 0.83 RURD SLlK WBPREP 07:00 - 07:30 0.50 SAFETY MTG - WBPREP 07:30 - 10:00 2.50 RURD - SLlK WBPREP 10:00 - 10:30 0.50 RURD - SLlK WBPREP 10:30-11:15 0.75 RUNPU SLlK WBPREP 11 :15 - 12:00 0.75 RUNPU SLlK WBPREP 12:00 - 13:00 1.00 BAIL FLD - WBPREP 13:00 - 16:37 3.62 LOG - OTHR WBPREP 16:37 - 17:00 0.38 LOG_ OTHR WBPREP 17:00 - 18:00 1.00 RURD SLlK WBPREP 08:00 - 08:30 0.50 SAFETY MTG_ PLUGAB 08:30 - 10:00 1.50 RURD_ CMT_ PLUGAB 10:00 - 10:30 0.50 RURD - SLlK PLUGAB 10:30-11:15 0.75 SAFETY MTG_ PLUGAB 11:15-13:45 2.50 RURD - CMT_ PLUGAB 13:45 - 14:22 0.62 PUMP_ CMT_ PLUGAB 14:22 - 16:00 1.63 WAlTON CMT_ PLUGAB 16:00 - 17:00 1.00 TAG_ BOTM PLUGAB 17:00 - 18:05 1.08 PUMP - CMT_ PLUGAB 18:05 - 18:28 0.38 PUMP - WTR_ PLUGAB Description of Operation$; close SS. RIH 2.75" BO shifting tool. Tag sliding sleeve at 4297' RKB. Unable to close SS. RIH 2.75" BO shifting tool. Tag sliding sleeve at 4297' RKB. Unable to close SS. Blew hydraulic hose. SD and repair hose. Replace hydraulic hose. Attempt to shift SS closed. No luck. POH. Rig back. LD for night and leave location. Prejob safety meeting. Discuss all topics on checklist. Start equipment and RU slickline. PT Lub 1 BOP with well pressure. RIH 3" braided line brush to 4300' RKB. Brush sliding sleeve and POH. RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS RIH 2.74" swage and tag plug at 4380'. POH RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS Bevel skirt on GS. RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS Run 2.75" BO shifting tool. Unable to shift sleeve. RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS Add weight bar and knuckle joints to tool string. RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS RIH 2.74" swage with 2.60" centralizer and tag plug at 4380'. POH RIH 2.72" GS pulling tool. Tag sliding sleeve at 4298' RKB. Unable to pass SS Rig back. LD for night and leave location. Prejob safety meeting. Discuss all topics on checklist. Start equipment. RU slickline. PT Lub 1 BOP with well pressure. RIH 2.5" JDC with bulldog spear. Spear PX plug and pulled loose in one hit. POH. No plug RIH 2.5" JDC with spiral spear. Spear PX plug and POH. RIH 2.5" DD bailer and tag TD at 5160'. Fliud level at 2000'. RIH with tandem PIT memory gauges. Make dynamic up down pass and stops. Check data quality. OK. Rig down and leave location. Prejob safety meeting. Discuss all topics on checklist. Spot cementing equipment to pump sand plug. Spot and RU Pollard slickline Prejob safety meeting. Discuss all topics on checklist. RU Cement pump and batch mixer. Pressure test lines and mix 3000# sand slurry (25 Bbls). Pump 25 Bbl sand slurry and displace with 38 Bbls KCI water. Well on vacuum. SD pump. Wait for sand to fall. RIH 2.55" GR and tag at 5124' RKB. POH SL. Mix gel and 3000# sand slurry. Pump 25 Bbl sand slurry and displace with 38 Bbls KCI water. Well on vacuum Printed: 7/11/2006 9:44:05 AM e e ;. Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date Hours C Sub Phase odéCode 3/21/2006 18:28 - 20:00 1.53 WAlTON CMT_ PLUGAB 20:00 - 21 :00 1.00 TAG_ BOTM PLUGAB 21 :00 - 22:00 1.00 RURD - SLlK PLUGAB 3/22/2006 08:00 - 09:15 1.25 SAFETY MTG_ PLUGAB 09:15 - 09:45 0.50 RURD - SLlK PLUGAB 09:45 - 10:25 0.67 TAG - BOTM PLUGAB 10:25-11:10 0.75 TAG - BOTM PLUGAB 11:10-13:25 2.25 RUNPU SLlK PLUGAB 13:25 - 14:00 0.58 SAFETY MTG - PLUGAB 14:00 - 15:45 1.75 RURD - CMT_ PLUGAB 15:45 - 16:28 0.72 PUMP - CMT_ PLUGAB 16:28 - 18:00 1.53 WAlTON CMT_ PLUGAB 18:00 - 18:35 0.58 TAG_ BOTM PLUGAB 18:35 - 19:00 0.42 RURD - CMT_ PLUGAB 3/23/2006 07:00 - 07:45 0.75 SAFETY MTG_ PLUGAB 07:45 - 09:45 2.00 RURD - SLlK PLUGAB 09:45 - 10:30 0.75 TAG_ BOTM PLUGAB 10:30 - 12:00 1.50 RURD - CMT_ PLUGAB 12:00 - 12:45 0.75 PUMP - CMT_ PLUGAB 12:45 - 14:00 1.25 DUMPB CMT_ PLUGAB 14:00 - 14:45 0.75 DUMPB CMT_ PLUGAB 14:45 -15:30 0.75 DUMPB CMT_ PLUGAB 15:30 - 16:30 1.00 DUMPB CMT_ PLUGAS 16:30 - 17:30 1.00 DUMPB CMT_ PLUGAB 17:30 - 19:30 2.00 RURD_ SLlK PLUGAB 3/24/2006 07:00 - 07:30 0.50 SAFETY MTG_ PLUGAB 07:30 - 08:00 0.50 RURD - SLlK PLUGAB 08:00 - 09:00 1.00 TAG_ BOTM PLUGAB 09:00 - 09:45 0.75 DUMPB CMT_ PLUGAB 09:45 - 10:30 0.75 DUMPB CMT_ PLUGAB 10:30 - 11 :00 0.50 SAFETY MTG_ PLUGAB 11 :00 - 12:00 1.00 DUMPB CMT_ PLUGAB 12:00 - 12:45 0.75 DUMPB CMT_ PLUGAB 12:45 - 13:30 0.75 DUMPB CMT_ PLUGAB 13:30 - 14:00 0.50 DUMPB CMT_ PLUGAB 14:00 - 14:45 0.75 DUMPB CMT_ PLUGAB 14:45 - 15:20 0.58 DUMPB CMT_ PLUGAB 15:20 - 16:00 0.67 DUMPB CMT_ PLUGAB 16:00 - 16:30 0.50 DUMPB CMT_ PLUGAB 16:30 - 17:00 0.50 DUMPB CMT - PLUGAB 17:00 - 17:45 0.75 DUMPB CMT_ PLUGAB 17:45 - 18:30 0.75 DUMPB CMT_ PLUGAB 18:30 - 19:00 0.50 DUMPB CMT_ PLUGAB 19:00 - 19:30 0.50 DUMPB CMT_ PLUGAB 19:30 - 20:15 0.75 DUMPB PLUGAB 20:15 - 21:15 1.00 DUMPB PLUGAB 21 :15 - 22:00 0.75 DUMPB PLUGAB 22:00 - 22:45 0.75 DUMPB PLUGAB 22:45 - 23:30 0.75 RURD - PLUGAB Page 3 of 10 Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: SD pump. Wait for sand to fall. RIH 2.55" GR and tag at 5088' RKBL. POH SL. Complete BJ rigdown. Rig down slickline and leave location. Issue permit. Prejob safety meeting. Discuss all topics on checklist. Spot and RU Pollard slickline RIH 2.5" swage and tag sand at 5089 RKB. .RU on short string. RIH 2.5" swage and tag sand at 4199' RKB. RIH X-lock and set in short string sliding sleeve. Prejob safety meeting. Discuss all topics on checklist. RU Cement pump and batch mixer. Pressure test lines and mix 3200# sand slurry (28 Bbls). Run prong and set in x-lock in short string sliding sleeve. Pump 28 Bbl sand slurry and displace with 45 Bbls KCI water. Well on vacuum. SD pump. Wait for sand to fall. RIH 2.55" GR and tag at 5030' RKB. POH SL. Complete BJ rigdown. Rig down slickline and leave location. Issue permit. Prejob safety meeting. Discuss all topics on checklist. Spot and RU Pollard slickline. Make up 2 ea 20' bailers RIH 2.5" swage and tag sand at 5022' RKB. Rig up to mix cement. Mix first 5 gal of cement and load bailer. RIH and dump bailer #1 at 5015' RKB. Fluid level at 1550. RIH and dump bailer #2 at 5015' RKB. RIH and dump bailer #3 at 5015' RKB. RIH and dump bailer #4 at 5015' RKB. RIH and dump bailer #5 at 5015' RKB. Rig back slickline for night and leave location. Issue permit. Prejob safety meeting. Discuss all topics on checklist. Spot and RU Pollard slickline. Pick up 2 ea 20' bailers RIH 2.5" swage and tag cement top at 5015' RKB. RIH and dump 20' X 2-1/2" bailer #6 at 5010' RKB. RIH and dump 20' X 2-1/2" bailer #7 at 5010' RKB. Stop job and discuss crane signaling and crane safety. RIH and dump 20' X 2-1/2" bailer #8 at 5005' RKB. RIH 20' X 2-1/2" bailer #9. Did not dump. RIH and dump 20' X 2-1/2" bailer #9 at 5005' RKB. RIH and dump 20' X 2-1/2" bailer #1 0 at 5000' RKB. RIH and dump 20' X 2-1/2" bailer #11 at 5000' RKB. RIH and dump 20' X 2-1/2" bailer #12 at 5000' RKB. RIH and dump 20' X 2-1/2" bailer#13 at 4995' RKB. PU bailer #14. Bailer dumped in tree. Flush tree and continue mixing. RIH and dump 20' X 2-1/2" bailer #14 at 4995' RKB. RIH and dump 20' X 2-1/2" bailer #15 at 4995' RKB. RIH and dump 20' X 2-1/2" bailer #16 at 4990' RKB. RIH and dump 20' X 2-1/2" bailer #17 at 4990' RKB. PU bailer #18. Bailer sheared stabbing onto tree. Flush tree and continue mixing. RIH and dump 20' X 2-1/2" bailer #18 at 4985' RKB. RIH and dump 20' X 2-1/2" bailer #19 at 4985' RKB. RIH and dump 20' X 2-1/2" bailer #20 at 4980' RKB. RIH and dump 20' X 2-1/2" bailer #21 at 4980' RKB. Rig back slickline for night and leave location. Printed: 7/11/2006 9:44:05 AM e e Marathon Oil Company Operations Sù'mm'8fy Report·· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/25/2006 PLUGAB Issue permit. Prejob safety meeting. Discuss all topics on checklist. PLUGAB Spot and RU Pollard slickline on long string. PLUGAB RIH 2.5" swage and tag cement top at 4981' RKB. PLUGAB RIH 2.75" shifting tool. Latch upper sliding sleeve at 4137'. Jar up. POH. Tool Sheared PLUGAB RIH 2.75" shifting tool. Latch upper sliding sleeve at 4137'. Jar up. Tool came free. latcxh back in to verify sleeve is open. Unable to pull free. Allow sleeve to equalize. Pull free and POH. Long Sleeve Open. Long string and annulus equalized. Rig off of long string and onto short string. RIH 2.50" JDC. Latch equalizing prong at 4130' RKB. Pull prong and POH. RIH 3" GS pulling tool. Shear Pin and POH. RIH 3" GS pulling tool. Pull plug body and POH. Hold safety meeting with Expro. Start spotting and rigging up Expro. RIH 2.75" shifting tool and latch sleeve. Jar up until pin sheared. POH. RIH 2.75" shifting tool and latch sleeve. Jar up until sleeve shifted. POH. Short string sleeve is open. Short string and annulus equalized. Rig back slickline and release. RU Eline. RIH 2.70" Jet cutter. Cut long string below dual packer at 4193' ELMD. Tag severed pipe. POH fired jet cutter. RD Expro and release. PJSM, load out al rig components, MIRU on KU 11-8 All major units spotted, commence plumbing I elect conn's. Move = 100%, RU = 50 %, Camp = 100 % PJSM, cont RU Glacier rig #1 on KU 11-8. Scope out mast, RU top drv torque tube, Make up all misc plumbing I elect conns. KENAI UNIT 11-8 KENAI UNIT 11-8 WORKOVER GLACIER DRILLING GLACIER DRILLING S.~ cøð:e 11:45-14:10 2.42 14:10 - 14:45 PLUGAB 14:45 - 15:15 PLUGAB 15:15 - 15:50 SLlK PLUGAB 15:50 - 16:20 0.50 RUNPU SLlK PLUGAB 16:20 - 16:40 0.33 SAFETY MTG_ PLUGAB 16:40 - 17:20 0.67 RUNPU SLlK PLUGAB 17:20 - 18:00 0.67 RUNPU SLlK PLUGAB 18:00 - 18:30 ELEC PLUGAB 18:30 - 19:45 TBG_ PLUGAB 19:45 - 20:15 0.50 RUNPU ELEC PLUGAB 20:15 - 21:00 0.75 RURD - ELEC PLUGAB 3/30/2006 12:00 - 06:00 18.00 RURD_ RIG_ MIRU 3/31/2006 06:00 - 06:00 24.00 RURD - RIG_ MIRU 4/1/2006 4/2/2006 4/3/2006 06:00 - 12:00 6.00 RURD_ RIG_ MIRU 12:00 - 16:00 4.00 NUND TREE WBPREP 16:00 - 00:30 8.50 NUND BOPE WBPREP 00:30 - 01 :00 0.50 SETREL TOOL WBPREP 01 :00 - 05:30 4.50 NUND BOPE WBPREP 05:30 - 06:00 0.50 TEST_ BOPE WBPREP 06:00 - 06:30 0.50 TEST_ BOPE WBPREP 06:30 - 12:00 5.50 TEST_ BOPE WBPREP 12:00 - 19:30 7.50 TEST_ BOPE WBPREP 19:30 - 20:30 1.00 CHANG EQIP WBPREP 20:30 - 23:30 3.00 TEST_ BOPE WBPREP 23:30 - 00:30 1.00 BLOWD CSG - WBPREP 00:30 - 03:00 2.50 TEST_ BOPE WBPREP 03:00 - 03:30 0.50 FLOW_ CHEK WBPREP 03:30 - 06:00 2.50 RURD - CSG_ CMPPUL 06:00 - 07:30 1.50 RURD - OTHR WBPREP 07:30 - 08:30 1.00 CIRC_ CFLD WBPREP Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: Desèription of OpeiàtioÀs No acc I dn time PJSM, cont RU Glacier rig #1 on KU 11-8. Accept Glacier rig #1 this date 1200 hrs. PJSM, test tree adptr fig, remove tree. PJSM, NU BOPE I all components. Pull BPVs, set TWCs for BOP test NU remainder BOPE. Slow going due to space limitations pertaining to dual string. (choke line up, ram doors, flow line etc) PJSM, attempt body test BOPE, TWCs leaking. Attempt re-test BOP, confirm TWCs leaking Fabricate test plugs for tbg hgr threads, install same. Plugs holding, test BOPE 250 I 2000 psi. Slow going, difficulty aligning dual string with rams. PJSM, Decision to pull tbg as single strings, change to 3 1/2 single rams. PJSM, re-test 3 1/2 ram set I BOP 250 12000 psi. Bleed 3 1/2 tbg X 9 5/8 csg annulus, 250 to 0 psi. Complete test BOPE (floor valves, mud lines) 250 12000 psi PJSM, flow check well while blow dn surface equip. PJSM, RU floor for 3 1/2 tbg pull, while steam cellar for mouse hole. Rig up for circulation and displacement of wellbore fluids. PJSM, attempt circ 6% KCL brine dn long string 3 1/2 tbg. No success, losses 264 bbls, no returns. Printed: 7/11/2006 9:44:05 AM e e Page 5 of 10 Marathon Oil Company.· ':> :", "<' ,', "',' ..... . Operations SlImmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/3/2006 4/4/2006 4/5/2006 3.50 CIRC_ CFLD WBPREP Mix I pump, attempt circ with 3% KCL brine. Partial returns, losses approx 50 bph. Total losses 310 bbls 1.50 RURD SLlK WBPREP PJSM, RU slickline for sliding sleeve work. 4.50 WORK SLlK WBPREP RIH slickline, close sliding sleeves long I short strings tbg. Confirm closed. RD slickline, release unit. Spot 15 bbls LCM (3 ppb HEC, 1 ppb Flo Vis, 30 ppb safecarb 40) dn long string below pkr. Soak LCM to wellbore Fill long I short string from surface dn tbg hgr with 60 bbls LCM (3 ppb HEC, 1 ppb Flo Vis, 30 ppb safecarb 40) Follow LCM, fill well bore with 3% KCL brine. Initial static loss with LCM 35 bph, decreasing to "0" bph, no static loss. PJSM, RU wireline for tbg cut. RIH 2.70 jet cutter on wireline, CCL, locate sliding sleeve, PJSM, cut short string tbg, 8 ft above sleeve (4130 ft) POH wireline, Temporarily RD wireline equip. Flow check, fluid column static, work tbg, pull tbg free with 55K over. Flow check, well static. Pull hgr to floor, difficult due to sticking I chattering I 25 - 45K over. Remove split hgr KENAI UNIT 11-8 KENAI UNIT 11-8 WORKOVER GLACIER DRILLING GLACIER DRILLING From,..To Houts Code ð~dbe Phase 08:30 - 12:00 12:00 - 13:30 13:30 - 18:00 18:00 - 18:30 18:30 - 19:00 0.50 RURD SLlK WBPREP 0.50 PUMP - LCM - WBPREP 1.00 PUMP - LCM_ WBPREP 2.00 PUMP_ LCM - WBPREP 19:00 - 20:00 20:00 - 22:00 22:00 - 23:00 1.00 RURD_ ELEC CMPPUL 23:00 - 00:30 1.50 CUT_ TBG_ CMPPUL 00:30 - 01 :00 0.50 CUT_ TBG - CMPPUL 01 :00 - 02:30 1.50 REPAIR RIG_ CMPPUL 02:30 - 06:00 3.50 PULD - TBG_ CMPPUL 06:00 - 10:00 4.00 PULD - TBG_ CMPPUL 10:00 - 10:30 0.50 PULD - PKR_ CMPPUL 10:30 - 17:00 6.50 PULD_ TBG_ CMPPUL 17:00 - 17:30 0.50 RURD OTHR CMPPUL 17:30 - 18:00 0.50 CHANG EQIP CMPPUL 18:00 - 18:30 0.50 REPAIR RIG_ CMPPUL 18:30 - 20:30 2.00 RURD_ OTHR CMPPUL 20:30 - 00:00 3.50 PULD - BHA_ CMPPUL 00:00 - 01 :00 1.00 PULD - BHA_ CMPPUL 01 :00 - 06:00 5.00 TRIP - DP - CMPPUL 06:00 - 07:00 1.00 SERVIC RIG_ CMPPUL 07:00 - 08:30 1.50 TRIP _ DP_ CMPPUL 08:30 - 09:00 0.50 CLNOU CSG_ CMPPUL 09:00 - 12:30 3.50 CLNOU CSG_ CMPPUL 12:30 - 13:00 0.50 REPAIR RIG - CMPPUL 13:00 - 19:00 6.00 WASH FILL CMPPUL 19:00 - 20:30 1.50 CIRC_ CFLD CMPPUL 20:30 - 00:30 4.00 TRIP - DP - CMPPUL Start: Rig Release: Rig Number: Spud Date: 8/13/1982 End: Group: 3/7/2006 Description of Operations Repair leaking "grabber" top drive. PJSM, POH laying dn short string 3 1/2 tbg. Slow going, re-cip tbg, work free various intervals. No losses. 60 jts 3 1/2 tbg layed dn at 0600 hrs. Cont. POH Laying Down Short String 135 jts 3112 Tubing, 7 Pups and 22.50' Of Cut Jt. Retrieval 100%, No Losses. PJSM; Work& Pull Packer Free ( Long String) W 55k Over Pull 2X. String Wt. 55k Up 40K Dn. 45k Static. PJSM; POH UD Long String 136 jts 31/2 Tubing WI Packer 119 ft cut tbg, Normal drag. Slight fluid loss to well bore RID Weatherford Tubing Handling Tools CIO Bails Repair top drive (grabber box) PJSM, Clear floor, RU for washpipe. PJSM, MU 7518 washpipe, 179 ft, RIH same Follow wash pipe with 6 1/4 BHA. Flow check, Follow BHA with 5" DP to 3444 ft at 0600 hrs. Correct DP displacement, no losses. PJSM; Lube Rig, Top Drive, Carrier, Blocks& Crown TIH F-3444' T/4169' Correct DP Displacement. No Losses Break Circulation W 100 SPM 1195 GPM/1 OOpsi Circ Wash F 4169 T- 4216'( Tag Up On Fill) Wash over blastjts. from 4216 to 4240' Tq. 8k T/9k. Circulate at 195 gpm 100spm 100psi. Lose 75 bbls 11 hr, pump LCM I sweep, regain 100% circ. Note: .5% EP lube added to combat hi torque initially. Torque reduced approx 75% instantly. Change Grabber Dies On Top Drive Circ. & Wash over blast jts from 4240' to 4359' Circ pump sweep @ 4359'. Circulate bottoms up 2x. Pump and spot HEC-10 Lcm pill. Monitor Well, Well Staticl No Losses. POH to washpipe from 4359' to Printed: 7/11/2006 9:44:05 AM e e " " Page 60f 10 Marathon Oil Company Operations Summary Report 512' No Fluid Loss To Hole. Correct hole hill and normal Tql Drag. PJSM, flow check, LD washpipe. MU overshot assy (8 1/8, 33/4 mill I grapple). Flow check, RIH same. Flow check, follow BHA with 5" DP. 1200 ft at 0600 hrs. Continue TIH WI Overshot Mill Assy. F- 1200' To 4180' No LosslGain Correct hole Displacement. Circ. Work! Mill Over 3112 Tubing Cut Jt At 4193' Set 50k Down Wt To Capture Fish. Pull Fishl Blast Jt. Seal Assy. From Packer. Confirm Capture WI 5K Over PIU Wt Of 11 Ok. PJSM; POH At Reduced Hoisting Rate Due To possiable Recovery Of 3 1/2 Tubing Cut JT. And Blast Jts. POH UD BOT Fishing Assy BHA To 8 1/8 Over Shot PJSM: Break Dowm Overshot Grapple Assy wI Recovered 3 1/2 Tubing Cut Jt. 8 Blastjts , BOT, Seal Assy And 1/20' Tubing Tail Pipe. For A Total Of 170' Of Fish Recovered UD 2 6 1/4 Drill Collars Clean Rig Floor Lube Rig, Top Drive Carrier, Blocks Crown PJSM; WI Expro WLS And Rig Up Same Run Expro Gamma Ray, Correlated To Dual Induction Focused Log Confirm Upper Perf F- 4224-4279 MD Lower Perfs F 4336- 4358 MD.Packer At 4361' MD. UD 6 6114 Drill Collars PJSM; WI Howco. MIU Howco 9 5/8 Setting Tool And EZ Drill Packer TIH W 9 5/8 EZ Drill Retainer on Drill Pipe To 4350' Tag Packer At 4361' PIU To 4323' Setting Dept Of Retainer. No GainlLosses Correct Displacement Break Circulation At 4323' Confirm Depth And Set Howco 9 5/8 EZ Drill Retainer at 4323' Set Tool By Rotating 35X Set Dogs. PU 125K, 140k, And Release At 150k Normal Up WT. 100k. Rotate 25x To Unlatch Setting Tool. Sting Into Retainer At 4323' 0.50 RURD_ CMT _ PLUGAB PJSM; W BJ IRig Up Cmt Line And Pump In Sub 1.00 SQUEZE CMT _ PLUGAB Test Cement Lines To 2700psi. Establish Injection Rate Of 3 bbl Per Min @ 600 psil Dec To 345 psi. Commence pumping Cement At 3bbls Per Min At 345psi Pump 10 bbls Cmt. Displace W 76 bbl 8.6 Kcl.( Displacement Of Drillpipe) Final Psi Of 502psi Pull Out Of EZ Drill Retainer, Pump 2bbl 8.6 KcI Reverse Circulate Clear Drillpipe Of cement 1666 Stks 76 bblsAt 4320' Trace Of Cement To Surface. Circ At 3bbl per Min 165psi. RID Cement Line And Pump In Sub, Circulate Long Way at 4320' 3bbl Per Min 165psi 65spm Clean Pitsl Build Volume For Hole Displacement Clean Pitsl Mix 6% KCL Compleation Fluid w/1% Conqor A303 Corr. Inhibitor Circ Displace Well Bore Fluid W 6 % KCL. Displace At 68spm 3bbl. Per Min. 350psi. 328bbls. Total. Weekley Safety Meeting Repair 5" Drillpipe Elevators PJSM POH UD 5" Drillpipe F-4323. Fluid Loss To Hole 5bbl Per Hr. PJSM; CIO 3 1/2 Rams To 3 1/2 Dual Rams. And Test 3 1/2 And Blind Rams 250/2000 psi. For 5 Min. (Test SuccessfuL) , Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code ~ub Phase ~ode 4/5/2006 20:30 - 00:30 4.00 TRIP - DP_ CMPPUL 00:30 - 03:00 2.50 PULD - BHA_ CMPPUL 03:00 - 05:00 2.00 PULD - BHA_ CMPPUL 05:00 - 06:00 1.00 TRIP - DP_ CMPPUL 4/6/2006 06:00 - 07:30 1.50 TRIP - DP - CMPPUL 07:30 - 08:00 0.50 MILL_ FISH CMPPUL 08:00 - 12:30 4.50 TRIP - DP - CMPPUL 12:30 - 13:30 1.00 PULD - BHA_ CMPPUL 13:30 - 14:30 1.00 PULD - TBG_ CMPPUL 14:30 - 16:00 1.50 PULD_ BHA_ PLUGAB 16:00 - 16:30 0.50 SERVIC RIG_ PLUGAB 16:30 - 17:00 0.50 RURD ELEC PLUGAB 17:00 - 19:00 2.00 RUNPUL ELEC PLUGAB 19:00 - 20:00 1.00 PULD - BHA_ PLUGAB 20:00 - 21 :00 1.00 PULD - PKR_ PLUGAB 21 :00 - 00:30 3.50 TRIP - TOOL PLUGAB 00:30 - 01 :00 0.50 CIRC_ CFLD PLUGAB 01 :00 - 01 :30 0.50 SETREL TOOL PLUGAB 01 :30 - 02:00 02:00 - 03:00 03:00 - 03:30 0.50 CIRC_ CFLD PLUGAB 03:30 - 05:00 1.50 CIRC_ CFLD PLUGAB 05:00 - 06:00 1.00 CLEAN - TANK PLUGAB 4/7/2006 06:00 - 09:30 3.50 CIRC_ CFLD PLUGAB 09:30 - 12:00 2.50 CIRC_ CFLD PLUGAB 12:00 - 13:00 1.00 SAFETY MTG_ PLUGAB 13:00 - 14:00 1.00 REPAIR RIG_ PLUGAB 14:00 - 18:00 4.00 PULD_ DP - PLUGAB 18:00 - 20:00 2.00 TEST_ BOPE CMPRUN Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: Oescription of Operations Printed: 7/11/2006 9:44:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Fromr¡;.. To 4/7/2006 20:00 - 22:30 22:30 - 00:00 00:00 - 04:00 04:00 - 06:00 e e Marathon Oil Company OperaUons Summary R'eport KENAI UNIT 11-8 KENAI UNIT 11-8 WORKOVER GLACIER DRILLING GLACIER DRILLING ~ur's C6dei Stib Code Phase 2.50 RURD_ OTHR 1.50 RURD_ CSG_ 4.00 INSPCT TUBE 2.00 RUNPU TBG_ CMPRUN CMPRUN CMPRUN CMPRUN 4/8/2006 06:00 - 12:00 6.00 RUNPU CMPRUN 12:00 - 13:00 1.00 RUNPU CMPRUN 13:00 - 16:30 3.50 RUNPU CMPRUN 16:30 - 19:30 3.00 RUNPU TBG_ CMPRUN 19:30 - 05:30 10.00 RUNPU TBG - CMPRUN 05:30 - 06:00 0.50 RUNPU TBG_ CMPRUN 4/9/2006 06:00 - 16:00 10.00 NUND BOPE CMPRUN 16:00 - 19:30 3.50 NUND TREE CMPRUN 4/10/2006 5/2/2006 5/5/2006 19:30 - 06:00 06:00 - 06:00 10.50 RURD_ RIG_ RDMO 24.00 RURD_ RIG_ RDMO 09:00 - 10:00 1.00 SAFETY MTG_ WRLN 10:00 - 11 :35 1.58 RURD - SLlK WRLN 11 :35 - 12:35 1.00 RUNPU SLlK WRLN 12:35 - 13:15 0.67 RUNPU SLlK WRLN 13:15 - 14:00 0.75 RURD_ SLlK WRLN 12:30 - 13:20 0.83 SAFETY MTG_ CMPFLW 13:20 - 15:30 2.17 RURD - OTHR CMPFLW Page? of 1Q Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: Descriptipn ofOper~üçns RlDDrillpipe Handling Tools, Spinners, Bails Mouse Hole, And Rig Floor PJSM; RlU Weatherford 3 1/2 Dual Tubing String Handling Tools. PJSM; Load Pipe Rack WI 3 1/2 Tubing Drift And Tally Same. PJSM; Run 3 1/2 Dual Tubing String, Long String 3 1/2 L-80 9.2ppf 8 RD,- Short String 3 1/2 L-80 9.2 ppf 511 Hydril. Fluid Loss To Hole 12 bbl per Hr. PJSM; Run 3 1/2 9.2ppf L-80 Dual Tubing String. Long String 3 1/2 IBTI Short String 3 1/2 Hydril 511. RIH TO 745' Work dual string at 745' string space out would not allow collar on long string to pass XN nipple on short string. PJSM; WI Weatherford POH UD dual tubing string adjust space out to place XN nipple on short string above collar on long string. Run 3 1/2 Dual Tubing Completion String To 745' Continue To Run 3 1/2 Dual Completion String Total Of 4085.63'1 128Jts Of 3 1/29.2# MBT Tubing In Long String And 4029' 127Jts Of 3 1/29.2# L-80 511 Hydril Tubing In Short String. XN Nipple In Long String Set At .4053.11' Wire Line Entry Guide Set At 4085.63'1 XN Nipple Set At 3996.98' In Short String Wire Line Entry Guide Set At 4029.63' 10 bbl Per Hr. Fluid Loss To Hole While Running Completion String. MIU Dual Hanger And Landing Joint/Land Dual Tubing CompletionStringl W 60K Set On Well Head. Set Back Pressure Valves. Test Hanger Seals To 5000psi F- 10 Min. Test Good. PJSM ; Remove Rams From Stack, N/D BOPE. Flush Mud System, RID Flow Lines, Choke And Kill Lines, Trip Tank. N/U Tree, Test Void TO 5000 Psi F- 10 Min (Test Good) Test Short String Tree To 5000 psi ( Test Good) Test Long String To 5000psi F- 10 Min. (Test Good) Note Cresent Flange On Short String Leaked. PJSM: Remove Kelly Hose, Mud Manfold, Choke And Kill Line Manifold. RID & UD Top Drive. RID Torque Tube Derrick Board, Pull Tong Counter Weights Prep Derrick For Removal From Carrier. PJSM:Continue Rig Down. Disconnect all Elect/ Plumbing Break Down All Major Unitsl Prep Mast For Scope Down. Begin Crane Work PJSM; RID & Set Out Dog, Choke Houses And Wind Walls Scope And Lay Down Mast. RID Boiler GeneratorAnd Water Tank Units. RID Out Riggers And Scope Down Sub. All Rig Componants Ready For Load Out. Rig Released From KU 11-8 At 0600HR. 4/10/2006 Note; Remove Mast From Carrier Due To 75% Load Limits Imposed Upon State Roads. Uptain work Permit, Held TGSM, Discussed Job and Safe Well Practices Rig up wireline on high valve side of tree RIH wI 2.75" Gauge Ring to 3977' WL to verify length of string, POOH RIH wI 2.75" Gauge Ring to 4038' WL (this tag was the long string, labeled valves, low valves on tree) Rig Down wireline, Depart location Uptain work Permit, Held TGSM, Discussed Job and Safety checklist. Discussed N2 handling Rig up N2 pump line to inner annulus (9-5/8" X 3-112") Printed: 7/11/2006 9:44:05 AM e e Page 8 of10 Marathon Oil Company Operations Summery Report Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From.... To ..... ..... / ...\ $ilb Phase f7/ours Ggde Çod~. 5/5/2006 13:20 - 15:30 2.17 RURD - OTHR CMPFLW 15:30 - 15:45 0.25 TEST_ EQIP CMPFLW 15:45 - 17:00 1.25 PUMP _ N2_ CMPFLW 17:00 - 18:00 1.00 RURD_ OTHR CMPFLW 5/24/2006 08:00 - 09:00 1.00 SAFETY MTG_ SLICK 09:00 - 10:10 1.17 RURD - SLlK SLICK 10:10 - 10:30 0.33 RUNPU SLlK SLICK 10:30 - 11 :30 1.00 RUNPU SLlK SLICK 11 :30 - 12:20 0.83 SLlK SLICK 12:20 - 13:10 0.83 RUNPU SLlK SLICK 13:10 - 14:15 1.08 RUNPU SLlK SLICK 14:15 - 15:20 1.08 RUNPU SLlK SLICK 15:20 - 16:15 0.92 RUNPU SLlK SLICK 16:15 - 17:10 0.92 RUNPU SLlK SLICK 17:10-18:00 0.83 RURD - SLlK SLICK 5/25/2006 08:00 - 09:15 1.25 SAFETY MTG_ CMPFLW 09:15 - 09:40 0.42 RURD - SLlK CMPFLW 09:40 - 09:55 0.25 BAIL_ FLD - CMPFLW 09:55 - 10:20 0.42 BAIL_ FLD - CMPFLW 10:20 - 11:20 1.00 BAIL_ FLD - CMPFLW 11 :20 - 12:30 1.17 BAIL_ FLD_ CMPFLW 12:30 - 14:15 1.75 BAIL_ FLD - CMPFLW 14:15 - 15:45 1.50 BAIL_ FLD - CMPFLW 15:45 - 16:30 0.75 BAIL_ FLD - CMPFLW 16:30 - 17:10 0.67 BAIL_ FLD_ CMPFLW 17:10-17:30 0.33 RURD - SLlK CMPFLW 5/26/2006 07:30 - 07:45 0.25 SAFETY MTG - CMPFLW 07:45 - 08:10 0.42 RURD - SLlK CMPFLW 08:10 - 09:35 1.42 BAIL_ FLD - CMPFLW 09:35 - 11 :05 1.50 BAIL_ FLD - CMPFLW 11 :05 - 12:40 1.58 BAIL_ FLD - CMPFLW 12:40 - 14:30 1.83 BAIL_ FLD - CMPFLW Start: 3/7/2006 Rig Release: Rig Number: 1 Spud Date: 8/13/1982 End: Group: Description of Operations. Pressure test treating lines to 2500 psi. Good test. Bullhead 1200 gal N2 down annulus taking returns up long string. Recovered 15 bbls water. Blew well to 0 psi. Rig Down N2 unit, Depart location Uptain work Permit, Discussed Job and Safety checklist. Rig up slickline unit, pressure test lab and BOP - test good RIH wi 40' 2-1/2" DD Bailer to 4150' KB, Let set POOH bailer has Cement Chunks RIH wi 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wi 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4200, POOH, Bailer Full of Water (3 RUNS) Rig Down and Clean up for the night, sign out Arrive, Uptain work Permit, Discussed Job and Safety checklist. Rig up slickline unit, pressure test lab and BOP - test good RIH wI 40' 2-1/2" DD Bailer to 4000, POOH, Bailer Full of Water (1 RUN) RIH wI 40' 2-1/2" DD Bailer to 4000, POOH, Bailer 1/2 Full of Water (2 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4100, POOH, Bailer Full of Water (4 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4100, POOH, Bailer Full of Water (4 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4100, POOH, Bailer Full of Water (4 RUNS), Wireline Hydraulics Overheating cooling off time. RIH wI 40' 2-1/2" DD Bailer to 4100, POOH, Bailer Full of Water (4 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4100, POOH, Bailer Full of Water (2 RUNS) RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (3 RUNS) Rig Down and Clean up for the night, sign out Arrive, Uptain work Permit, Discussed Job and Safety checklist. Rig up slickline unit, pressure test lab and BOP - test good RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 33Gal Water Retrieved RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 38Gal Water Retrieved RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 33Gal Water Retrieved RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 35Gal Water Retrieved Printed: 7/11/2006 9:44:05 AM e e Marathon Oil Company Operations $ummary R~port Page 9 of 10 Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Spud Date: 8/13/1982 Event Name: WORKOVER Start: 3/7/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: Date From - To Hours iCode Sub Phase. fi)escriptiôn ôf OpeFratio~s Coôe 5/26/2006 14:30 - 16:10 1.67 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" OD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 33Gal Water Retrieved 16:10-17:00 0.83 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (3 RUNS) 19Gal Water Retrieved, Total of 191 Gal. Water and 23' of Fluid level 17:00 - 17:30 0.50 RURD SLlK CMPFLW Rig Down and Clean up for the night, sign out 5/29/2006 07:30 - 07:45 0.25 SAFETY MTG_ CMPFLW Arrive, Uptain work Permit, Discussed Job and Safety checklist. 07:45 - 08:10 0.42 RURO - SLlK CMPFLW Rig up slickline unit, pressure test lub. and BOP - test good 08:10 - 09:30 1.33 BAIL_ FLO - CMPFLW RIH wI 40' 2-1/2" OD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 38Gal Water Retrieved 09:30 - 11 :05 1.58 BAIL_ FLO - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 38Gal Water Retrieved 11 :05 - 12:40 1.58 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 36Gal Water Retrieved 12:40 - 14:35 1.92 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (5 RUNS) 38Gal Water Retrieved 14:35 - 14:55 0.33 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4250, POOH, Bailer Full of Water (1 RUN) 7Gal Water Retrieved 14:55 - 15:40 0.75 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4150, POOH, Bailer Full of Water (2 RUNS) 14Gal Water Retrieved 15:40 - 16:45 1.08 BAIL_ FLO_ CMPFLW Standby while production pressures up on well. Bullhead well push remaining water into formation 16:45 - 17:00 0.25 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4250, POOH. Bailer Full of Water (1 RUN) 7Gal Water Retrieved 17:00 - 17:30 0.50 RURD - SLlK CMPFLW Rig Down and Clean up for the night, sign out 5/31/2006 07:40 - 08:00 0.33 SAFETY MTG - CMPFLW Arrive, Uptain work Permit, Discussed Job and Safety checklist. 08:00 - 08:45 0.75 RURD - SLlK CMPFLW Rig up slickline unit, pressure test lub. and BOP - test good 08:45 - 09:10 0.42 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4270' GL, POOH, Bailer 1/2 Full of Water (1 RUN) 09:10 - 10:00 0.83 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4200' GL, POOH, Bailer No Water, Noting water level is deeper than 4200' WL 10:00 - 10:23 0.38 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4240' GL, POOH, Bailer 1/4 Full of Water (1 RUN) 10:23 - 10:43 0.33 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4284' GL, POOH, Bailer Full of Water (1 RUN) 10:43 - 11 :00 0.28 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4280' GL, POOH, Bailer No Water (1 RUN), Cleaned out bailer check ball clogged with frac sand. (Total water 5 runs=11 gal) 11 :00 - 12:40 1.67 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4280' GL, POOH, Bailer Full of Water (5 RUNS) 33Gal Water Retrieved 12:40 - 14:20 1.67 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4280' GL, POOH, Bailer Full of Water (5 RUNS) 30Gal Water Retrieved 14:20 - 15:20 1.00 BAIL_ FLO - CMPFLW RIH wI 40' 2-1/2" DO Bailer to 4280' GL, POOH, Bailer Full of Water (3 RUNS) 15:20 - 16:00 0.67 BAIL - FLD - CMPFLW RIH wI 40' 2-1/2" OD Bailer to 4280' GL, POOH, Bailer 1/2 Full of Water (2 RUNS) (23Gal in 5 Runs) 16:00 - 16:45 0.75 BAIL_ FLD_ CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4280' GL, POOH, Bailer 1/2 Full of Water (2 RUNS) (10Gal in 2 Runs) 16:45 - 17:15 0.50 RURD - SLlK CMPFLW Rig Oown and Clean up for the night, sign out 6/1/2006 07:30 - 07:40 0.17 SAFETY MTG_ CMPFLW Arrive, Uptain work Permit, Discussed Job and Safety checklist. 07:40 - 08:00 0.33 RURD - SLlK CMPFLW Rig up slickline unit, pressure test lub. and BOP - test good 08:00 - 08:15 0.25 BAIL_ FLD - CMPFLW RIH wI 40' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer 1/4 Full of Water (1 RUN) Printed: 7/11/2006 9:44:05 AM e e MarathQn Oil Company . Operations Summary fi~pon Legal Well Name: KENAI UNIT 11-8 Common Well Name: KENAI UNIT 11-8 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From .i!'·.·To Hour$ Co¿fe .. Sub. Cod~ 6/1/2006 08:15 - 08:40 0.42 BAIL_ FLD - CMPFLW 08:40 - 09:25 0.75 BAIL_ FLD - CMPFLW 09:25 - 10:35 1.17 BAIL_ FLD - CMPFLW 10:35 - 11 :00 0.42 BAIL_ FLD_ CMPFLW 11:00 -11:15 0.25 BAIL_ FLD_ CMPFLW 11:15 -11:45 0.50 BAIL_ FLD - CMPFLW 11 :45 - 12:40 0.92 BAIL_ FLD_ CMPFLW 12:40 - 15:00 2.33 BAIL_ FLD - CMPFLW 15:00 - 17:00 2.00 RURD_ SLlK CMPFLW 6/8/2006 08:00 - 09:00 1.00 SAFETY MTG_ CMPFLW 09:00 - 10:00 1.00 RURD_ ELEC CMPFLW 10:00 - 10:20 CMPFLW 10:20 - 11 :20 CMPFLW 11 :20 - 11 :45 0.42 RUNPU ELEC CMPFLW 11 :45 - 12:00 0.25 RURD - OTHR CMPFLW Start: 3/7/2006 Rig Release: Rig Number: 1 pescrìptic)n Spud Date: 8/13/1982 End: Group: RIH wI 40' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer 1/2 Full of Water (1 RUN), Remove 20' of Bailer RIH wI 20' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (3 RUNS), 14 Gal Water Removed RIH wI 20' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (5 RUNS), 13 Gal Water Removed RIH wI 20' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (2 RUNS) RIH wI 20' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (1 RUN), Remove 10' of Bailer RIH w/1 0' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (2 RUNS), 10 Gal Water Removed RIH wI 10' 2-1/2" DD Bailer to 4275' GL, POOH, Bailer Full of Water (4 RUNS) (2) full (2) half Full of Water RIH wI 10' 2-1/2" DD Bailer to 4280' GL, POOH, drive shaft broke on wireline pto, got a new one and had it replaced and continued out of the hole. Rig Down and Clean up for the night, give well back to production, sign out Uptain work Permit, Held TGSM, Discussed Job and Safety checklist. Discussed nesting Terns on pad. Rig up Expro E-line to run PIT log. RIH PIT string. Fluid level at 3930' ELMD. LS XN at 4067' ELMD. SS XN @ 4012' ELMD. POH E-line. Rig Down E-line unit, move to KBU 42-6 Printed: 7/11/2006 9:44:05 AM 1r~1rŒ (m~~[L~ Œ e AIfASIiA. OIL AND GAS CONSERVATION COMMISSION / I / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael A. Mullin Advanced Production Engineer Marathon Oil Company P.O. Box 1949 Anchorage, Alaska 99611 \ q¡.-- 00(7 Re: Kenai Gas Field KU 11-8 Sundry Number: 306-074 [ (',' ( t! (~ Dear Mr. Mullin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. Sincerely, Chai DATED this~ day of February, 2006 Enc!. e e Alaska Region Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1305 Fax 907/283-1350 Jan 17,2006 RECEIVE Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 FEB 2 7 2006 Alaska Oil & Gas Cun~~ Anchorage Reference: Application for Sundry Approval Field: Kenai Gas Field Well: KU 11-8 Dear Mr. Aubert, Enclosed please find a Application for Sundry Approval, along with the associated attachments for the KU 11-8 well in the Kenai Gas Field. This sundry replaces the sundry that was submitted for this workover on Jan 18, 2006. I apologize for the confusion and the / need to resubmit the sundry. We will be cementing the pool 6 perforations on the long string, pulling the dual completion, Squeezing through an EZSV below Pool 4, B-1 sand, and running dual 3-1/2" tubing strings that will both flow the same interval. We intend to start work in mid February. If you require further information, please contact me. Sincerely, . /}Æif~~ MiC"~( Mull¡,( v Advanced Production Engineer Telephone: 907-398-9954 Email: MAMullin@MarathonOil.com Attachments: Form 403 Summary of Proposal Current wellbore diagram Proposed wellbore diagram OR,\G\~\tA.L _ STATE OF ALASKA b¡ S <'-'2.Út ALA. Oil AND GAS CONSERVATION COMM.ON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 W(;¡A- "L11..7{z..oO~ RECEIVED 2 ?""¡ FEB 7 ,-UUG 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U A'askltJt5lGas Cí:m~. GGG1If'jÊl6~~ Alter casing 0 Repair well 0 / Plug Perforations [;] Stimulate 0 Time Extension Mchorag6 Change approved program 0 Pull Tubing [;] Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development [;] Exploratory 0 82-97 / 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai, AK, 99611 50-133-20357 / 7. KB Elevation (ft): 9. Well Name and Number: 26.7' KU 11-8 / 8. Property Designation: 10. Field/Pools(s): / Kenai Unit A-028142 Kenai Gas Field / Sterling Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): I~ffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): IJUnk (measured): 5364' 4879' 5217' 4750' 4380' Casing Length Size MD / TVD Burst Collapse Structural 132' 20", 94#, H-40 132' 132' Conductor Surface 2000' 13-3/8",61#, K-55 BTC 2000' 1903' Intermediate Production 5362' 9-5/8", 47#, N-80 5362' 4877' Liner Perforation Depth MD (ft): l~erfOration Depth TVD (ft): I~Ubing Size: rUbing Grade: I~Ubing MD (ft): 4225' - 5093' / 3840' - 4575' 3-1/2" / 3-1/2" / 9.2# N-80 4185 - 4382 Packers and SSSV Type: A-5 dual packer at 4171' and a Model F-1 Packers and SSSV MD (ft): A-5 dual packer at 4171' and a Model F-1 packer at 4362'. packer at 4362'. ~ 12. Attachments: Description Summary of Proposal lj 13. Well Class after proposed work: Detailed Operations Program [;] BOP Sketch 0 Exploratory 0 Development [;] Service 0 14. Estimated Date for 15. Well Status after proposed work: " 0 [;] 0 0 Commencing Operations: Mar 12th, 2006 Oil Gas Plugged Abandoned 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael A. Mullin Printed Name Mic2ael A. Mullin Title Advanced Production Engineer Signature ¿< /}4/~ /"/¡'Ce~ Phone (907) 398-9954 Date 23-Feb-06 { / / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30"- -07 Ý Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 T.e,~t }So P f to 2.000 yH.A':. OLb ~ J.¡; 0-- W\. i!-1At · OtheM J.¿ 0....."" l (J 1 ~ ~ ~ ; "1 .. eo ....¿,,,d . to w-all P y"o V S"b""",,. ~. tQ 4- ' R8DMS Sf , î 8 2006 APPROVED BY 1- - zg ,.. Db Approved by:-tà ~ ~U COMMISSIONER THE COMMISSION Date: ....., '~ - Form 10-403 Revised 07/2005 OR\G\\~AL Submit in Duplicate e e Marathon Oil Company Alaska Region KU 11-8 Kenai Gas Field, Pad 41-7 W orkover Procedure WBS # WO.06.13356.EXP History: KU 11-8 is a low pressure Sterling dual with open pool 6 and squeezed pool 5.1 on the long string and open pool 4 B-1 and B-2 sands on the short string. It is suspected that pool 5.1 squeeze is leaking and has killed pool 6. It is also suspected that the Pool 4 B-2 sand is wet and has killed the short string. Objective: Cement pool 6, pull the dual completion, abandon the pool 4 B-2 sand and complete the well in the Pool 4 B-1 sand with Dual 3-112" tubing strings flowing the same interval to allow the well to unload. The completion will allow flowrates ranging from 500MCF/day to 2.5MM with the well unloading properly. Procedure: 1. Contact Kenai Gas Field Office daily for work permit, discuss safety and environmental concerns. 2. Remove flow lines to storage and PLC control panel to the electrical shop. 3. Fill and pressure test the long string plug to verify tubing integrity. 4. RU slickline and pull the long string plug from 4380'. / 5. Dump bail cement from TD to 5038 ELMD in 9-5/8". / 6. Tag fill in short string to decide where to shoot off long string. 7. Set X plug in short string XA sleeve at 4130'. 8. RD Slickline. 9. RU Eline unit. 10. Tag TOC to confirm ELMD of top of cement plug. / 11. Pressure test long string to see if pool 5.1 squeeze is leaking. 12. Shoot offlong string at 4353' (10' above sump packer) or at top offill tagged in step 6. / 13. Bleed both strings to 0 psi. e e 14. RD eline unit. IS. RV slickline unit 16. Set plug in Long string XA sleeve at 4298'. 17. Fill both tubing strings with 6% KCI and test X plugs. 18. Contact ABB Vetco wellhead representative, Set 2 way checks in the tubing hangers. 19. Nipple down tree and release to Vetco for inspection and repair. 20. Nipple up 11" SK spool with ported blind. 21. MIRV Glacier Drilling rig #1. a. Nipple down 11" SK spool. Inspect and verify hanger threads are (3-112" EVE 8rd, 2 ea 3-1/2" EVE 8rd landing joints approx 22' long will be needed). NV 11" SM BOPJ}éP~U ped with 3-1/2" dual SM rams in upper ram cavity, and test BOPE to 2Sqí200 . An additional single gate ram will not be used in this workover to a ow more rig clearance and due to the low BHP of233psi. / b. Pull 2 way checks. c. Make up landing joints to both long and short strings. 22. RV slickline. Pull x plugs from sliding sleeves in both strings and open sliding sleeves. 23. Pump high viscosity Flo-vis. Pump adequate pill to isolate all sands in first attempt. Circulate well to remove all trapped gas. 24. Rig up Weatherford Tubing services with 3-1/2" tubing tongs and equipment. Pull 3- 1/2" dual string. 2S. RIB and pull dual packer. 26. RV eline unit and set EZSV at 4330'. 27. RllI drillpipe. Sting into EZSV and squeeze mioimU@lS cement. 28. Reverse out excess cement. 29. POR drillpipe. 30. Run dual tubing strings as per wellbore diagram. One string will be BTC and the other flush joint. 31. Set X plugs in both strings 32. Set BPV in both strings. e e v-I Gf\ f\1 D\)) 0 V t 33. Nipple up original dual tree. 34. Pull BPV's 35. Set 2 way check valves. 36. Test tree. 37. Pull 2 way check valves. 38. Set BPV's 39. RDMO Glacier Rig # 1 40. RU ABB Vetco, pull both BPV's. 41. RU flow back tank, 2" chiksan and choke skid for CT operations. 42. RU BJ services to tree. a. RU CT with 41/16" 10M BOPE stack and 1.75" CT. /' b. PT BOPE to 75/2000 psi. c. MU BHA with dbl check valves and jet nozzle to N2 lift out 6% KCL. d. RIH to PBTD while jetting with N2. e. POOH, pressure up on wellbore leaving 250 psi of nitrogen on tubing. f. RD BOP. Rig down BJ Coiltech. 43. MIRU slickline unit. a. RU BOP and lubricator. b. PU 3.5" X 40' bailer. c. Trip bailer to bottom until all fluid is removed from the well. d. RDMO slickline unit. 44. MIRU electric line unit. a. RU BOPE with sufficient lubricator. For 3-3/8" X 30' perf guns. b. Pressure test lubricator and BOPE to 75/2000 psi. c. Reperforate Pool 4, B-1 sand (55') with 23/8" hollow steel carries at 4 spf. d. Flow test well to production facility recording rates and FTP. / e. RD eline unit. Turn well over to production. Contacts: Drilling Operations Geologist Reservoir Eng Will Tank Mickey Mullin Jennifer Enos Kent Kuch Work Phone Cel (713) 296-3273 (907) 283-1337 398-9954 (713) 296-3319 (713) 296-3387 Drive Pipe: 20" 94# H-40 @ 132' 13 3/8" 61 # K-55 BTC Casing @ 2000' Cmt wi 1275 sks of Class G Perforation Record Short Strinq Pool 4: B51 4224'-4279' (8spf, 8/82) ~2,Þ"4336'-4358' (8spf, 8/82) / Squeezed Lonq Strinf:J Pool 5.1 : B-3 4394'-4424' (8spf, 8/82) B-4 4467'-4522' (8spf, 8/82) *(B-3 & B-4, 85' net, Sqz'd 10/23/97 wi 186 bbl Maraseal) Open Lonq Strinq Pool 6 C-1 5063'-5093' TDT (6spf, 11/97) Current 2,B KU 11-8 Pad -7 Kenai AK RT-GL=29' Tubing Detail C Short Strinq: 31/2" 9.2# N-80 Tubinq A. Otis XA sliding sleeve @ 4130' (ID=2.75") *Closed 6/20/03 B. Baker Model A-5 Dual Packer @4174' C. Otis XN Nipple @ 4185' (No-go=2.635") 3 Lonq Strinq: 3 1/2" 9.2#, N-80 Tubinq 1. Otis XA Sliding Sleeve @ 4137' (ID=2.75") *Verified closed (6/20/03) 2. Baker Model A-5 Dual Packer @ 4174' 3. Blast Joints from 4200'-4298' & 4302'-4361' 4. Otis XA Sliding Sleeve @ 4298' (10=2.75") *Shifted open (6/20/03). Fill in to 4337' KB. 5. Baker Model F-1 Prodn Packer @ 4363' 6. Otis XN Nipple @ 4380' (No-go=2.635") *PXN plug (set 11/25/00) 7. Wireline Re-entry Guide @ 4382' 5 * PX plug (refer to tubing detail) Fill @ 5217' ELM (11/4/97) 9 518" 47# N-80 Csg @ 5362' Cmt wi 1500 sks of Class G TD=5364' Proposed Drive Pipe: 20/1 94# H-40 @ 132' 13 3/8/1 61 # K-55 BTC Casing @ 2000' Cmt wI 1275 sks of Class G Perforation Record Short Strinq Pool 4: B-1 4224'-4279' (8spf, 8/82) 5 Squeezed Lonq Strinq Pool 5.1 : B 31391' 1121' (8spf, 8/82) B 11167' 1522' (8spf, 8/82) *(B-3 & B-4, 85' net, Sqz'd 10/23/97 wI 186 bbl Maraseal) 95/8/1 47# N-80 @ 5362' Cmt wI 1500 sks of Class G TD=5364' KU 11-8 Pad 41 Kenai AK RT-GL=29' Tubing Detail Short Strinq: 3 1/2/1 9.2# N-BO Tubing Otis XN Nipple @ 4068' (No-go=2.635/1) WEG @ 4070 Lonq Strinq: 3 1/2/1 9.2#, N-80 Tubinq Otis XN Nipple @ 4098' (No-go=2.635/1) WEG @ 4100 Coiled Tubing tailpipe 1 .75/1 Nipple at 4278', WEG @ 4280' EZSV Cement retainer 4330' 5 Bbl Cement plug squeezed through retainer with rig. 5. Baker Model F-1 Prodn Packer @ 4363' 6. Otis XN Nipple @ 4380' (No-go=2.635/1) 7. Wireline Re-entry Guide @ 4382' Fill @ 5217' ELM (11/4/97) KeoaiKU . 11;;;8"Sufldry #306:;028 .. . e . .. Subject: Kenai KU .11~8Sundry #306-028 From: "Mullin,. Mi~keY"<mmullin(@marathonOil.com> Date: Wed, 22 fßb.200ßP7:08:12-PßOO To: winton_aubert@admin.state.ak.us Winton, e We officially request cancellation of Sundry 306-028, KU 11-8 workover, due to significant changes in the well design. Thank You, I will resubmit the sundry for the workover with the changes. Mickey Mullin Advanced Production £ngineer Marathon Oil Company (907) 283-1337 (907) 398-9954 1 of 1 ---'". 6 I:;' 2/22/20067:12 AM , , e e I/06LC v ¿¡..IF Alaska Region f'J1 I1'M Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1305 Fax 907/283-1350 Jan 17,2006 Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 \~d-./ oq1 Reference: Application for Sundry Approval Field: Kenai Gas Field Well: KU 11-8 Fr' Dear Mr. Aubert, Enclosed please find a Application for Sundry Approval, along with the associated attachments for the KU 11-8 well in the Kenai Gas Field.. We will be cementing the pool 6 perforations on the long string, pulling the dual completion, Squeezing through an EZSV below Pool 4, B-1 sand, and running a concentric water lift completion with gas flow up the 9-5/8" casing. We intend to start work in mid February. If you require further information, please contact me. I will be out of the office on vacation until Jan 30th, If any urgent questions arise, please contact Ken Walsh at (907) 283-1311. Sincerely, t::.-¿,~.///~.. .' .";¿:._./ .' //z / // / 7 ,." ..... Mic eT/~~ ¿{/ (~( Advanced Production Engineer Telephone: 907-398-9954 Email: MAMullin@MarathonOil.com .. Attachments: Form 403 Summary of Proposal Current wellbore diagram Proposed wellbore diagram Proposed wellhead / tree configuration a STATE OF ALASKA a ALA_ OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Operational shutdown Plug Perforations [] Perforate New Pool 0 4. Current Well Class: / [] Exploratory 0 o Service 0 '¡' ~ 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Company 3. Address: PO Box 1949, Kenai, AK, 99611 7. KB Elevation (ft): 26.7' 8. Property Designation: Kenai Unit A-028142 11. Total Depth MD (ft): 5364' Total Depth TVD (ft): 4879' Casing Structural Conductor Surface Intermediate Production Liner Length 132' 2000' 5362' Perforation Depth MD (ft): 4225' - 5093' ./ Packers and SSSV Type: Suspend Repair well 0 Pull Tubing [] on Development Stratigraphic 9. Well Name and Number: KU 11-8 ./ 10. Field/Pools(s): PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): 5217' Plugs (measured): 4380' Junk (measured): Size 20", 94#, H-40 TVD 132' Burst Collapse 1903' 9-5/8",47#, N-80 4877' Perforation Depth TVD (ft): 3840' - 4575' A-5 dual packer at 417. packer at 4362'. Tubing MD (ft): 4185 - 4382 A-5 dual packer at 4171' and a Model F-1 packer at 4362'. / 12. Attachments: Detailed Operations Program [] 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is tr Printed Name Michael A. Mullin Signatur~,¡( / Conditions of approval: Tubing Grade: 9.2# N-80 13. Well Class after proposed work: Exploratory 0 Development [] Service 0 15. Well Status after proposed work: Oil 0 Gas [] / Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ D WDSPL 0 orrect to the best of my knowledge. Contact Michael A. Mullin Title Advanced Production Engineer Phone (907) 398-9954 Date COMMISSION USE ONLY 2.. ; ~I; ~ 7 17-Dec-06 êfJÚJ ... Ò~~ ission so that a representative may witness Sundry Number: Plug Integrity 0 Other: Approve(! by: Form 10-403 Revised 07/2005 Mechanical Integrity Test 0 Location Clearance 0 RBDMS BFt fEB 2 2 2006 COMMISSIONER APPROVED BY THE COMMISSION Date: o IGINAL Submit in Duplicate e e Marathon Oil Company Alaska Region KU 11-8 Kenai Gas Field, Pad 41-7 W orkover Procedure WBS # WO.06.13356.EXP History: KU 11-8 is a low pressure Sterling dual with open pool 6 and squeezed pool 5.1 on the long string and open pool 4 B-1 and B-2 sands on the short string, It is suspected that pool 5.1 squeeze is leaking and has killed pool 6. It is also suspected that the Pool 4 B-2 sand is wet and has killed the short string. Objective: Cement pool 6, pull the dual completion, abandon the pool 4 B-2 sand and complete the well in the Pool 4 B-1 sand with a 2-3/8" X 1-3/4" coiled tubing concentric water lift after the rig moves. The concentric water lift will operate with a check valve in the 2-3/8" CT string and cyclic gas lift connected to flow gas down the 2-3/8" string to unload water up the 1-3/4" string. Gas production will flow up the 9-5/8" casing. Procedure: 1. Contact Kenai Gas Field Office daily for work permit, discuss safety and environmental concerns. 2. Remove flow lines to storage and PLC control panel to the electrical shop. 3. Fill and pressure test the long string plug to verify tubing integrity. 4. RU slickline and pull the long string plug from 4380'. 5. Dump bail cement from TD to &ELMD in 9-5/8". 6, Tag fill in short string to decide where to shoot offlong string. 7. RU Eline unit. 8. Tag TOC to confirm ELMD of top of cement plug, 9. Pressure test long string to see if pool 5.1 squeeze is leaking. 10. Shoot offlong string at 4353' (10' above sump packer) or at top offill tagged in step 6. 11. RU slickline and open long string and short string sliding sleeves 12. Bleed both strings to 0 psi, e e 13. Contact ABB Vetco wellhead representative, Set BPV s in the tubing hangers. 14. MIRU Glacier Drilling rig #1. a. Remove BPVs and pump high viscosity Flo-vis. Pump adequate pill to isolate all sands in first attempt. Circulate well to remove all trapped gas. Install two way checks. b. ND tree. Inspect and verify hanger threads are (3-1/2" EUE 8rd, 2 ea 3-1/2" EUE 8rd landing joints approx 22' long will be needed). NU 13 5/8" 5M Weatherford BOPE equipped with 3-1/2" -5.5" VBR 5M rams in upper ram cavity, and test BOPE to 250/2000 Pull two way checks. An additional single gate ram will not be used in this workover to allow more rig clearance and due to the low BHP of 233psi . 15. Rig up Weatherford Tubing services with 3-1/2" tubing tongs and equipment. Pull 3- 1/2" dual string. 16. RIH and pull dual packer. / 17, RU eline unit and set SVat 4330', c- 18. Rill drillpipe. Sting in(.;~SV and squeeze ~sãck1J cemeut. ./ L/ 19. Reverse out excess cement. 20. POH drillpipe. 21. Set recompletion hanger in wellhead, and set 2 way check (see wellhead / tree diagram). 22. RDMO Glacier Rig # 1 23. RU 4" tree as per attached diagram. 24. RU ABB Vetco, pull 2 way check. 25. RU flow back tank, 2" chiksan and choke skid for CT operations. 26. RU BJ services to tree. a. RU CT with 4 1/16" 10M BOPE stack and 1.75" CT. b, PT BOPE to 7512000 psi. c. MU BHA with dbl check valves and jet nozzle to N2lift out 6% KCL. d. RIH to PBTD while jetting with N2, e, POOH, pressure up on wellbore leaving 250 psi of nitrogen on casing. f. RD BOP, Rig down BJ Coiltech, 27. MIRU slickline unit. a. RU BOP and lubricator. e e # b. PU 3,5" X 40' bailer. c. Trip bailer to bottom until all fluid is removed from the well. d. RDMO slickline unit. 28. MIRU electric line unit. a. RU BOPE with sufficient lubricator. For 3-3/8" X 30' perf guns. b. Pressure test lubricator and BOPE to 7512000 psi. c, Reperforate Pool 4, B-1 sand (55') with 3 3/8" hollow steel carries at 6 spf. d. Flow test well to production facility recording rates and FTP. e. Run BHP gauges to record static BHP. Rig down electric line. 29. RU CT. a. Run and hang off 2-3/8" CT string with Nipple, WEG, and dual pump out plugs as per the proposed wellbore schematic.. b. Run and hang off 1-75" CT string with only WEG as per the proposed wellbore schematic. c. Pump off dual plugs with N2. d. Rig back CT, 30. RU slickline a. Run and set 1,25" standing valve in nipple in 2-3/8" string. 31. Connect timed gas lift and determine the best frequency to unload the water from the concentric string, Contacts: Drilling Operations Geologist Reservoir Eng Will Tank Mickey Mullin Jennifer Enos Kent Kuch Work Phone Cel (713) 296-3273 (907) 283-1337 398-9954 (713) 296-3319 (713) 296-3387 Drive Pipe: 20" 94# H-40 @ 132' 13 3/8" 61 # K-55 BTC Casing @ 2000' Cmt wI 1275 sks of Class G Perfora.tion Record Short Strinq Pool 4: B-1 4224'-4279' (8spf, 8/82) B-24336'-4358' (8spf, 8/82) Squeezed Lonq Strinq Pool 5.1 : B-3 4394'-4424' (8spf, 8/82) B-4 4467'-4522' (8spf, 8/82) *(B-3 & B-4, 85' net, Sqz'd 10/23/97 wI 186 bbl Maraseal) Open Lonq Strinq Pool 6 C-1 5063'-5093' TDT (6spf, 11/97) 2,B KU 11-8 Pad 41-7 Kenai AK RT -GL=29' Tubing Deta.il c Short Strinq: 31/2" 9.2# N-80 Tubinq A. Otis XA sliding sleeve @ 4130' (ID=2.75") *Closed 6/20/03 B. Baker Model A-5 Dual Packer @ 4174' C. Otis XN Nipple @ 4185' (No-go=2.635") 5 Lonq Strinq: 3 1/2" 9.2#, N-80 Tubinq 1. Otis XA Sliding Sleeve @ 4137' (ID=2.75") *Verified closed (6/20/03) 2. Baker Model A-5 Dual Packer @ 4174' 3. Blast Joints from 4200'-4298' & 4302'-4361' 4. Otis XA Sliding Sleeve @ 4298' (lD=2.75") *Shifted open (6/20/03). Fill in tubing to 4337' KB. 5. Baker Model F-1 Prodn Packer @ 436.3' 6. Otis XN Nipple @ 4380' (No-go=2.635") *PXN plug (set 11/25/00) 7. Wireline Re-entry Guide @ 4382' * PX plug (refer to tubing detail) Fill @ 5217' ELM (11/4/97) 9 5/8" 47# N-80 Csg @ 5362' Cmt wI 1500 sks of Class G TD=5364' <II Drive Pipe: 20" 94# H-40 @ 132' 133/8" 61# K-55 BTC Casing @ 2000' Cmt wI 1275 sks of Class G 9-5/8" Casing Plug at 4330' Record Short Strinq Pool 4: B-1 4224'-4279' (8spf, 8/82) B-24336'-4358' (8spf, 8/82) Squeezed Lonq Strinq Pool 5.1 : B-3 4394'-4424' (8spf, 8/82) B-4 4467'-4522' (8spf, 8/82) *(B-3 & B-4, 85' net, Sqz'd 10/23/97 wI 186 bbl Maraseal) PROPOSED Pluç¡ç¡ed Lonç¡ Strinç¡ Pool 6 C-1 5063'-5093' TOT (6spf, 11/97) Proposed KU 11-8 Pad 41 Kenai AK RT-GL=29' PROPOSED Tubing Detai! Internal Strinq: 1.75" CT WEG at 4220' External Strinq: 2-3/8" CT 1. Standing valve Nipple @ 4223' 2. 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" \ C)iX" tt ~/8 WI\ \v\:i\\.::¡ V'll\.¡ Ij . \.L\O~ -, \ \ (t,lÖ(v'\Ç\£.\ ~ / ¡1,}tJ-k -------- ac \J K-COK~~-t\ÒrJ \.)\):;'0.\(\' w/ b S/¡b' H \IN" Q\CJ~k ~ ...) ~ \\ / "" \/~ S(Yì ¡ -............., 1...1 \--'-,/ -\ LXI .,'-'-...........-/ \ ' \' 7Yt'b 5\"\ \\~t 'J( ,L-\ /6 60ì " \,.,~\ , ".' .....,!1{W \ '" S1:\Y~jt()..'.>U ., \ - e \- 8 T VJ:~ \\ ~'l. 'tù'o~i\j9 ~ecJ. :> i 7-(. I{ í"~~ be \ \ I 0('t,w:tO\¿'{,) \1()~Òì()l>-.) l S Or...> \>-~. I * DC\') ~\:)\~ t'\~ \~.\ ():Q::Mf.9,,\Qi.,X1d. le;;i;,\ ¡ ÌJ \-\- w\ ~'n C\j\ 4\\ s\d.e. ()üt\cl \\eoJ1, 'ot~1.j '.1\{)I.)\)ð.. k\¡'(..\ I \).,..~ v..H\ \fJ.CV~IS u,,)Ó..''-J' lqov-13-00 04:00pm From-MARATHON OIL +gls$$4548g T-Tg? P.O1/D$ F-25t Alaska Domestic Ju~ion _M. arathon Od Company P.O, Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: II-Name: .~'~' -~Lx~c~d~'~..' ' .... ., I Company: .J~ ~"t c.~,, .. Fax No.: Number o! ,.Pages (i. cl.~l,g ~pa__~)! FROM: , Name: , Locatl.on/Extens. ion: .... Fax No.: 907/564-6489 Anc~orag~ NOTE: transmission is not complete, please call 90/'/561-5311. A subsidiary of USX Corporation Environmentally aware tot the long run. ' Marathon OilCompany T-?g? P. OZ/O; · ~ alaska Region Domestic Production F-251 P.O. Box 196168 Anchorage, AK 99519-6168 Yelephone 907/561-;311 Fax 907/564-6489 November 13, 2000 Mr, Tom Maunder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KU 11-8s Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS for well KU 11-8s. Additionally, I have provided an intended procedure, Please advise if additional information is required. I can be reached at 564-6317 or e-mailed at dmtitus @ marathonoii,com. Sincerely, Denise Titus Production Engineer Enclosures Of /S/NAL Prum-~ARAIHUH UIL +gl$$$4548g T'?g? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Requeat Abandon Alter Casing i Change Approved Program Suspend..__ Operation Shutdown-- Re-enter Suspended Well__ Repair Well__ Plugging ~ Time Extension -- Stimulate ~ -- Pull Tubing__ Variance._.._ Perforate,__ Other.~X 6, Datum Elevaticm ~,7 feel - ?. Unit or Property-Nar~' Kenal Unit 8;~ll-lqi~mber 2. N~-m'~'of Operator MARATHON Oil COMPANY · 3:'Address P, O, Box 196168, Anchorage, AK 99~19-6168 4. Location o[ Well st Surface' .f v" 374' FNL, 4266' FWL, Sec, 7, T4N, R11W. S,M, At top of Productive Interval ! 5, T~iSe of Well: Development ~X Exploratory -- Strattgraphio__ Service At Effective Depth Wash Sand With Coiled Tubing At Total Depth 855' FNL. 1296' FWL, Sec. 8, T4N, R11W, S.M, 12. Present Well Conditi~"Summary To~al Deplh; measured t~ue vertical 5364 feet Plugs (meaaumd) 4880 feet v/ KU 11 g. Permit .Nuclear 82-97 v. ,. 10, AP1 Number 50- 133-20557 v' r l~. Kenai Gas Field, Pool 4 Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intenmediate Production Liner Perforation Depth: Tubing (size, grade, ~nd measured depth) Lenglh Size Cemented 132' 20" Driven 2000' 13-3/8" t 275 eke 6362' 9-5/8" 150o measured B-l; 4224' - 4273' MD, B-2: 4336'- 4~!52' true vertical B-1: 38B6' - 3900' 'I'VD, B-2; 39S6' - 3971' 3-1/2", 9.2.~, N-80 tubing to 4285' MD Measured Dep~ 132' 20o0' True Vedioal Depth 132' t903' 4878' ORIGINAL Packers and sSSV (type and measured depth} Baker model A.5 dual packer @ 4174' MD B~ker model F-I pecker ~ ~' MD ~. Att~men~ ' Desc~ption S~mma~ of p~ss~__ Oe~iled O~eta~one Pmgra~ ~ ~4. E~imated Date for Commencing Ope~flbn 116,"S~{us of WeFC'lassifi~fion as; 11/1~00 i ~. Ifpropo~l w~a ~'~6~lly Approved I Oil G~a X I Nsme o~ Appr~er ~te Approved ! Sowioe BOP Sketch Suspended ..... 17, I hereby c~r~l~ that the foregoing is true and cor~e~ to the best of my knowledge. Signed ~)e~'tt,~ ~*,,3,~ , IC'~'$ (,,. Title Production Engineer ~ ~ ~1~ " ' FOR CO'MMISS~N ~SE-ONEY C~ditions o'f ~ppmval: Nmi~ Com~issioh ~ mp~five may witne~ "' Plug Integ~ BOP Test~ Lo--riCh Cleamn~ Meohani~i In~l~ Test__ Sub~quen~ Fo~ Required 10-~~ .Approved b~O~erof~e Comml~ion ORiGiNAL ~.~u:~NED~.,, ...~ BYt ~o~ ~o-~ n~. o~s/e~ ~ T~ ¥ ~,:'>.i .......... tlr Date . , ,1!/13/00 .... //""~x T-Tg7 P. 04/0~ F-2~I Marathon Oil Company Alaska Region KU 11-08s Kenai Gas Field, Pad 41-7 AFE #0489200 Sand Wash Procedure Objective: Sand fill on lower perforations restricts well flow, A fluid level was detected at about 3980'. Close sliding sleeve, Run in with 1,75" CT and wash sand to 4400', Jet well in with nitrogen, Open sliding sleeve to restore annular pwduction. Procedure: 1) MIRU Pollard slicldine. Close Otis "XA" sliding sleeve (ID=2.75") at 4130'. Set Plug in long string XN nipple at 4380' (ID=2.635"). RDMO Pollard. 2) MIRU Dowell 1.75" CT. 3) Mix 3% KCI, Steam heat tanks if needed. 4) Pressure test to 2000 psi. 5) RIIt w/wash nozzle. Dry tag fill. Expect sand at 4281'. Wash sand to 4400' taking returns to open top tank through chicksan and gas buster. 6) Once returns are clean, POOH pumping nitrogen. 7) RDMO Dowell Schlumberger. 8) MIRU Pollard slickline. Open Otis "XA" sliding sleeve at 4130'. RDMO Pollard. 9) Trim well to system and produce per instruction of production engineer. N'kDRLG~KGI~WELLS\KU 11 ~08sXclpz'oc.doc 11/13/00, DMT ............. ~,,, r, u,,-wa~a I nvn v~ ~. +ft1~$$4548g T-Tg7 Kenai Gas Field .... Well KU 1 1-8, Pad 41-7 ...... Marathon Oil Co., Alaska Region P.0~/0~ F~B-THF: 26.72' RT-GL: 29.0' 374'8 & 4266' E of NW Comer Sec. 7, T4N, R11W Shortstring Tubing: 3-1/2". 9.2#, N-80. Butt. 20". 94#, H-40 Drivo pipe @132' 134/8", 61#, K-55, BTC Casin§ (~ 2000' Cmt w/1275 sks ofCla~s G Ods "XA" Sliding Sleeve ~ 4130' ID -- 2.750" Sleeve opened for annular flow 8/21198 Baker A-5 Dual Packer, Otis "XN" Nipple ~ 4185' ID "2,635" Sh~,~a'in _~ P~rfll B.,I 4224'-4273' (S spf, 8/27/g2) 15-2 4336'- 4352' (8 spf, 8/27/82) Top of Cement approx. 1700' CBL _Squee~.ed Long, tin .~ Peris 4394'-4424' (8 spf, 8/28/82) 446?-4522' (8 spf, 8!26/82) (B-3 & B-4, 85' net. sqzd wi 186 bbl of Magical on 10/23/9/) _Open Lon~stTi.n~: Pcrf$ '- -C,-! 5063'- 5093' TDT (11/4/97) (2-1/8" strip guns. 6 spf. ~,45' phase) TI) (~ 5364' Otis "XA" Sliding Sleeve (~4137' ID = 2.750" Loagstring Tubing: 3-1/2", 9.2#, N-80, Butt. Blast ~oint~ 4200' - 4298' 4302'. 4361' Otis "XA" Sliding Skeve @ 4298' ID = 2.750" Baker Model F-I Paoker (~ 4363' · Cais 'giN" Nipple @ 4380' ID = 2.635" Wireline R~entry Ouide @ 4382~ RECEIVED ~- . ,.~"/ ~ ,5 2000 -- Al~,~a Oii a Gas Co~,,s. Commission m @ s2]?, ~ (] 1/4~horage 9.518", 47~, N-80, BTC C~g ~ 5362' Cmt w/1500 ~ of Class O Last Rev: YGE, 9/1 Al~egion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 1, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Wells KU 11-8s, KU 24-5s, and KU 43-6al Dear Mr. Wondzell: Please find attached the Report of Sundry Well Operations, well schematic and daily reports for the above referenced wells. If you have any questions, please feel free to call me at 564-6315. Sincerely, ~,J n~ '~!~~ Engineer M:\WP~OPNS98~JGE 101 Enclosure RECEIVED 0CT 6 998 ~Ol/& Ga~ Commiss~ Ar~ra~ xc: CEF Well Files ORIGINAL A subsidiary of USX Corporation Environmentally aware for the long run. g:tcmntdrig~kgf~wellstkul 1.Ss~AOGCCOI A.xts STATE Of ALASKA ~. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown ... Stimulate Plugging Perforate Pull Tubing Alter Casing .,. Repair Well Other ,...X.. 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 374' FNL, 4266' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory__ Stratigraphic M Service At Effective Depth Convert to Annular Flow At Total Depth 855' FNL, 1296' FWL, Sec. 8, T4N, R11W, S.M. 6. Datum Elevation (DF or KB) 26.7 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 11-8s 9. Permit Number 82-97 10. APl Number 50- 133-20357 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5364 feet Plugs (measured) 4880 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 132' 20" Driven 2000' 13-3/8" 1275 sks 5362' 9-5/8" 1500 sks B-I' 4224' - 4273' MD, B-2: 4336. - 4352' Measumd Depth 13Z 2000' 5362' True Vertical Depth 132' 1903' 4878' true vertical B-1: 3856' - 3900' TVD, B-2: 3956' - 3971' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2~, N-80 tubing to 4285' MD Baker model A-5 dual packer {~ 4174' MD Baker model F-1 packer {~ 4363' MD ORIGINAl. RECEIVED '13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 5530 0 0 110 Subsequent to Operation unknown, not yet tested 15. Attachments 116. Status of Well Classification as: I Copies of Logs and Surveys run Daily Report of Well Operations X Oil__ Gas ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ ,~ {~3d,,. ~ Form 10-404 Rev. 061~ '~ ~ Suspended~ J. Gary Eller Title Production Engineer Service Date 10/1/98 Submit in Duplicate Kenai Gas Field Well KU 11-8, Pad 41-7 .., ............. ............ _ Marathon Oil Co., Alaska Region KB-TI-IF: 26.72' RT-GL: 29.0' 374'S & 4266' E of N-W Comer Sec. 7, T4N, R11W Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. Offs "XA" Sliding Sleeve ~ 4130' ID = 2.750" Sleeve opened for annular flow 8/21/98 Baker A-5 Dual Packer ~ 4174' Otis "XN" Nipple @ 4185' ID = 2.635" Shortstring Perfs B-1 4224'-4273' (8 spf, 8/27/82) B-2 4336'-4352' (8 spf, 8/27/82) Top of Cement approx. 1700' CBL Squeezed Longstring Perfs B-3 4394' - 4424' (8 spf, 8/28/82) B-4 4467'-4522' (8 spf, 8/26/82) (B-3 & B-4, 85' net, sqzd w/186 bbl of Maraseal on 10/23/97) Open Longstring Perfs C-1 5063'- 5093' TDT (11/4/97) (2-1/8" strip guns, 6 spf, 4-45° phase) TI) @ S364' 20", 94#, H-40 Drive pipe @132' 13-3/8", 61#, K-55, BTC Casing ~ 2000' Cmt w/1275 sks of Class G Otis "XA" Sliding Sleeve ~4137' ID = 2.750" Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Blast Joints 4200' - 4298' 4302' - 4361' Otis "XA" Sliding Sleeve @ 4298' ID = 2.750" Baker Model F-1 Packer ~ 4363' Otis "XN" Nipple @ 4380' ID = 2.635" Wireline Re-entry Guide @ 4382' Fill @ 5217' ELM (11/4/97) 9-5/8", 47#, N-80, BTC Casing ~ 5362' Cmt w/1500 sks of Class G Last Rev: JGE, 9/1/98 980826.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/26/98 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #7 - AFE 0481898 Kenai Gas Field WELL #: KU 11-8s 3-112", 9.2#, N-80 CASING: 9-518", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS MIRU Pollard slickline unit on KU 1 1-8s. Test lubricator and BOPE to SITP. RIH with JDC pulling tool end retrieve prong from PXN plug at 4185' MD. POOH. RIH with GS pulling tool, retrieve PXN plug body from 4185' MD. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen $0 $8,900 'Misc. $500 $4,000 Pollard slickline $800 $4,700 R&L Construction vacuum truck $400 $400 Vetco Gray ,2" gate valves $0 $1,600 DAILY COST: $1,700 CUM: $20,000 REPORTED BY: J.G. Eller 980825.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/25/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 OTHER: Day ~3 - AFE 0481898 SUMMARY OF OPERATIONS RU Dowell nitrogen pump on 9-5/8" casing of well KU 11-8. Pressure test nitrogen lines to 2500 psig. TP = 700 psig, CP = 200 psig. Held operational and safety meeting. Bled tubing pressure to zero. Began pumping nitrogen down the casing while taking returns of packer fluid off the shortstring tubing. After pumping 125,760 SCF of nitrogen (maximum pump pressure = 1400 psig) got nitrogen returns to surface. Shut down nitrogen pump, then continued to blow nitrogen from the tubing to make sure all packer fluid was unloaded. Shut in well at casing and tubing. RD nitrogen. Final TP = CP = 480 psig. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen $4,000 $8,900 Misc. $500 $3,500 Pollard slickline $0 $3,900 Vetco Gray 2" gate valves $0 $1,600 DAILY COST: $4,500 CUM: $18,300 REPORTED BY: J.G. Eller 980821 .xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/21/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN' Sterling B-1 & B-2 OTHER: Day #5 - AFE 0481898 SUMMARY OF OPERATIONS MIRU Pollard slickline on KU 11-8s tubing. Pressure test BOPE and lubricator to SITP. SITP = 1275 psig, casing pressure = 0 psig. RIH with "B" shifting tool to XA sleeve @ 4130' MD. Jarred open XA sliding sleeve at 4130' MD; tubing pressure fell to 700 psig and casing pressure increased to 200 psig. Could not re-engage "B" shifting tool, verifying that XA sleeve is fully open. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC !roustabouts $0 $400 Dowell nitrogen $0 $4,900 Misc. $500 $3,000 Pollard slickline $2,150 $3,900 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $2,650 CUM: $13,800 REPORTED BY: J.G. Eller 980820.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/20/98 Fl LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 OTHER: Day ~ - AFE 0481898 SUMMARY OF OPERATIONS MIRU Dowell nitrogen pump on KU 11-8s tubing. Pressure test lines to 3000 psig. Pressure up on tubing to 1270 psig using 17,670 SCF of nitrogen. PXN plug is holding. RDMO nitrogen unit. Note: Plan to use slickline to shift open the XA sliding sleeve over the weekend. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen unknown unknown Misc. $500 $2,000 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $500 CUM: $4,000 REPORTED BY: J.G. Eller 980819.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/19/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow OTHER: Day #3 - AFE 0481898 Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS Bled 9-5/8" casing on KU 11-8 to zero. Held operational and safety meeting. Removed blind flange from secondary casing outlet on tubing head. Installed a newly tested 2-1/16", 5M gate valve. Removed old casing valve, and installed another newly tested 2-1/16", 5M gate valve. Closed casing valves, release roustabout crew. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $400 $400 Dowell nitrogen $0 unknown Misc. $500 $1,500 Vetco Gray 2" gate valves $1,600 $1,600 DALLY COST: $2,500 CUM: $3,500 REPORTED BY: J.G. Eller 980817.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/17/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow OTHER: Day #2 - AFE 0481898 Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS Hooked up a chart recorder on the 9-5/8" casing of KU 11-8 over the weekend. Casing pressure !steady at 1360 psig. Dug out around 13-3/8" surface casing valve. Opened valve and confirmed that there is no communication between the 13-3/8" and 9-5/8" casings. Bled 9-5/8" casing to zero. Vendor Equipment Daily Cost Cumulative Cost Dowell nitrogen $0 unknown Misc. $500 $1,000 DALLY COST: $500 CUM: $1,000 REPORTED BY: J.G. Eller 980814.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/14/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Convert to annular flow Kenai Gas Field WELL #: KU 11-8s 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 OTHER: Day #1 - AFE 0481898 SUMMARY OF OPERATIONS RU Dowell nitrogen pump on 9-5/8" casing of well KU 11-8. Pressure test lines to 3000 psig. Pressure test 9-5/8" casing to 1365 psig using 40,000 SCF of nitrogen. Volume of nitrogen used indicates fluid level is at 1200' or deeper, which is why the final test pressure is lower than the 1900 psig that is written in the procedure. The 13-3/8" surface casing could not be monitored due to gravel fill in the cellar (see note below). RD nitrogen unit. Note: Plan to leave pressure on the 9-5/8" casing over the weekend, and will put a chart on the casing to record the pressure test. On Monday, will dig out to the 13-3/8" surface casing to verify that it is not communicated to the 9-5/8" production casing. Vendor Equipment Daily Cost Cumulative Cost Dowell nitrogen unknown unknown Misc. $500 $500 DALLY COST: $500 CUM: $500 REPORTED BY: J.G. Eller 980813.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/13/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KU 11-8s TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: BENCHES OPEN: Sterling B-1 Add casing outlet for annular flow completion OTHER: Day #1 - AFE 0481898 SUMMARY OF .OPERATIONS RU Pollard slickline on KU 11-8s. Test BOPE and lubricator to SITP. RIH with 2.720" gauge ring, tag up at 4228' WLM. POOH. RIH with PXN plug, set in XN-nipple at4185' MD. POOH. Verify proper setting of plug with check-set tool. POOH. RIH and set prong in P×N plug. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline slickline $1,750 $1,750 Misc. $500 $500 ,,, ~ , DALLY COST: $2,250 CUM: $2,250 REPORTED BY: J.G. Eller Anchor age-, Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK99519-6168 Telephone 907/561-5311 August 5, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Kenai Gas Field. Annular Flow Conversion Dear Mr. Wondzeli: As per your request, attached is a review of potential problems associated with converting Wells KU 11..8s, KU 24-5s, and KU 43-6AI at the Kenai Gas Field to annular flow. As the analyses show, Marathon does not anticipate that these conversions will cause undue stress, corrosion, or erosion on the production casing strings. Sincerely, ~ion Engineer A subsidiary of USX Corporation Environmentally aware for the long run. .$ENT BY'~arazhon 011 Company~,,8- .5-98 ' 8'46A)1 ' Anch~----~e-~ 907 276 7-~42'~ 2/ 4 WELL KU 1 l-SS, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling B- 1 and B-2 Sands (Pool 4) in well KU 1 l-Ss to be produced up the 3 ½" tubing and 9¥a" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Erosional Velocity Corrosion Surface Safety Comrols Burst/Collapse of Casing Solution The highest potential for erosive flow exists at the 2-I/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 12 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines tbr signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. Ifthe partial pressures of COz is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no I-I~S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a scparate flowline from thc existing tubing completion. Surface safety controls will be sitnilar to that of other Kenai Gas Field completions. Pressures imposed on the 9%" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 53% of the rated casin~ burst or collapse. Alaska Re.,~,.,~n Domestic Production Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 28, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ~j' Anchorage, AK 99513-7599 ~ ~q.... C) cl ~ (.0~:~' ©~' Reference: Kenai Gas Field, Wells KU 11-8s, KU 24-5s, and KU 43-6al Dear Mr. Wondzell: Please find attached procedures for permitting annular flow in wells KU 11-8s, KU 24-5s, and KU 43-6al in Kenai Gas Field. The increased flow area by producing up the production casing and tubing simultaneously is expected to double the well's gas deliverability. Flow up the production casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. This work is expected to commence early August 1998. Please contact me if further information is needed. j~~G, ileS[ncerel rYprbdu.~tio'.~-~n Engineer M:\WP\OPNS98~JGE728. Enclosure RECEIVED 4 1998 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0:IEXCEL Wogc, cO'I.xI$ ~ 1. Typo of Request: Abandon Suspend__ Operation Shutdown Alter Casing Repair Well Plugging , ., Change Approved Program ,. Pull Tubing Variance Re-enter Suspended Well__ · Time Extension Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 995~19-6168 4. Location of Well at Surface 374' FNL, 4266' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive InterVal 5. Type of Well: Development X Exploratory , Stratigraphic ..... SerVice At Effective Depth Convert to Annular Flow At Total Depth 855' FNL, 1296' FWL, Sec. 8, T4N, R11W, S.M. 6. Datum Elevation (DF or KB) 7. Unit or Property Name Kenai Unit 26.7 feet 8. Well Number KU 11-8s 9. Permit Number 82-97 lO. APl Number 50- 133-20357 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5364 feet Plugs (measured) 4880 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length Size Cemented 132' 20" Driven 2000' 13-3/8" 1275 sks 5362' 9-5/8" 1500 sks B-I' 4224' - 4273' MD, B-2: 4336' - 4352' B-I' 3856' - 3900' TVD, B-2: 3956' - 3971' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2~, N-80 tubing to 4285' MD Baker model A-5 dual packer @ 4174' MD Baker model F-1 packer @ 4363' MD ORIGINAL Measured Depth 132' 2000' 5362' True Vertical Depth 132' 1903' 4878' RECEIVED AlasJ~ 0il & Gas Cons. Commissiol Anchorage 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 8/5/98 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.., '~. (,~_ _~_~,,,k"~'~ Title Production Engineer [ 'X~ "~ FOR COMMISSION USE ONLY Conditions of Ap~k~va~ Notify~Com~nission so representative may witness ~ ~, Pl~-i~tegrity ~ BOP Test Location Clearance Mechanical In'~e'g'rity Test..._.. Subsequent Form Required 10- Date 7/30/98 JApproval No~.~ Approved by Order of the Commission Form 10o403 Rev. 06115188 Original Signed By David W. Johnston Commissioner Date ! Sl~om~n TrTplicate Copy Ro. turnod WELL KU 11-8S- AFE 0481898 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Ob|ective: Allow flow up the tubing-casing annulus in well KU 11-Ss to increase gas deliverability. Procedure: 1. Shut in both sides of well KU 11-8. MIRU slickline on KU 11-8s. Test BOPs and lubricator to SITP. Set PXN plug in XN nipple (ID = 2.635") at 4,285' MD. Verify proper setting of mandrel in nipple using check-set tool. RDMO slickline. 2. MIRU nitrogen unit on KU 11-8. Using nitrogen, pressure test 9%" casing to 1,900 psig. Monitor 13%" casing for potential communication. When test is complete, bleed all pressure off 9%" casing. Note: If volume of nitrogen pumped indicates annular fluid level is low, we may be able to reduce the pressure test requirement on the casing. 3. When casing is completely bled down, remove blind flange on tubing spool across from the existing 9%" casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull off the old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 4. RU nitrogen unit on KU 11-8s. Using nitrogen, pressure test PXN plug to 1,900 psig. Do not bleed off tubing when finished. RD nitrogen. 5. MIRU slickline. Test lubricator and BOPs to SITP. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve at 4130' MD. Shift open sliding sleeve at 4130' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. 6. Bleed nitrogen pressure off of tubing. 7. RU nitrogen unit on 9%" casing ofKU 11-8. Pump nitrogen down casing, taking fluid returns on tubing to catch tank. Do not exceed casing test pressure. Continue until nitrogen is blowing around the tubing, then shut in the tubing. RD nitrogen. Note: Leave at least 500 psig on the tubing and casing after shutting in. If necessary, apply necessary pressure with nitrogen. 8. MIRU slickline on KU 11-8s. Test BOPs and lubricator to SITP. Pull PXN plug at 4,285' MD. RDMO slickline. Well KU l l-8s Convert to Annular Flow Page 2 9. As soon as possible, produce well at maximum flow rate up tubing to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. 10. Shut in KU 11-8s. Install flowline to produce out both sides of the tubing head on KU 11-8s. When complete, flow casing side and tubing side simultaneously to test separator and compare with previous test. When testing is complete, produce as per instructions of Production Foreman. JGE July 27, 1998 N:~DRLG~KGF~WELLS~Ku I I-8s~ad~INFLOW. WPD Kenai Gas Field Well KU 11-8, Pad 41-7 Marathon Oil Co., Alaska Region KB-2I-W: 26.72' RT-GL: 29.0' 374'S & 4266' E of NW Comer Sec. 7, T4N, RI 1W Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve ~ 4130' ID = 2.750" Baker A-5 Dual Packer @ 4174' Otis "XN" Nipple @ 4285" ID = 2.635" Shortstring Peffs B-I 4224'-4273' (8 spf, 8/27/82) B-2 4336'-4352' (8 spf, 8/27/82) Top of Cement approx. 1700' CBL Squeezed Longstring Perfs B-3 4394'- 4424' (8 spf, 8/28/82) B4 4467'- 4522' (8 spf, 8/26/82) (B-3 & B4, 85' net, sqzd w/186 bbl of Maraseal on 10/23/97) Open Longstring Perfs C-I 5063'- 5093' TDT (1 I/4/97) (2-1/8" strip guns, 6 spf, ±45° phase) m @ 5364' 20", 94#, H-40 Drive pipe @132' 13-3/8", 61/t, K-55, BTC Casing @ 2000' Cmt w/1275 sks of Class 13 Otis "XA" Sliding Sleeve (~4137' ID = 2.750" Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Blast Joints 4200' - 4298' 4302' - 4361' Otis "XA" Sliding Sleeve ~ 4298' ID = 2.750" Baker Model F-1 Packer (~ 4363' Otis "XN" Nipple (_.& 4380' ID = 2.635" Wireline Re-entry Guide @ 4382' Fill (q3, 5217' ELM (11/4/97) 9-5/8", 47#, N-80, BTC Casing @ 5362' Cmt w/1500 sks of Class O Last Rev: JGE, 7/27/98 G:~CMN~DRLG~WELLb'~llSI404.XLS ' '~ STATE Of ALASKA ALASKA Oil_ AND GAS CONSERVATION COMMI881ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging X Perforate X Pull Tubing . Alter Casing Repair Well Other 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 374'FNL, 4266'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 748'FNL, 792'FWL, Sec. 8, T4N, R11W, S.M. At Effective Depth At Total Depth 855'FNL, 1296'FWL, Sec. 8, T4N, R1 lW, S.M. 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 26.7 feet 7. Unit or Property Name Kenai Unit s. Well Number KU 11-8L 9. Permit Number/Approval Number 82-97 / 397-164 lO. APl Number 50-- 133-20357 11. Field/Pool Kenai Gas Field/Sterling Pool 12. Present Well Condition Summary Total Depth: measured true vertical 5364 feet Plugs (measured) 5273' PBTD 4879 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 132' 2000' 5362' measured true vertical Short string Long stdng Short stdng Long stdng Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured Depth True Vertical Depth 20" driven 132' 132' 13-3/8" 1275 sks 2000' 1903' 9-5/8" 1500 sks 5362' 4877' B-l: 4225-4274, B-2:4337-4353 C-1: 5063-5093 B-l: 3840-3884 B-2:3941-3955 c_,.,,,,o.,,,,, ORIGINAL Short string: 3-1/2", 9.2~, N-80 to 4185' · Long string: 3-1/2", 9.28, N-80 to 4381' A-5 dual packer ~ 4171 ', F-1 packer ~ 4362' RECEIVED 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Added perfs - C-1: 5063-5093 Plugged wi gel - B-3:4395-4425 & B-4:4467-4522 Treatment Description Including Volumes Used and Final Pressure 186 bbl of crosslinked Maraseal gel, final SITP -- 190 psig. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation Shut in. Subsequent to Operation Shut in. 15. Attachments 116. Status of Well Classification as: I Copies of Logs and Surveys run m Daily Report of Well Operations , ,X,,, Oil Gas X Suspended 17. I hereby Certify tha~he foregoing is true, and correct to the best of my knowledge. Signed ~'~ ~~"~'~ t--~ Title Production Engineer Form 10-404 Rev. 06/15/~..~ ~ Service Date 11/26/97 Submit in Duplica{~~ Sheet2 Well KU 11-8L Summary of Operations October 22, 1997 to November 4, 1997 10/22/97 10/23/97 10/27/97 10/28/97 11/4/97 11/5/97 MIRU Dowell 1.5" coil tubing unit. Hold safety mtg, test BOPs. Blend batch of Maraseal gel and RIH w/coil tubing. Pump gel while moving coil from 4300' to 4600' CTM. Pumped total of 186 bbl of gel into wellbore, gaining approximately 100 psig on SITP. Flush coil, allow gel to set. Attempt to clean out residual gel, but coil froze up. Thaw out coil. Clean out firm gel with coil tubing to 5240' CTM with 3% KCI water. Able to maintain water returns throughout job. PU to 3800' CTM, blow tubing dry with nitrogen. RDMO coil tubing. MIRU Schlumberger electric line. Log TDT from 3600' - 5200'. Perforate C-1 reservoir 5063' - 5093' MD w/2-1/8" strip guns. RDMO electric line. Attempt to flow well without success. Page 1 Alaska Hegion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 2, 1997 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Well 11-8L Dear Mr. Wondzell: Please find attached a revised procedure for the plug back and recompletion of well KU 11o8L in the Kenai 'Field. Sundry Approval for this work has already been granted by Mr. Dave Johnston under approval number 397-164. The attached procedure differs from the original by: 1 ) use of Maraseal to abandon the open perfs instead of cement, 2) inclusion of a TDT Icg prior to perforating, 3) possible inclusion of additional perfs on the basis of the TDT Icg, and 4) less severe pressure testing of the plugged perfs and tubing-casing annulus. This work is expected to commence by October 10, 1997. Please contact me if further information is needed. Sincerely, ~.~~Produc~ion Engineer H:\WP\OPNS97kKUI 18LI Attachment RECE!VED A subsidiary of USX Corporation Environmentally aware for the long run. SENT BY'l~larathon 0tl Company Date; Field/Platform: Lea.ss; Site: Sand: 1 -Oct-97 Kenai Gas Field RnCrlOF age--, Marathon Oil Con~P-a;w Coil Tubi,~glWireline Work Request Well KU 11-8L 41-7 SS: Pool 4.0 B-l, 2 {Sterling) LS: Pool 5.1 B-3, 4 {Sterling) Packer: Tbg: EOT: Mia ID; KB: 26 Est Start Date: 9124197 Est Comp Date: 10t3/97 Tubing Clear: Fill depth: Tree Connection: OBJECTIVE: Dual 4171' Single 4362' SS 3-112" 0.2# N-80 LS 3-1/2" 9.2# N-80 SS 4.185' LS 4381' SS 2.75" {~186'1 LS 2.75" {~,380'} SS LS 5181' {8/27193) SS 3-1/2' 8rd LS 3-1/2" 8rd fill, squeeze off B-3,4 peris Wl Maraseal gel,"i'~i'~"~¥ i%'~ p~ri"'~:l, '"' POTENTIAL PROBLEMS: Sticking coil, difficulty cleaning"'o'~t residuel'g~l, potential fo'r i~'Ultiple squeez'es. ~LAST WIRELINE WORK: IA 3 1/2" scratcher was run to 5181' 0'n 8127193. Gr,~dient survey run at 4426' same day. ,., PROCEDURE: ":1) Hold safety/environmental meeting; ' i~e'view'~'~e'~ure'~'-~-~'~'~:;'-~ and LS are SI. 2) RU wireline unit on LS, Function test wireline BOPs and test lubricator against SI wellhead pressure. 3) RIH w/2,70" GR and tag fill. POOH and RD, 4~ RU pump truck on annulus. MU 500 bbls 3% KCI water, !!il PT tubing-casing annulu.~ to 1000 psig while monitoring SS a~d LS pressure, 6) RU pump on LS, test lines, Pump 10 bbl of 3% KCI and 300 bbl Ma~aseal gel, Displace w/4 bbl of 3% KCI. 7) RD pump truck. Allow gel to set for minimum of 24 hours. 8) RU 1-1/2" coil tubing. Test lines to 4000 psi, RIH w/coil tubing, Circ. ul~te wellbore clean to too of fill w/ 3% KCI. Verify that well will hold a column of water to ensure thor all zones are plugged. If test fails, repeat steps 6 through 8. 9) Wash fill to at least 5200'. 113) PU to 6050' and pump N2 at maximum rate and cirolute well dry, POOH, 11! Blow wall down to 100 psig and monitor WHP, RD CTU, 12) Repeat step 1 w/E-line crew. 13) RU E-line, PT to SI WHP, ,14) Run TDT log to TD. EvalUate for possible perle to be added $O63' - 5093'. 15~ Perforate 5063' - 5093' (30', if TDT log supports), BO20-§OAS' 126'), ,5010-5020' [10'), 4980-~,996' I1 iw/2-1/2" Hnllnw carrier gunS, 16) RD and flow well. .., QUESTIONS/COMMENTS? Pete Bergs-S64-6319 Wayne Cissel-283-3766 APPROVALS: ~~-.._-_.~ (W. C. Barron, Gary Ellet-E6&-6315 Fax to KGF Foreman G:cmn\drlg?,gf\wells\ku 1 1-8,!~ctprog2.x!, RECEIVED i 0 ?_ 1997 0il ,& Gas Cons. L;o.u~ 'Anchorage ~tform: 1 -Oct-97 Kenai Gas Field 41-7 SS: Pool 4.0 B-l, 2 (Sterling) LS: Pool 5.1 B-3, 4 (Sterling) 26.7' t Date: 9/24/97 ~p Date: 10/3/97 Packer: Dual 4171 ' Single 4362' Tbg: SS 3-1/2" 9.2// N-80 LS 3-1/2" 9.2// N-80 EOT: SS 4185' LS 4381' Min ID: SS 2.75" (4185') LS 2.75" (4380') Tubing Clear: SS Fill depth: LS 5181' (8/27/93) Tree Connection: SS 3-1/2" 8rd LS 3-1/2" 8rd 'i~/E: fill, squeeze off B-3,4 perfs w/Maraseal gel, ruri-i:E~)-g¥~r~ c-1. 'IAL PROBLEMS: :ing coil, difficulty cleaning out residual gel, potential for multiple squeezes. IRELINE WORK' 1/2" scratcher was run to 5181' on 8/27/93. Gradient survey run at4426' same day. URE: ioldsafety/environmentalmeeting. Review procedure. Ensure SS and LSareSI. IU wireline unit on LS. Function test wireline BOPs and test lubricator against SI wellhead pressure. JH w/2.70" GR and tag fill. POOH and RD. LI pump truck on annulus. MU 500 bbls 3% KCI water. T tubing-casing annulus to 1000 psig while monitoring SS and LS pressure. -J pump on LS, testlines. Pump 10bblof 3% KCland 300bblMarasealgel. Displace wi4 bblof 3% :) pump truck. Allow gel to set for minimum of 24 hours. J 1-1/2" coil tubing. Test lines to 4000 psi. RIH w/coil tubing. Circulate wellbore clean to top of fill w/ :Cl. Verify that well will hold a column of water to ensure that all zones are plugged. If test fails, repeat ' 6 through 8. ash fill to at least 5200' . 2U to 5050' and pump N2 at maximum rate and circlute well dry. POOH. · 31ow well down to 100 psig and monitor WHP. RD CTU. :~epeat step 1 w/E-line crew. ~U E-line. PT to SI WHP. ,un TDT log to TD. Evaluate for possible perfs to be added 5063' - 5093'. ~erforate 5063'-5093' (30', if TDT log supports), 5020-5045' (25'), 5010-5020' (10'), 4980-4995' (1E~') 1/2" Hollow carrier guns. :~D and flow well. ~IS/COMMENTS? Pete Berga-564-6319 Wayne Cissel-283-3766 -~ (W. C. Barton) F Foreman Gary Eller-564-6315 G :cmn\drlg\kgf\wells\ku 11-81\ctprq.g2:.x, Is, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O:~EXCEL ~SUNDR¥.XLS 1. Type of Request: Abandon Suspend Operation Shutdown Re-enter Suspended Well Alter Casing Repair Well Plugging X Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate X Other Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 374'FNL, 4266'FWL, SEC.7, T4N, R1 lW, S.M. At top of Productive Interval 748'FNL, 792'FWL, SEC.8, T4N, R1 lW, S.M. At Effective Depth At Total Depth 855'FNL, 1296'FWL, SEC.8, T4N, R11W, S.M. 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service Datum Elevation (DF or KB) 26.7 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 11-8L 9. Permit Number 82-97 10. APl Number 50-- 133-20357 11. Field/Pool KENAI GAS FIELD/STERLING POOL 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 5364 feet Plugs (measured) 5273' PBTD 4879 feet feet Junk (measured) feet "IVNIgI IO Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length Size Cemented Measured Depth 20" Driven 132' 13 3/8" 1275 sacks 2000' 95/8" 1500 sacks 5362' B-4: 4467-4522; B-3: 4395-4425; B-2: 4337-4353; B-I' 4225-4274. B-4: 4058-4107; B-3: 3993-4020; B-2: 3941-3955; B-I' 3840-3884. True Vertical Depth 132' Tubing (size, grade, and measured depth) 4877' SF_.? 9 1997 ~cliorage Long string: 3 1/2", 9.2 ppf, N-80 to 4381' Short string: 3 1/2", 9.2 ppf, N-80 to 4185'. Packers and SSSV (type and measured depth) A-5 dual packer at 4171'. Model F-1 packer at 4362'. 13. Attachments DeScription Summary of Proposal __ Detailed Operations Program _~X BOP Sketch 14. Estimated Date for Commencing Operation 9/24/97 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas _~X Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~.~~ FOR CO MTitl~ I~Si O~,~y~,~~ Conditions of Approval: Notify Commission so representative may witness Plug Integrity__ BOP Test f Location Clearance Mechanical Integrity Test__ Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. 06/15188 ]Approval No. ~)~ ~,) _ Commissioner Date Submit in Triplicate Date: 9~8~97 Field/Platform: Lease: Site: Sand: Marathon Oil Company Coil Tubing/Wireline Work Request Well KU 11-8L Kenai Gas Field 41-7 SS: Pool 4.0 B-l, 2 (Sterling) LS: Pool 5.1 B~3, 4 (Sterling) KB: 26.7' Est Start Date: 9/24/97 Est Comp Date: 10/3/97 Packer: Tbg: EOT: Min ID: OBJECTIVE: Tubing Clear: Fill depth: Tree Connection: Dual 4171' Single 4362' SS 3-1/2" 9.2// N-80 LS 3-1/2" 9.2// N-80 SS 4185' LS 4381' SS 2.75" (4185') LS 2.75" (4380') SS LS 5181' (8/27/93) SS 3-1/2" 8rd LS 3-1/2" 8rd Tag fill, squeeze off B-3,4 perf, perf C-1. POTENTIAL PROBLEMS: Sticking coil, multiple attemps may be required to get a good squeeze. LAST WlRELINE WORK: A3 1/2" scratcher was run to 5181' on 8/27/93. Gradient survey run at 4426' same day. PROCEDURE: 1) Hold safety/environmental meeting. Review procedure. Ensure SS and LS are SI. 2) RU wireline unit on LS. Function test wireline BOPs and test lubricator against SI wellhead pressure. 3) RIH w/2.70" GR and tag fill. POOH and RD. 4) Repeat step 1 w/CTU crew and stage PTS tank, Haliburton tank and BC tank. RU lines. MU 500 bbls 3% KCI water. MU 150 bbls WF120 gelled water. 5) PT tubing-casing annulus to 2000 psig while monitoring SS and LS pressure. 6) RU 1-1/2" CTU w/wash nozzle and back pressure regulator valve. PT lines to 4000 psig. 7) RIH pumping 1/4 bpm. Tag fill. Flag coil 10' above fill depth. PUH to TT. 8) MU 20 bbls latex cement per Dowell design. Check fluid loss data. MU 50 bbls 1.2 #/bbl Biozan pill. 9) RIH to 4522'. W/return line SI, pump 10 bbls 3% KCI water, 16.5 bbls cement. Displace w/Biozan. Spot 1 bbl out CT, then PUll to 3691' on a 1:1 ratio until cement is placed. 10) Note CT-Tubing annulus pressure. Perform hesitation squeeze in 250 psig increments every 30 minutes to a maximum squeeze pressure of 1000 psig over noted annulus pressure. Do not squeeze more than 6.75 bbls. Hold final squeeze pressure for 1 hour. 11 ) Open choke and launch ball. RIH contaminating cement at a 50% ratio. Make 3 down passes and 2 up passes at ~ 80 ft/min, slowing pump speed across perforations. Circulate hole clean w/20//gelled water and POOH slowing across XN and XA sleeve. Allow cement to set up for 2 days. 12.) RU pump and PT cement plug to 1000 psig. If test fails, repeat steps 4 through 12. If test is good, RIH w/CT to insure there are no restrictions and tag fill. If fill is above 5100' consider cleaning out well. 13. PU to 5050' and pump N2 at maximum rate and circlute well dry. POOH. 14. B ow well down to 100 psig and monitor WHP. RD CTU. 15. Repeat step 1 w/E-line crew. 16. RU E-line. PT to SI WHP. 17. Perforate 5020-5045' (25'), 5010-5020' (10'), 4980-4995' (15')w 2-1/2" Hollow carrier guns. 18. RD and flow well. QUESTIONS/COMMENTS? Fax to KGF For~'man Pete Berga-564-6319 Wayne Cissel-283-3766 (W. C. Barron) Gary Eller-564-6315 Mike Olson-903-509-5450 G:cmn\drlg\kgf\wells\ku 11-81\ctprog.xh Union Oil and Gas .Division: Western Region Union Oil Compar,, .~f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, ,n DOCUMENT TRANSMITTAL November 27, 1984 FIRST CLASS MAIL TO: Fran Jones FROM: LOCATION.- Anchorage LOCATION: ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: Regarding: KU 11-8 - One (1) copy of registered survey plat PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECE VED DA TED: Anchorage ~_C~9.86 K U ll-8 (Center of Cellar) _ Set Wood hub & nail Lat. 60°27'30.461"N Long 151°14'43 870" W X = 275,167.07 Y : 2,361,622 16 NW corner SEC. 7 4266' N.T.S. SCALE l" = 300' LEGEND AND NOTES' ~) Found G.L.O. brass cap monument. All bearings refer to the West line of Section 7 as being North. Top of gravel pad elevation is 77.2 feet above MLLW of Cook Inlet or 66 1 feet above Mean Sea Level. Basis of coordinates is USC&GS Tri Station AUDRY in ASP Zone 4. ~ AUDRY. · Lat. 60o30' 50.599"N Long.151°16'37.445"N X: 269,866.75 Y= 2,382,045.42 · K.U. !1-8 PREPARED FOR , ~ UNIQN Oil CQMPANY.OF CALIF OPERATOR SURFACE LOCATION' 374 Ft. South and 4266 Ft. East from the NW Corner Section 7, T4N, RllW, S.M., Alaska. Surveyed by' McLane & Associates, Inc. Date o¢ Survey: June 18, 1982 _~k,>.:." ~, '".?+~, ~.-' ~~ '..~ ~, ~ "~QTH ~ ~ RECEIVED ~ov 2 9 Bk. No. 82-~ska 0~ & Gas Anchor~l~ , , , ,, , AiA$1~A Oil MID Bill Sheff!eld, (;overnor 3001 PORC'UPINE DRIVE ANCHORAGE,ALASKA ggs01.1-3l'g 2 TELEPHONE (907) 279,-1433 DATE: O,~TL'o ~r 4 ~. / ~ ~ ./~. n_.'~-- ~, £. I,¢'A ,,-//~,~ ,, . ~~ .o. ~ 77' We wish to bring to your attention that the Commission has nofi yet received the following required items on the subject well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled~well. Please submit the above missing material. C. V. Chatteruc~ Chairman lc:C.024 Union Oil and Gas ~ion: Western Region Alaska Expl~ ~,tion District Union Oil Company or California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 October 18, 1982 HAND DELIVERY union DOCUMENT TRANSMITTAL TO: William Van Alen State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Anchorage, AK FROM: R. C. Warthen REFERENCE: KU 11-8 One (1) blueline and one (1) sepia of the following: CDL-GR 5" CDCN-GR 5" DIL 2" and 5" BHC 2" and 5" One (1) mag tape #1427 and verification list One (1) each Directional Survey, Tang., Ang. Ave., Rad. of Curv. ~.AS~. ACKNOW~,~.DS~. R~.C~.~P? BY S~SN~US ~D R~.?U~S O~. COPY DATED: D ~ · " '~ STATEOF ALASKA · ALASKA O,,JAND GAS CONSERVATION C .O.',.../IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well .... OIL [] GA SUSPENDED [] - ABANDONED []: SERVICE [] , 2. Name of Operator 7. Permit Number · UNION OIL CONPANY OF CALIFORNIA 82-97 3. Address 8. APl Number pO BOX 6247 ANCHORAGE AK 99502 50-133-20357 4. Location of well at surface 9. Unit or Lease Name 374'S & 4266'E of NW Cot, Section 7, T4N, RllW, SH. KENAI UNIT At Top Producing Interval 10. Well Number 748'S & 792'E off NW Cor, Section 8, T4N, RllW, SN. KU #11-8 At Total Depth 11. Field and Pool 855'5 & 1296'E of NW Cor, Section 8, T4N, RllW, 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. KENAI GAS FIELD Pad 66' MSLI A-028142 Sterling Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of ComPletions 8713/82 8/20/82 9/1/82 ___ feet MSLI 2 -17. Total Depth (MD+TVD)5364 ' & 4857 ' 18. Plug Back Depth (MD+TVD)5273 ' & 4776 ' YES/j~'19' Directional SurveYNo [] I20' Depth where sSSV setfeet MD I21' Thickness Of PermafrOst · . 22. Type Electric or Other Logs Run DTL-SP-CR-BHC-Sonic, CNL-FDC-GR, CBL-VDL-GR-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD C.ASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20,, 94 H-40 0 132. Driven Driven --- 13 .3/8 61 K-55 0 2000 17 1/2 1275 sxs --- . 9 5/8 47 N-80 0 5362. 12 1/4 1500 sxs --- - 24. Perfora_tions o.pen to Rrodgction (MD+TVD of Top and Bottom and 25. ~ TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD HPF Pool ,3 1/2" --- 4363' B-4 4467----4522' 4058-4107' 8 5.1.. 3 .:l/2" --- 4170 ' 8-3 4395-4425' 3993-4020 ! ' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8,2. 4337-4353' 3941-3955, -. !! .. 4: DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , B-1 4225-4274' 3840-3884' " " · · 27. PRODUCTION'TEST I-:Method of OperatiQn (Flowing, gas. lift, etc.) Date.E~. 't Pfoduction - . .: ,:-'~ .. . 9/19/82I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKESIZE IGAS-OILRATIO R/:3N/R~2 ..... 6 TEST BERIOD..I~ · : 2375 SSI . . _ I FloW.·¢:Nbing... Ca.sing Pressure - CALCULATED' -~ OIL'~BBL G'~i~i~.~FLS WATER-DEL OIL GRAVITY-APl (corr) Press..· ~nn¢~- .. ---- :4-HoUI~ RATE'I~ ' ~ ~' "9500 SS ' 28. CORE D~j~Ii~0 LS Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' '" RECEIVED NONE .' : : ,. "." ;' , ' '- . .' ~:,-~'.,, . · SEP 2 ! 982 . . . . .:. - , ~ ,-:, -: ., .. - ~ .:: . ,. Alaska0jl& Gas Cons. Commission · .. . ,-. Anchorage V Form 10-407 Submit in duplicate Rev. 7ol-80 CONTINUED ON ,REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/Sterling 3993' 3649' Tested Pool 5.1 thru LS = 9.1 MMCFPD w/ Gas Sands 14 BWPD ~ +800 psi T/Beluga Fm. 5253' 4780' Tested Pool 4 thru SS = 9.5 MMCFPD w/ 9 BWPD ® +800 psi , , , 31. LIST OF ATTACHMENTS 32. I hereby~ that the fOregoing is true and correct to the best of my knowledge Sig 'ned,' Title DIST DRLG SUPT Date 9/14/82 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate whiCh elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval repo~ted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item Z7: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Fnrm 1 ~.4n-7 UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Kenai Unit WELL NO. FIELD KGF Sterling Rool KU #11-8 LOCATION: 374'S & 4266'E of NW oorner~ Section 7~ .T4N~ RllW~ SM (surface) SHEET A PAGE NO. 1 SPUD DATE 8/13/82 COMP. DATE 9/1/82 ~ CONTRACTOR Brinkerhoff RIG NO. 59 TYPE UNIT * DRILL PIPE DESCRIPTION 5" HWDP: 4 1/2 IF Z PERMIT NO. 82-97 SERIAL NO.A-028142 ID 5364' TVD 4857 ' DEVIATION (BHL) COMPANY ENGINEER Watson, ~raham ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR * RT TO GL 29.0' RT TO DRILL DEC~ RT TO PRODU~TIQN r~r~/?' ..~ APPROVE - ' - CASING & TUBING R~CORD SIZE WEIGHT THREAD .GRADE DEPTH REMARKS 20" 94# - H-40 132' Driven 13 3/8" 61# BUtt. K-55 2000' 1275 sxs cl "G" cmt w/ additives 9 5/8" 47# Butt. N-80 5362' 1500 sxs cl "G" cmt w/ 5% kcl~ .4% 3 1/2" 9.2# Butt. N-80 4382' D-31~ .2% D-6~ .8% D-28 & .4% D-47. LS Dual Baker A-5 3 1/2" pkr 3 1~2" .... 9.2# . Butt.. N-80 4186' SS " " PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 8/2~/82 4467-4522' 5273' (FC) B-4 sds 8 HPF - open to production 8/27/82 4395-4425' " B-3 sds " " " 8/27/82 4337-4353' " B-2 sds " " " 8/27/82 4225-4274' " B-1 sds " " " INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. FTP CHOKE MCF GOR REMARKS 9/19/82 B-3 & B-4 LS 800 psi 9100 LS w/ 14 BWPD BLi'& Bz2 SS 9'500 SS 'W/ 9 BWPD Sterling Pool 800 psi WELL HEAD ASSEMBLY TYPE: CASING HEAD: CIW 13 3/8" SOW x 13 5/8" 3M Cs~ Head · CASING HANGER: CIW tYpe "AW" ,, TUBING HEAD: CIW "DCB" 13 5/8" 3000 psi x 10" 5000 psi TUBING HANGER: Dual Cameron 3 1/2" "DCB-B" 8rd TUBING HEAD TOP: 3 1/2" 8rd EUE MASTER VALVES: CHRISTMAS TREE TOP CONN: 3 1/16" 5000 psi 3 1/2" 8rd UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028!42 WELL NO. KU #11-8 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS A 8/11/82 DAILY COST: ACC COST: AFE ANT: B 8/12/82 DAILY COST: ACC COST: AFE ANT: I 8/13/82 DALLY COST: ACC COST: AFE AMT: $ 61,353 $ 61,353 $2,200,000 20" D. 132' $ 26,197 $ 87,550 $2,200,000 266'/234' 20" D. 132 66 PCF 150 SEC $ 28,278 $ 115,828 $2,200,000 Commenced operations over KU #11-8 ~ 00:01 hrs 8/11/82. Strung up blocks and raised derrick. Continued general rig up. RU Delmag D-22 drive hammer and drove 20" 94# drive pipe to refusal ~ 132' w/ 250 BPF. Completed general rig-up. Drove rathole. Cut off 20" csg and installed 20" 2N sow flange. Installed 20" Hydril and diverter system. Spudded well w/ 17 1/2" bit ~ 20:15 hrs. Cleaned out drive pipe f/ 32' to 132' and drilled 17 1/2" hole f/ 132' to 266'. 2 8/14/82 822'/556' 20" D. 132 67 PCF 51 SEC DAILY COST: $ 48,612 ACC COST: $ 164,440 AFE AMT: $2,200,000 3 8/15/82 2005'/1183' 20" D. 132' 70 PCF 49 SEC DAILY COST: $ 87,273 ACC COST: $ 197,713 AFE ANT: $2,200,000 Drld 17 1/2" hole f/ 266' to 300'. Circ & POOH. RIH w/ bit #2 on BHA #2 for Dyna-drill run #1. Oriented Dyna-drill and DD 17 1/2" hole f/ 300'-822'. Circ & POOH. RIH w/ BHA #3 & reamed Dyna-drill run. DD 17 1/2" hole f/ 822'-1410'. Circ and POOH. RIH w/ BHA #4 and DD 17 1/2" hole f/ 1410-2005. Circ and POOH to run csg. RECEIVED · F E B i. 8 Alaska Oil & Gas Cons, Commis$io. Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #11-8 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4 8/16/82 2005'/0' 20" D. 132' 13 3/8" C. 2000' 70 PCF 51 SEC DAILY COST: $ 158,381 ACC COST: $ 350,094 AFE AMT: 5 8/17/82 DAILY COST: ACC COST: AFE AMT: 6 8/18/82 DAILY COST' ACC COST: AFE AMT: 7 8/19/82 DAILY COST: ACC COST: AFE AMT: $2,200,000 2010 '/5 ' 20" D. 132' 13 3/8" C. 2000' 68 PCF 47 SEC $ 30,760 $ 380,854 $2,200,000 3278'/1288' 20" D. 132' 13 3/8" C. 2000' 69 PCF 49 SEC $ 28,718 $ 409,572 $2,200,000 4020'/722' 20" D. 132' 13 3/8" C. 2000' 76 PCF 51 SEC $ 35,396 $ 444,968 $2,200,000 RU and ran 13 3/8" 61# K-55 buttress casing. Set shoe $ 2000', F.C. $ 1953'. RIH w/ 5" d.p. w/ stab-in tool and stabbed into float collar. Broke circ. and circ. clean. Pumped 50 Bbls. of caustic water ahead of 1025 sx c1 "G" w/ 2 1/2% gel and 2% CaC12 followed by 250 sx cl "G" w/ 2% CaC12. Displaced w/ 10 Bbls. H20 and 18 Bbls. of mud. CIP $ 13:20 Hrs. W.O.C. 8 hrs. POOH w/ d.p. Removed hydril and cut off excess 13 3/8" and 20" csg. Made final cut on 13 3/8" csg. Installed and tested CIW 13 3/8" sow x 13 5/8" 3M csg head. Installed BOPE and tested to 3000 psi-ok. Tested csg to 2500 psi. RIH w/ '12 1/4" bit #3 RR on BHA #5 and cleaned out float collar and cmt to 1990'. Tested csg to 3000 psi. Cleaned out shoe ® 2000' and drilled to 2010'. Performed leak off test-shoe held 90 PCF equivalent. Circ and POOH. RIH w/ bit #4 on BHA #6 (30' belly) and directionally drilled 12 1/4" hole f/ 2010' to 2450'. POOH. RIH w/ bit #4 on BHA #7 (locked up w/ lC' lead collar). Directionally drilled 12 1/4" hole f/ 2450' to 2921'. POOH. RIH w/ bit #5 on BHA #8 (locked up w/ tandem N.B. stabs) and directionally drilled 12 1/4" hole f/ 2921' to 3298'. Directionally drilled 12 1/4" hole f/ 3298' to 3718' POOH. RIH w/ bit #6 on BHA #8 ilO' pendulum) and directionally drilled 12 1/4" hole f/ 3718' to 4020'. Bade short trip to shoe. Circ & POOH. RIH w/ bit #7 on BHA #9 for Dyna drill run #2. Alaska Oil & Gas Cons, Commission Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #11-8 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8 8/20/82 DAILY COST: ACC COST: AFE AMT: 4542'/522' 20" D. 132 13 3/8" C. 2000' 72 PCF 45 SEC $ 146,989 $ 591,957 $2,200,000 Orient Dyna-Drill for left hand turn. Dyna-Drill f/ 4020 to 4100'. POOH. RIH w/ bit #7 on BHA #11. DIP drill 12 1/4" hole f/ 4100' to 4297'. POOH. RIH w/ bit #7 on BHA #12. Dir drill 12 1/4" hole f/ 4297' to 4542'. 9 8/21/82 DAILY COST: ACC COST: AFE ANT: 5364'/822' 20" O. 132 13 3/8" C. 2000' 71PCF 45 SEC $ 33,596 $ 625,553 $2,200,000 DIP drill 12 1/4" hole f/ 4542' to 5136'. POOH. RIH w/ bit #8 on BHA #13. OIR drill 12 1/4" hole f/ 5136' to 5364'. CIRC & cond hole for logs. 10 8/22/82 DAILY COST: ACC COST: AFE AMT: 11 8/23/82 DAILY COST: ACC COST: AFE AMT: 5364'/0' 20" D. 132' 13 3/8" C. 2000' 72 PCF 47 SEC $ 87,160 $ 712,713 $2,200,000 5364'/0' 13 3/8" C. 2000' 9 5/8" C. 5362' 74 PCF 44 SEC $ 381,642 $1,094,355 $2,200,000 Complete short trip. Circ clean. POOH. Ran DA DIL-SP-GR-BHC-Sonic & CNL-FDC-GR f/ 5368' WLTD to 13 3/8" shoe. (OH-VDL did not work in two attempts). RIH. Circ clean-POOH. Ran 9 5/8" 47# N-80 Butt csg. Rigged up & circ csg annulus clean while reciprooiating csg. Cemented 9 5/8" csg w/1500 sxs "G" w/ 5% KCL .4% D-31 .2% D-6 .8% D-28 & .4% D-47. Reciprocated csg while cementing until so WT decreased to 60,000 #. Pumped 50 bbls water ahead & displaced w/ mud. Did not receive any cmt returns to surface. Bumped plpg w/ 2500 psi. CIP ~ 21:50 hrs. B 1 8 1983 Gas Cons. oommissior~ AnChorage UNION OIL COWPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #11-8 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12 8/24/82 5364'/T. D. 5273' ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' '73 PCF 31 SEC DAILY COST: ACC COST: AFE AMT: $ 25,751 $1,118,636 $2,200,000 13 8/25/82 5364' T.D. 5273' ETD (FC) 13 3/8" C. 2000' 9' 5/8" C. 5362' 65 PCF KCL FLUID DALLY COST: ACC COST: AFE AMT: $ 30,907 $1,149,543 $2,200,000 14 8/26/82 5364' T.D. 5273' ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' 64 PCF Brine DAILY COST: ACC COST: $ 44,074 $1,194,618 AFE AMT: $2,200,000 15 8/27/82 5364' T.D. 5273' ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' 64 PCF BRINE DAILY COST: ACC COST: $ 80,161 $1,274,749 AFE AMT: $2,200,000 Remove BORE. Cut off 9 5/8" csg. Installed CIW slips & DCB spool. Installed & tested BORE. Tested 9 5/8" csg to 2500 psi. CO to 5273' w/ 8 1/2" bit & 9 5/8" csg scraper. Circ clean. ROOH. Ran gyro survey on D.A. wireline. Ran CBL/VDL/GR/CCL log f/ 5273' to surface. R.D. Dresser Atlas. RIH w/ 8 1/2" bit on 9 5/8" csg scraper to 5273'. Cleaned mud pits and mixed KCL completion fluid. X-Over to 3 % KCL Completion fluid. Layed down HWDP. Set RTTS on tbg ~ 4173'. Displaced tbg w/ nitrogen. Perf'd sterling "B-4" w/ 2 1/8" guns 4 HPF f/ 4467' to 4487' under 600 psi drawdown. Worked perf gun into tbg (1 hr). Inflow perf'd "B-4" w/ same guns f/ 4487' to 4521' (2 runs) Tested "8-4" perf's f/ 4467' to 4522'. Final rate 6.35 MMCFPD & no water 8 860 psi. Inflow perf'd 4 HRF using 2 1/8" guns the "B-3" f/ 4395' to 4425', "B-2" f/ 4337' to 4353' & "B-l" f/ 4225' to 4274'. Test well until clean. Final rate 8.79 MMCFRD, 4.8 BWRD ~ 850.psi. Killed well. RIH to 4550'. Spot 20 RRB CACO3 & 2 RRB "XC" in 3% KCL f/ 4550' to 4000". POOH. RECEIVED FEB 1 8 19B2 Al~sk~ Oil & Gas Cons, Commissior, Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #11-8 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 16 8/28/82 DAILY COST: ACC COST: AFE AMT: 17 8/29/82 DAILY COST: ACC COST: AFE AMT: 18 8/30/82 DAILY COST: ACC COST: AFE ANT: 19 8/31/82 5364' T.D. 5273 ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' 64 PCF BRINE $ 72,068 $1,346,817 $2,200,000 5364' T.D. 5273' ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' $ 179,198 $1,526,015 $2,200,000 5364' T.D. 5273' ETD (FC) 13 3/8" C. 2000' 9 5/8" C. 5362' $ 39,199 $1,565,215 $2,200,000 5364' I.D. 5273' ETD 13 3/8" C. 2000' 9 5/8" C. 5362' DAILY COST: $ 21,945 ACC COST: $1,587,159 AFE AMT: $2,200,000 20 9/01/82 DAILY COST: ACC COST: AFE AMT: 5364' T.D. 5273' ETD 13 3/8" C. 2000' 9 5/8" C. 5362' $ 69,910 $1,657,069 $2,200,000 Perf'd 4 HPF w/ 4" csg guns on 120° phasing the "B-4" f/ 4467' to 4522', "B-3" f/ 4395' to 4425', "B-2" f/ 4337' to 4353' & the "B-i" f/ 4225' to 4274'. RIH w/ 8 1/2" bit & 9 5/8" osg scraper to 5273'. CIRC clean. POOH. Ran gauge. Ring & junk basket to 4500'. Set baker "0" pkr on WL ~ 4363' OIL. RIH w/ seals on DP & test PKR ~ 4363'. POOH. Layed down drill pipe. Rigged up & ran dual 3 1/2" comp. assy. Stabbed into "0" pkr ~ 4363' & tested same. Set & tested "A-5" dual pkr ~ 4170'. LS MS ¢ 4382' SS MS 8 4186'. Installed BPV'S. Removed BOPE. Installed CIW dual 3 1/2" tree. Tested 3 1/2" dual CIW tree. Opened sleeve in LS ~ 4137' & displaced annulus w/ RKR fluid. Closed sleeve ~ 4137' & opened sleeve ~ 4298'. Displaced LS w/ nitrogen taking returns in SS until well came on. Closed "XA" ~ 4298'. Tested sterling "B-3" & "B-4" thru LS ~ 9.1 MMCFRD & 14 BWPD ~ + 800 psi. Shut in LS. Tested "B-iT & "B-2" thru SS ~ 9.5 MMCFRD & 9 BWRD ® + 800 psi. Shut in well. Installed BRV'S. Released rig tc moving rate @ 13:00 hrs. 8/30/82. Rig down. ., Moved Rig to brinkerhoff yard. Release rig ~ 19:00 hrs 9/01/82. LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO, KU #11-8 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS DESCRIPTION 13 3/8" CASING DETAIL LENGTH TOP BTW 47 13 3/8" B&W Float Shoe Butt 13 3/8" 61# J-55 Butt 13 3/8" B&W Stab-in Float Collar Butt 13 3/8" 61# $-55 Butt 13 3/8" 61# $-55 Butt Pin x Cutoff CIW 13 3/8" SOW Head/12" 3000 Flange 1.72' 1998.05' 1999.77 43.16' 1954.89' 1998.05 2.15' 1952.74' 1954.89 1919.74' 33.00' 1952.74 2.88' 30.12' 33.00 1.40' 28.78' 30.12 Centralizers 10'-30'-60' above shoe; then every jt for 500'; then every other jt fo: · 1000'; then every 4th jt to surface. Two cmt bskts 50' & 55' below surface. Cmt'd w/ 1025 sxs el "G" w/ 2 1/2% pre-hydrated gel & 2% CaCL2 followed by 250 sx, "G" w/ 2% CaCL2 tail~slurry. Displaced w/ mud. Had good returns to surface. CIP r. 13:20 hrs 8/16/82. RECEIVEO FEB 1 8 1983 Alaska. Oil & Gas Cons CDrnmis:;ior~ Anchorage LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #11-8 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS DESCRIPTION 9 5/8" CASING DETAIL LENGTH TOP BTM ,, ,, 6 2 12 112 9 5/8" Float Shoe (Butt) 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Float Collar (Butt) 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Pup #A 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Pup #B 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Pup #C 9 5/8" Csg 47# N-80 (Butt) 9 5/8" Csg 47# N-80 (Butt) X Cut off Landed below RT KB 1.66' 5362.34' 5364.00' 84.19' 5278.15' 5362.34' 1.42' 5276.73' 5278.75' 254.28' 5022.45' 5276.73' 20.50' 5001.95' 5022.45' 81.43' 4920.52' 5001.95' 487.50' 4433.02' 4920.52' 21.01' 4412.01' 4433.02' 38.22' 4373.79' 4412.01' 20.98' 4352.81' 4373.79' 4292.42' 60.39' 4352.81' 32.67' 27.72' 60.39' 27.72' 0 27.72' Total of 136 jts 47# N-80 Csg run in hole Note: *9 5/8" csg landed on slips in bowl of CIW 13 3/8" SOW head with 12" 3000~ flange up 9 5/8" headed with CIW DCB spool 12" 3000 flange down & 10" 5000# flang~ up face of 10" 5000# flange e 26.72' below RT. *Turbolizers run 10', 30' & 60' above shoe and every jt to 4000'. Centralizers rur every jt from 4000-2000'. Rigid bows run from 2000'-surface on every other jt. : cement baskets run ~ 4080.63' and 4042.11' respectivelY. Cmt'd w/ 1500 sxs "G" w/ 5% kcl, .4% D-31, .2% D-6, .8% ..D-28 and .4% D-47, Reciprocated csg while cmtg until down wt decreased to 60,000#. Displaced w/ mud. Didn't receive any cmt returns to surface. Bumped plug w/ 2500 psi. CIP ~ 21:5[ hrs 8/23/82. RECEIVED FEB 1 8 IBB2 Alaska Oil & Bas Cons. Commission Anchorage LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #11-8 FIELD SHEET D PAGE NO. 9 Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 12 73 46 135 10 LONG STRING TUBING DETAIL DESCRIPTION 3 1/2" Butt Baker Wireline Guide 3 1/2" Butt Otis XN Nipple 3 1/2" 9.2# N-80 Butt Pup Seal Assy for Baker F-1 Rkr Locater Sub 3 ea 20" x 4 1/2" OD Blast Jts 3 1/2" Butt 3 1/2" Butt Otis XA Sleeve 5 ea 20" x 4 1/2" OD Blast Ors 3 1/2" Butt 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Pup 9 5/8" 47# x Dual 3 1/2" Butt Baker A-5 Rkr 3 1/2" 9.20# N-80 Butt 3 1/2" Butt Otis XA Sleeve 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Pup XO 3 1/2" Butt - 3 1/2" 8rd CIW Hanger 3 1/2" 8rd - 3 1/2" 8rd KB Total Joints Total Pup jOints TOP BTM 4381.45' 4382.23' 4379.70' 4381.45' 4374.57' 4379.70' 4362.00' 4374.57' 4361.15' 4362.00' 4302.06' 4361.15' 4298.14' 4302.06' 4199.63' 4298.14' 4189.59' 4199.63' 4183.44' 4189.59' 4170.74' 4183.44' 4140.82' 4170.74' 4136.90' 4140.82' 4130.78' 4136.90' 3770.16' 4130.78' 3766.91' 3770.16' 3677.56' 3766.91' 3672.31' 3677.56' 1458.60' 3672.31' 1453.55' 1458.60' 46.31' 1453.55' 36.29' 46.31' · 32.23' 36.29' 28.15' 32.23' 27.65' 28.15' 26.72' 27.65' 0 26.72' Landed tbg hanger in CIW DCB spool w/ 10" 5000# flange up LENGTH .78 1.75 5.13 12.57 .85 59.09 3.92 98.51 10.04' 6.15' 12.70' 29.92' 3.92' 6.12' 360.62' 3.25' 89.35' 5.25' 2213.71 ' 5.05' 1407.24' 10.02' 4.06' 4.08' .50' .93' 26.72' UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE A-028142 WELL NO. KU #11-8 FIELD SHEET D PAGE NO. Kenai Gas Field lO DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS SHORT STRING TUBING DETAIL STS DESCRIPTION TOP BTM _ LENGTH 84 14 lO lO 3 1/2" Butt Otis XN Nipple 9 5/8" 47# A-5 Baker Pkr 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" Butt Otis XA Sleeve 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# N-80 Butt Pup 3 I/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# M-80 Butt Pup 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Tbg 3 1/2" 9.20# N-80 Butt Pup 3 1/2" 9.20# N-80 Butt Pup XO 3 1/2" 8rd x 3 1/2" Butt Pin to Pin Tbg Hgr CIW 8rd Box to Box Kelly Bushing 4184.59 ' 4186.34 ' 4174.24' 4184.59 ' 4164.14' 4174.24 ' 4133.87' 4164.14' 4129.95' 4133.87' 1583.35' 4129.95' 1579.43' 1583.35' 1151.22' 1579.43' 1146.10' 1151.22' 873.66' 1146.10' 870.56' 873.66' 539.47' 870.56' 533.47' 539.47' 356.75' 533.47' 352.45' 356.75' 44.61' 352.45' 34.51' 44.61' 28.15' 34.51' 27.65' 28.15' 26.72' 27.65' 0 26.72' 1.75' 10.35' 10.10' 30.27' 3.92' 2546.60' 3.92' 428.21' 5.12' 272.44' 3.10' 331.09' 6.00' 176.72' 4.30' 307.84' 10.10' 6.36' 0.50' 0.93' 26.72' Tbg landed with CIW hanger in CIW DCB spool 10" 5000# flange up 26.72' below KB. Total Ots= 134 Total Pups : 8 AlaSk~ Oil & Gas Guns, Gomm~s;ior~ CONTRACTOR Brinkerhoff Si~nal Inc. OIL COMPANY Union Oil Company TOOL RUSHER DR RIG MAKE & MODEL RIG NO. 59 BIT RECORD LEASE/WELL NO. KU #11-8 DR COUNTY Kenai SHEET FIELD/TOWN SEC/TSHIP/ DR RANGE · TOOL STATE Alaska Kenai Gas Field S,e.c,,., 30: TSN, R.1.1~. , · RECORD NO. NO. JOINTS MAKE IF SIZE TYPE 4 1/2 OD 6 5/8" NO. i PUMP (-'4AKE & MODEL Emsco F-lO00 Liner 6 1/2 NO. 2 PUMP MAKE & MODEL Oilwell iO00P Liner 6 SPUD DATE 8/13/82 INTER UNDER SURF DRILL COLLARS NO OD ID LENGTH TD DRILL COLLARS NO OD ID LENGTH RUN JETS 32ND BIT No. ,SIZE M~KE TYPE .... 1 .... 2 .3, S,ER DEPTH FOOT- OUT AGE , WT ACCUM 1000 VERT PUMP No 1 No. 2 MUD DULL COND REMARKS HOURS HOURS ~LB · RPM DEV. PRESS SPM LIN SPM LIN WT VIS ,T, B,,G (FAI,LURE~ ,ETC.) 1PR SEC 17 1/2 S35J 2PR " " 1PR " " 1PR " " 3PR SEC 12 1/4 - 4 HTC 12 1/4 X3A 5 SEC 12 1/4 S33S 6 II Ii HTC 12 1/4 MX3A 'd SEC 12 1/4" S33S 9 Il Il l0 " S44C 130100 122290 130100 I! RA 528 255391 248797 PP262 245939 255419 272197 300 168 822 522 1410 588 2005 595 2010 5 2921 911 3718 797 4020 302 4297 277 5136 839 5364 288 2 1/2 27 90 0 1200 60 49 66 150 2 2 I 6 1/4 15 " " 1100 64 58 66.5 51 2 4 I 5 1/2 35/100 " 1400 58 48 70 49 2 2 I 3 1/2 35 " " " " " " " 3 3 I CO Cmt/FC/FS 6 35 120 0 2300 90 - 69 49 2 2 I 7 1/2 35 110 0 2300 90 - 69 49 2 1 I 3 1/2 30 110 0 " 90 - 76 51 ? 8 1/2 45 110 " " 90 - 73 45 1 1 I DD 80' 13 3/4 " " " " " 71 45 6 2 I 3 " " " " " - 72 47 1 1 I CO Cmt Plug TUBING DETAIL LO/V6' 1.51/2" OTIS "XA" SLEEVE AT 41:56.90' 2. BAKER A-5 DUAL PACKER AT 4170.74' 3. BLAST JOINTS FROM 4199.63' TO 4298.14' 4. 31/2" OTIS "XA" SLEEVE AT 4298.14' 5. BLAST JOINTS FROM 4502.06' TO 4361.15~ 6 LOCATOR SUB AT 4:516.15' T. BAKER f-I PACKER W/SEAL ASSY. AT 4362.00' 8. 31/2" OTIS "XN"'NIPPLE AT 4379.70' 9. BAKER WIRELINE GUIDE AT 4581.45' A. 51/2" OTIS "XA" SLEEVE AT 4129.95' B. BAKER A-5 DUAL PACKER AT 4174.24' C. 51/2" OTIS "X.N" NIPPLE AT 4184.59' PERFORATION DIITE 8126/82 8127182 II II 1A'TEAk'/fL 4467'-- 4522' 4595' - 4425' 4557' -- 4355' 4225' - 4274' RECORD OOIVzglKiOIV B-4 Sd. PRODUCTION II B-3 Sd. B-2 Sd. " II B- Sd. KU 11-8 B 2 '-',. O! 26.72 20'~ 94...~ H-4ODRIVE PIPE AT 132' t3 3/8", 61.~ K-55 CASING AT 2pO0' 95~8". 47~, N - 80 CASING AT 5,362' union kU i I- 8 · WELl SCHEMATIC COMPLETED: 9/I/82~ Well I4U 11-8 IFieldKENAI GAS County KENAIIDate Drawn By B.W. -JCheckecl B~ Approved By Scale ._NONE t Page I Of. I OCr 1 AHF / SCIENTIFIC DRILLING ANCHORAGE OFFICE GYROSCOPIC DIRECTIONAL SURVEY FOR ********************* *UNION OIL OF CALIF.* ********************* JOB NUHBER: 1355 WELL KUll-8 LOCATION: SURVEY DATE: SURVEY ENGINEER: MAGNETIC DECLINATION: KENA1 GAS FItD 08/25/8~ ~' ~ ~' A~ F~ BARRY S. W Drilling AT . O0 E Internationa GYRO REFERENCE BEARING: N 65-45 W HOD OF CALCUkAT~N ¥~RT1CAL SECTION: THE TANGENTIAL METHOD CALCULAIED USING PROPOSAL OF'S 73- ? E C:[IMNENTS: DEPTH 0 IS RKB ELEVATION ABOVE SEA LEVEL THANK YOU THIS SURVEY IS' CORRECT TO THE BEST OF MY *KNOW~DGE AND IS SUPPORTED BY ACTUAL FIELD DATA COMPANY REPRESENTATIVE ' AHF / oL,.[ENTIF'IC DRILLING ANCHORAGE OFFICE PAGE 1 JOB NUHBEI;~: Hli. AS, DEP TH 100, O0 ;?00,00 300. O0 400, O0 500,00 600. O0 7O0. O0 800, O0 9O 0.00 0O0. O0 100.00 200,00 300.00 400, O0 500, O0 VER'i', l')[.'i; P T H 100,00 199,99 299,98 399,96 499,72 599,38 698,63 797,11 894.93 991 ,57 087,64 182,20 271 . 30 360,40 449.50 1355 INRUN SURVEY BY VER T, SECT. -. 83 -1.66 -3.36 -5,08 1,14 THE ..... 1 AN(:,EN1 ~1.. METHOD (.';OLIIR SE ], NC DEV, D M ,87 0-30 N 89-, 1,75 1- 0 N 86-58 W 1,75 1- 0 N 64- 7 W 6,98 4- 0 N 79-55 E LOOR I) LAT'] T UDE , ,03 $ ,03 S ,07 N ,83 N 2,05 N 8.87 20,84 38.04 58,67 84,45 8,88 4-45 N 85-54 E 12,19 7- 0 S 84- 7 E 17,36 10- 0 S 81- 7 E 80.79 18- 0 S 80- 8 E 25.88 15- 0 S 78-15 E 8,64 1 1.29 4.86 10,13 111.90 144,39 185'. 7(I 27,5.03 280.39 87,56 16- 0 S 78-26 E 32,56 19- 0 S 76-48 E 45,40 27- 0 S 76-53 E 45,40 27- 0 S 76-11 E 45.40 87- 0 S 75-29 E 15,66 83.15 53,45 44.29 55.67 DATE: 0 8/25/8;~ ] NATEo D-LEG DEPARTURE PER 100 ,87 W .50 1,75 W ,02 3,49 W ,50 5,06 W ,40 1,81 E 4,85 N N S S S 10.07 E .88 22.19 E 2.46 39.35 E 3.03 59,83 E 2,01 85.17 E 3,03 112,18 E 1.00 143,86 E 3,04 188.07 E 8,00 232.16 E 276,11E ,32 AMF / SCIENTIFIC DRILLING ANCHDRAGE OF'FICE PAGE 2 JOB NUMBER: 355 i';l~ AS, VER'I , VERT, DEPTH DEP'I H SF.' C'I' , 1600, O0 1538,6(} 1700,00 1622.70 1800, O0 1711 . (JO 1900.00 1799,70 2000,00 1888.40 2100.00 1977,50 220 O. O0 P065,79 2300, O0 ;7154,09 24,00, O0 22-4.1 .76 2500 . O0 2329.22 2600,00 2416,04 2700,00 2502,86 P800,00 2589,68 2900,00 2677,15 3000,00 2764,61 325,75 379.74 426,6b 472,74 518,87 564.21 611,09 657,99 706,05 754,5(! 804,11 853.71 903,33 951.81 1000,28 INR I. JN SURVEY BY THE TANGENTI~AL METHOD COUR SE ]' NC !G DEV, D H 4,5,40 27.- 0 S""75Z4"0 E 54,10 2~2-45 S 76-48 E 46,95 28- 0 $ 75-26 E 46,17 27-30 $ 76-,.30 E 46,17 27-30 S 75-48 E 45.4(} 27- 0 S 75-58 E 46,95 28- 0 S 76-12 E 46,95 28- 0 S 75-46 E 48.10 28-45 S 75-36 E 48,48 29- 0 S 75- ~ E 49,62 29-45 S 74-,36 E 49,62 29-45 S 74-37 E 49,62 29-45 S 72-54 E 48,48 29- 0 S 72- 4 E 48.48 29- 0 S 72- 5 E DATE: 08~25~82 COOR D ]. NATES D-LEG LAl~]~TUDE DEPARTtJRE PER 100 66,91 S 320,10 E ,09 79.26 S 372,77 E 5,78 91,06 S 418,2(} E 4,80 101,84 S 463,10 E ,70 113,17 S 507,87 E ,32 124,18 S 551.91E .51 135,38 S 597,50 E 1.01 146,92 S 643,01 E ,20 158,88 S 689,60 E ,75 171,39 S 736.44 E .37 184,57 S 784.28 E .78 197.74 S 832.12 E .01 212,33 S 879.55 E .85 227.25 S 9?5.67 E .85 242.16 S 971.81 E ,01 AMF / SCIENI'IFIC DRILLING ANCHOR A('..;E OFFICE PAGE J[IB NU~iBE. R: HE AS DEP T 3100, 3300, 3400. 3500. 36O 0, :3700, 3800. ;3900. 4000, 4100. 4200, 430 0, 4400. 4500. 1355 , VER'r, VERT, H DEPTH SECT. 00 2852 O0 2938 00 3025 00 3112 O0 3199 O0 O0 O0 O0 O0 3285 3371 3458 3545 3638 .07 1(148,74 .89 1098,34 ,71 1147,94 ,55 1197,54 .13 1847,51 00 O0 00 O0 O0 .73 1297,46 .97 1348,05 .57 1397,93 ,39 1447.38 .85 1495.70 3721,96 3811,83 3901,90 3991.78 4082,4? 1541,06 1584,82 1688,15 1671.85 1714,02 INRUN SURVEY BY THE TANGI-~N'I':~:AI.,, METHOD COUR S~- I NC DEV, D M 48.48 29- 0 49, 49, 49. 5(I. S , 62 2?-45 S 71-20 e 62 29-45 S 71-22 E O0 30- 0 S 71-24 E DATE: 0 8185/82 257,58 S 1017,77 E ,31 2?3.30 S 1064,84 E .75 289,18 S 1111,85 E .10 305,04 S 1158,87 E ,01 320.99 S 1206.26 E ,25 50,00 30- 0 S 70-37 E 50,63 30-25 S 70-4? E 50.00 30- 0 S 69-11 E 49,62 29-45 S 68-26 E 48.48 29- 0 S 68-30 E 337,58 S 1253,49 E 354.22 S 1301,24 E 371.99 S 1347.97 E 390.24 S 1394.12 E ,45 408.01 S 1439,23 E .75 45, 43, 43. 43. 42. 40 27- 0 S 75-36 E 84 26- 0 S 76-37 E 44 25-45 S 77-13 E 84 26- 0 S 77-43 E 26 25- 0 S 76-55 E 419,30 S 1483,20 E 3,89 429.45 S 1525,84 E 1.10 439.06 S 1568.21E 448.39 S 1611.04 E 457.96 S 1652,21E 1.06 : :COOR D ] NATES D-LEG :LATITUDE DEPARTURE PER 100 AMF / SCIENTIFIC DRILLING ANCHORAGE (]FF']. C:E PAGE 4 NUMBER: 1355 DATE: 08/25/88 INRUN ,:,t JR VEY BY ME DE 460 470 480 490 500 AS, VI.:'R 1, VER T, P l'H D E P l'H S E C'1[', 0,0 O. 0 O. 0 O, 0 I1. O 0 4172,29 1757.76 0 4861,59 1808,73 0 4350,69 1848.04 0 4439.79 1893.42 0 4528,29 1939,95 THE TANGENtS!AL. METHOD OURSE :[NC: ~ COORD DEV, D M LAI'I'rUDE 43,84 86- 0 S 77- 7 E 467,73 45.01 88-45 S 75-31::'E 478,~8 S 45.40 87- ~ S 76-35 E 48~,51 S 45,40 87- ~ S 74-57 E 501,30 S 46.56 27-45 S 75-10 E 51~.82 S NA'rEs D-LEG DEPARTIJRE PER 100 1894.94 El 1,00 1738,59 E 1,03 1788,69 E ,54 1828,53 E .74 1871,54 E ,78 510(}. 0 5200.0 5300,0 5350.0 0 4617.06 1985.97 0 4705,36 2038,90 0 4793,85 2079,83 0 4837,80 8103,30 46.05 27-85 S 75-18 E 584.91 S 46,95 28- 0 S 74-50 E 537.20 S 46,95 28- 8 S 74-31E 549.73 S 23.47 28- 0 S 74-81E 558.06 S 1916,07 E 1981,39 E 2008.83 E .15 8029.23 E ,15 THE; 5350,00 HORIZONTAL D]SPLACEMENT AT THE DEPTH OF FEET EQUALS 2104.04 FEET AT S 74-41 E, AHF / SC]'ENTIFIC DRILLING ANCHOR A[.;E OFFICE GYROSCOPIC D:I, RECTIONAI_ SURVEY FOR ~UNION OIL. OF CALIi::',* JOB NUMBER: 1~55 WE'L I_ NAME: KTJ11-8 L OCA'I :1 ON: KENA1 (;AS FIELD SUI(VEY DA'! E.: 08/85/88 SLIRVEY ENC,] NEER: BARRY S. WALTER MA[.;NETIC DILCLINATION: AT ,00 E GYRO REFERE, NCE BEAR]N(;: N 65-45 W t. iE'TH(:,II) (:IF' CALCI. JI. AT].ON: '[HE AN(;I_E-AVERA(;ED HE'THOI) VE R1 ICAL SECI"J ON: CALCUI_A1ED USING PROPOSAL OF' S 73- ~ E DEPTH 0 IS RKB ELEVATION ABOVE SEA LEVEL THANE YOU THIS SURVEY IS CORRECT TO THE BEST OF MY *KNOyL~EDGE AND IS SUPPORTED BY ACTUAL FI. ELD DATA.* * C~PANY RE'PRESENTAT] VE' AMF / SCIENI'IFIC DRILLING ANCHOR AGE OFFICE PAGE 1 J()B NUHBER: MI! AS, VFRT' , VERT, DEP'I H I)EPTH SECT, '! O0 , O0 ~ O0 , O0 -.', 41 ~00 , O0 200 , O0 -1 , 24 300 , O0 27~, ~ -B, 51 400 , O0 ~99,9'7 -4.25 500 , O0 499.88 -4,9~ 600. O0 599,59 2.04 700 , O0 699,06, 11 ,89 800 . O0 797.96 26,47 900 . O0 896,, 12 45,38 O0 O, O0 993 , 3& 68,60 100,00 1089,77 95,21 200.00 1185,10 125.20 300,00 1277.15 164,19 400.(10 1366,25 209.51 500.00 1455.35 254.86 DATE: 08/25/82 1NRIlN SURVEY BY THE " ~"' ' ~' AN(~I_E-AVE!R~AGI=D METHOD COUR SE DEV. ,44 ,87 1,31 1,75 4,36, INC D M , , 0-30 W 0-'30 N89-;~a W 1- 0 N 86-58 W 1- ON64-TW 4- 0 N 7?-55 E (~OOR b i NATES LAT1TUDE DEPARTUR D-LEG E PER 1 O0 .01 S .44 W ,50 .03 S 1.31 W ,02 ,01 N 2,62 W ,50 .44 N 4,31 W ,40 4.76 N 3,71 W 4.85 ! 10. 14, 17. 23, 63 4-45 N 85-54 E 24 7- 0 S 84- 7 E 78 10- O S 81- 7 E 08 12- 0 S 80- 8 E 34 15- 0 S 78-15 E 5,71 N 3,86 E .88 5.54 N 14,10 E 8.46 3,64 N 28,76 E 3.03 ,54 N 47.58 E 2,01 3.84 S 70,51 E 3.03 30. 45. 45. 72 l&- 0 S 78-26 E 07 19- 0 S 76-42 E 07 27- 0 S 76-53 E 40 27- 0 S 76,-11 E 40 27- 0 S 75-2~ E 9.84 S 96,68 E 15.72 S I26.05 E 24.65 S 164.09 E 35,22 S 208.24 E 46.33 S 252.26 E I .00 3.04 8.00 AMF / SCIENTIF'IC DRII_I. ING ANCHORAGE OFF].CE PAGE 2 ME AS, VERI', VERI', DEP'IH I)E,P'FH SEC'r, 1600.00 1544,45 300,22 1700,00 1&:31,16 349,96 1800,00 1717.43 400,45 1900.00 1805,93 446,96 2000.00 1894.63 493,07 INRUN StJRVEY BY DATE: 08125/82 THE' ANGLE.-AVEE!AGED METHOD COUR SE, 1 NC DEV, b M 45,40 27- 0 S E 49,81 32-45 S 50,57 28- 0 S 75-86 E 46,56 27-:30 S 76-30 E 46,17 27-30 S 75-48 E 2100,00 1983,53 538.81 45,79 27- 0 S 75-58 E 2200,00 2072,24 584.92 46,17 28- 0 S 76-12 E 2300.00 2160.53 631,81 46,95 28- 0 S 75-46 E 2400,00 ?248.52 679,29 47.52 28-45 S 75-36 E 2500.00 2336.08 727.54 48,29 29- 0 S 75- 3 E C[tOR D 1 NATES D-LEG LATITUI3E DEPARTURE PER 100 2600.00 2423,23 776.58 2700.00 2510.05 826.18 2800.00 8596.87 875,80 2900,00 8684,01 924.85 3000,00 2771,47 973.32 57,64 S 296,23 E 69.49 S 344,61 E 5,78 81,68 S 393,70 E 4,80 98,91S 438,87 E ,70 103,97 S 483,70 E 115,13 S 528,10 E .51 186,24 S 572,92 E 1,01 137.61S 618,47 E ,20 149,36 S 664,58 E ,75 161.59 S 711,24 E .37 49,05 29-45 S 74-36 E 49,62 29-45 S 74-37 E 49,68 89-45 S 72-54 E 49,05 ;~9- 0 S 72- 4 E 48.48 29- 0 S 7;~- 5 E 174,44 S 758,58 E ,78 187.61S 806,48 E .01 201,49 S 854,06 E ,85 216.25 S 900.84 E .85 231.17 S 946.97 E ,01 AMF / SCIENTIFIC DRILLING ANCHORAGE OFFICE PAGE 3 tLtb* NUi'.;BE. IR: fie AE:, VE R'I' I)E'PTH DEPT 31 O0.00 2858. 3200, O0 P946, 3[~00, 00 ~(J37, 340(), ~0 3'119, 3500, O0 3206. 3600.00 3293, 3700.00 3379. 3800.00 5465, 3V00,00 3552. 4000.00 3639, 1355 INRUN SURVEY BY THE ANGL. E-AVE~AGED METHOD DATE: 08125182 . VER1 . COURSE INC H S E C'I" , D E'. V, D M . , S E 93 1021 79 48.48 08 1070,82 49,05 29-45 S 90 1180,48 49.62 ;29-45 S 71-80 E 71 1170,08 49,62 29-45 S 71-22 E 43 121~.80 4~.81 30- 0 S 71-24 E 03 1869.77 50.00 30- 0 S 70-37 E 45 1380.04 50,31 30-25 S 70-49 E 87 1370.28 50,31 30- 0 S 69-11 E 58 1419,94 49.81 29-45 S 68-26 E 72 1468.83 49.05 29- 0 S 68-30 E 4100,00 3728.07 1515,77 46.95 27- (! S 75-36 E 4P00.00 3817.51 1560.i~3 44.68 26- 0 S 76-37 E 4300,00 3907,49 1603,88 43.64 25-45 S 77-13 E 4400,00 3997,46 1647,40 43,64 86- 0 S 77-43 E 4500.00 4087.72 1690,33 43,05 25- O S 76-55 E COOR D ] NATES I-AT] TUI)E DEPAR'rIJRE 246,34 S 993,02 E 261,90 S 1039,53 E 277,70 S 1086,57 E 293.57 S 1133.59 E 309.48 S 1180,79 E D-LEG PER 1 O0 ,75 ,10 ,01 ,25 325,75 S 1228,07 E 342,36 S 1275,56 E 359,58 S 1322,84 E 377,59 S 1369,28 E 395.60 S 1414.91 E ,92 .75 410.06 S 1459,57 E 420.78 S 1502.88 E 430.66 S 1545.39 E 440.13 S 1587,99 E 449.59 S 1629,99 E 3,89 1 .10 1.06 AMF / SCIENI'IFiC DRILLING ANCHORAGE OFFICE NUMBER: ME Ac.;. VE, R DE. PTH DEP 4600 . 00 4177 4700. O0 4267 4800. O0 4356 4900, O0 4445 500(!. O0 4534 510 (!. O0 4623 5200.00 4711 5300, O0 4800 5350 , O0 4844 1355 DATE: (! 8/25/82. INRIJN $1JRVEY BY '1', VE.R T, 1 H SE(~l', THE AN(;;I_E-AVEI~GED METHOD COURSE INC C(30RI)] DEV, I) M LATITUDE NATES D-LEG DEP AR'FUR E P ER 100 .98 1733.89 43.05 26- 0 S 77- 7 E 457.26 S .57 1777,64 44,42 26-45 S 75-31. E 467,76 S .77 1822,79 45,20 87- 0 S 76-35 E 480.66 S ,87 1868,14 45,40 27- 0 S 74-57 E 491.82 S ,67 1914.10 45.98 87-45 S 75-10 E 503.67 S 1671,94 E 1.00 1715,11 E 1,03 1758,98 E .54 1802,99 E ,74 1847,41E .76 ,30 1960,37 46,30 27-25 S 75-18 E 515,48 S .84 2006,84 46,50 28- 0 S 74-50 E 527,46 S ,13 2053.77 46,95 28- 0 S 74-31E 539,87 S .88 2077.24 23.47 28- 0 S 74-81 E 546,17 S 1892.19 E 1937,11E ,62 1982.37 E .15 2005,00 E ,15 THE HOR].ZONTAL DISPLACEMENT AT THE DEPTH OF 5350.00 FEET EQUALS 2078.06 FEET AT S 74-46 E, AMF: / c"'" · ..~, L, ]'. E N T I F' i C D R ! L. L I N G ANCHORAGE OFF].CE GYROSCOPIC ~]REC'F]ONAL.SURVIEY FOR *UN]ON OIL OF CALIF',* JOB NUMBER: 1355 WELl_ NAME: KIJ1 1-.8 [ (') C A'I' ] 0 N: SURVEY DATE: SURVEY ENGINEER KENAi GAS FI!E~LD : () 8 / 25 / 8 ~ BARRY S, MAGNE'FIC I)ECI_INATI(]N: AT ,00 E GYRO REFEREN[:IE BEAR1NG: N 85-45 W J. iE'I'HOX) OF CAI_CIJLAT],ON: THE RAD'.IIJS OF CURVATtJRE VER1 ]CAL SECI".I ON: CALCULAI'ED IJSING PROPOSAl~ (IF S 73- 9 E DEPTH () IS RKB ELEVATION ABOVE SEA LEVEL THANK Y[)L! *************************************************** * TH],S SURVF.'Y iS CORRECT TO THE BEST (IF MY *KNOWJo~DGE AND IS__SiJPPORTED BY AC'[UAL F]F.'.LD DATA,*- .x. -X. * , .x. -x.,.x..x..x..x..x., -x. , ' ~g4;l~P A NY RE PRESENTAI'IVE * .x..x..x., .x. ** .x., .x..x..x..x., .x..x..x.,,, .x., .x..x., .x..x.,, .x., .x. ** .x..x..x..x.,, .x- .x..x..x..x.-x. -x., .x. -x. AMF / SCIENTIFIC DRILLING ANCHOR AGE OFF] CE PAGE 3(]B NUHBER: 1355 FiE A,c.:, VERT. VER'I', D I.-';. P 'IH I)E PTH SECI', 100,00 100,00 -',41 200,00 200,00 -1,24 300.00 299.99 -2,51 400,00 397.77 -4,24 500,00 499,86 -4.75 600 , O0 599,57 2,22 700, O0 699,04 12,05 800 , 00 797.93 26,62 900.00 896,09 45,54 1000, O0 993,31 68,75 1100. O0 1089.68 1200 , O0 1185,04 1300,00 1P77, O1 1400, O0 1366,11 1500,00 1455,21 95.36 125.34 164,30 209,62 254,97 INRiJN SURVEY BY THE RAI)]US OFf CiJRVATURE COUR SE INC DEV, I) M 44 0 - 30 ,:,(',~i;8l! W .87 0-30 N 8?-55 W 1,31 1- 0 N 86-58 W 1,75 1- 0 N 64- 7 W 4,36 4- 0 N 79-55 E 7,63 4-45 N 85'-54 E 10,23 7 .... 0 S 84- 7 E 14,78 10.- 0 $ 81- 7 E 19,08 12- 0 S 80- 8 E 23.34 15- 0 S 78-.15 E DATE: 08/25/82 COOR ID ], NAT El S LAlllUDE DEPARI'UR D-LEG E PER 100 26,72 16- 0 S 78-26 E 10,30 $ 96.52 E 1,00 30,07 19- 0 S 76.-42 E 16,77 S 125,88 E 3,04 39.04 27- 0 S 76.-5,'5.E 25,69 S '163.89 E 8,00 45,40 27- 0 S 76-11 E 36,26 S 208,04 E . 45,40 27-' 0 S 75-29 E 47,37 S 252.06 E 4,65 N 3,72 El ,88 4,49 N 13,95 E 2.46 2,59 N 28,60 E 3,05 ,52 S 47,43 E 2,01 4,90 S 70.35 IE 3.03 . O1 S .44 W .50 .03 S 1,31 W ,02 .01 N 2.62 W .50 .44 N 4,30 W .40 ~,71 N ,3,84 W 4.85 AMF / SCIENTIFIC DRILLING ANCHORAGE OFF]C£ PAGE 2 3lib NUHBER: HI AS, VERT, D[ P]H DEPTH 1600, O0 1544 1700,00 1630.99 1800,00 1717, 1900. O0 1805.74 2000 , O0 1894 21 (10 , 0(! 1983,34 2PO0.00 2072,04 2~?,00, O0 2160,33 ;7400,0 0 2248,32 250 O, O0 2335.89 2600, O0 2423,03 2700,00 2509,8,~? 2800, O0 2596,87 2900,00 2683,8'1 3000. O0 2771 , 27 1355 INRUN SLJRVEY BY THE RAD]LIS ('~:i CURVA'I"URE DATE: 08125/82 VE R T. (]OUR SE 1 NC RING 300.3 27-0 s': 350.04 4~.79 32-45 S 76-48 E 400.53 50.55 28- 0 S 75-26 E 447.03 46,56 87-30 S 76-30 E 493,1~ 46,17 27-30 S 75-48 E COOR D ], NAT E S LAT]'[IJDE DEPARTIJR D-LEG E PER 100 58,68 S 296.02 E .09 70,55 S 344,38 E 5,78 82.65 S 393,48 E 4.80 93,94 S 438,83 E ,70 105,00 S 483,46 E ,32 538,87 45,79 27- 0 S 75-58 E 116,16 S 584,98 48,17 28- 0 S 76-12 E 127,27 S 631,87 46.95 28- 0 S 75-46 IE 138,64 S 879,35 47,52 28-45 S 75-38 E 150.39 S 727,61 48.29 29- 0 S 75- 3 E 182,63 S 778,84 49,05 29-45 S 74-36 E 175.47 S 826,28 49.82 29-45 S 74-37 E 188,65 S 875.90 49.62 29-45 S 72-54 E 202,53 S 924,94 49.(15 29- 0 S 7?- 4 E 217,29 S 973,40 48,48 29- 0 S 72- 5 E 232,20 S 587,86 E .51 572.68 E 1,01 618,23 E ,20 884,27 E .75 710,99 E 758,33 E ,78 808,21 E .01 853,84 E .85 900.62 E .85 946.74 E .01 AMF / SCIENTIFIC DRILLING ANCHORALiE OFFICE PAGE 3 3[mI.: NUFiBER: 1355 FiE AS, UERI. VER'T, DE P TH PEP lH SE Cl'. 3100.00 3200. O0 3300,00 3400.00 350 (!, 00 3600,00 3700. O0 3800.00 3900. O0 4000,00 4100.00 4200,00 4300. O0 4400.00 4500, O0 2(358,73 1021. (.37 2?45,88 1070,87 3032,70 1120.48 3117,52 1170,11 3206,23 1219,88 3~92.83 1269,85 3379.25 1320,13 346,5,67 1370.36 :~552.38 14;~0 , 03 3639,52 1468,9;~ 3727,81 1515,83 3817,31 1560.39 3~07,28 1603,93 3997.26 1647.45 4087,51 1690,39 INRUN SURVEY BY THE RADIUS 0~,?. CURVATURE COURSE ]NC I)EV. I~ M 48.48 2?- 0 ~J 7'1 E 4?. 05 2?-4,5 S 71-38,E 47.68 29-45 S 71-~0 E 49,62 89-45 S 71-88 E 47,81 30- 0 S 71-24 E 50.00 30- 0 S 70-37 E 50.31 30-25 S 70-4? E- 50.31 30- O S 69-11 E 49.81 2?-45 S 68-~6 E 49.05 29-' 0 S 68-30 E 46,94 27- 0 S 75-36 E 44.62 26- 0 S 76-37 E 43.64 85-45 S 77-13 E 4~.64 26- 0 S 77-'4~ E 43,05 25- 0 S 76-55 E DATE: 08125/82 COORDINATES LAT].TUDE DEPARI'URE D-LEG PER 100 326.79 S 1227.84 E 343.41 S 1275.34 E .43 360.62 S 1322.61 E .92 378.63 S 1367.05 E .45 3?6.64 S 1414.68 E .75 411.10 S 1459.38 E 3.89 421.81 S 1502.63 E 1.10 431.69 S 1545.14 E 441.17 S 1587.74 E 450.62 S 168~.74 E 1.06 247.37 S 9?2,7(3 E ,31 262.73 S 1039,29 E .75 278.73 S 1086.33 E .10 294.62 S 1133,37 E .01 310,52 S 1180.56 E: ,25 AMF / SCIENTIFIC DRILLING ANCHOR AGE OFF1CE PAGE 4 EiB NtJHBER: I'ili ~E;, VERT. I)1!' P TH DEP'IH 4/.'., 00, O (!4177.77 4700. O0 4867. ,36 4800. O0 4356.56 4900. O0 4445.66 ,5 (! 00.00 4534,46 5100.00 4623,10 52(10.00 4711.63 5300.00 4799.92 5350,00 4844,07 1355 DATE: (18125/82 INRUN StJRVEY BY VER T, COIJRSE 3, NC COOR I) SECT, DEV, I) M t..AT1TUDE 1NATES D-LEG DEPARTURE PER 100 1733,34 43,05 26- 0 ,3: ~ E 460,29 1777,69 44,42 26-'45 S 75-31:-E 470,8(I 1878,84 45,20 27-' (! S 76-35 E 481.69 1868,17 45,48 27- 0 S 74-57 E 492,85 1714,14 45,78 27-45 S 75.-1(1 E 504,70 1671,69 E 1,00 1714,89 El 1,03 1758,72 E ,54 1802,72 E ,74 1847,15 E .76 1960.42 46,30 27-.25 S 75-18 E 516,51 2006,89 46.50 28- 0 S 74-50 E 528,5(! 2053,82 46,95 28- 0 S 74-'31 E 540,?1 2(177.28 23,47 28- (! S 74-21 E 547.21 S 1891,92 E ,34 S 1936.84 E S 1982.12 E .15 S 2004,73 E THE HOR]ZONTAL DISPLACEMENT AT THE DEPTH OF 535(I,80 FEET EQiJALS 2078,08 FEET A'[ S 74-44 E. Suggested form to be inserted in each "Active" we~l folder'to check for timely compliance with our regulations. -'' We l~Name and NUmber Op~.~tor, ' ~1 Reports and Materials to be received by: Date Required Date Received Remarks ~_~C°mpleti°n~,. Report. Yes ~--c~/--.. ~ ~ ~/' Well History '-"- /~--~ Yes ..... _.<~ / . ' ~., "~.....~ Mud, Log .-~/~"-- P I , .... · Core Chips ,/¢/~/~* Core Description ,/¢/d ~ Inclination Survey /~ , . DirectionalSurvey Y~,S- PI / Drill Stem Test Reports ~/~.~/ Production Test Reports y ~,~- ~ _~./_~ Logs Run. Yes STATE OF ALASKA ALASKA ~ND GAS N WORI vE" OPERATION MONTHLY REPORT DRILL¢ONsERvATIONG AND ilSSlON 1. Drilling well [] Workover operation [] ...... 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 82-97 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20357 4. Location of Well 9. Unit or Lease Name at surface KENAI UNIT 10. Well No. 374'S & 4266'E of NW corner, Sec. 7, T4N, RllW, SM. KU Ifll-8 11 ~ Field and Pool 5. ElevatiOnpadin feet66I(indicateMSL KB, DF, etc.) I 6. Lease DesignationA_028142 and Serial No. Sterlingl~ENAI GASpoolFIELD For the Month of AUGUST ,19 82 .12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ~ O0:O1 hrs 8/11/82 Spud well w/ 17 1/2' ~ 20:15 hrs 8/13/82 Released rig ~ 19:00 hfs 9/1/82 5364' TD 5273' ETD (FC) 13. Casing or liner run and quantities of cement, results of pressure tests Drove 20" 94¢f csg to 132' Ran 13 3/8" 61¢f K-55 butt csg to 2000' w/ 1275 sxs cl "G" - tested to 3000 psi -~ok Ran 9 5/8" 47¢f N-80 butt csg to 5362' w/ 1500 sxs cl 'G" - tested to 2500 psi - ok 14. Coring resume and brief description None 15. Logs run and depth where run DIL-SP-GR-BHC-Sonic f/ 5368-2000' CNL-FDC-GR f/ 5368-2000' CBL-VDL-GR-CCL f/ 5273-0' 16. DSTdata, perforating data, shows of H2S, miscellaneousdataperfed4467-45221 MD 8 HPF J~~VED, 4395-4425' " " 4337-4353'" " SEP 1 5 982 4225-4274' " " Comrntss 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '-~" ' ' NOT port on this fc 'm is required for ea~,, ~,lendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and'Gas Conservation ;ommission by the~.th of the succeeding month, unless otherwise directed. c~.~ ~n_~n~ / ~/~/~ Submit in duolicate · June 17, 1982 Mr. Eenin A. Tablet Landman Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Re I Kenai Unit KU #11-8, A-028142 Union Oil Company of Alaska Permit };o. 82-97~ Sur. Loc. 388'$ & 4260'E of 5~ Corner, Section 7, T4N, RllW, SM. Btmh°le Loc. 900'S & 1124'E of NW Corner, Section 8, T4N, RllW, SM. Dear Mr. Tabler~ ~nclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A continuous directional survey is req~red as per 20 AAC 25o050(b)(5). If available, a tape containing the digitlled log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in' Alaska and their drainage systems have been classified as important for the spawning or m~gration of anadromous fish. Operations in these areas are subject to AS 16.05. 878 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by .the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing opurations you may be contacted by a representative of the Department of F~vironmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. ~r. ~vin A. Tablet F~nai Unit, EU #11-$, A-028142 To aid us in scheduling field work, ~ would appreciate your noti~ying this office within 48 hours after the well is He ~ul~ also like to ~ notified so that a representative of ~ffor~ the ~ondu~or shoe is dr~lled and also to witness testing of blo~ut pre~nter e~ip~nt ~fore ~rface casing shoe drilled. office adequate advance notification so that we ~ay have Very truly yours, C. V. Chatterton Chai r~an of ~aska Oil and Gas Conservation Co~mission ~nclo~ur~ cc~ ~par~ment of Fish & ~ame, ~abitat Section w/o encl. Departn~nt of £nViro~nta! Conservation w/o encl. CrC/g lh Union Oil and Gas ~"'~son: Western Region Union Oil Company of California P.O, Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager .June 16, 1982 Mr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99504 KENAI SOLDOTNAAREA State of Alaska Kenai Gas Field Kenai Unit, KU #11-8, A-028142 (8-86-71-5390-600972) Dear Mr. Chatterton: Enclosed for Your approval are three (3) fully executed copies of the above captioned Permit to Drill KU#11-8 in the Kenai Gas Field. Also enclosed is our Check No. 19203 in the amount of $100.00 to cover filing fees. Very truly yours, Landman bde Enclosures cc: J. R. Callender Ann Lannin/LA Office JUN 1 6 1982 Oil & Gao, C~ns. C~, STATE OF ALASKA ALASKA L,,,. AND GAS CONSERVATION CO,.,,~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator JNION 0IL COHPANY OF CALIFORNIA 3. Address ~0 BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface 9. Unit or lease name +380'S & +4260'E of NW Corner, Section 7, T4N, RllW, SM. KENAI UNIT At top of proposed producing interval 10. Well number +775'~ & +610'E of .NW corner, Section 8, T4N, RllW, SM. KU ¢f11-8 At total depth 11. Field and pool +900'S & +l124'E of NW corner, Section 8, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. KENAI GAS FIELD KB +--90' MSL I A-028142 STERLING ROOL 12. Bond information (see 20 AAC 25.025) National Fire Insurance Company of Type Statewide surety and/or number Hartford (B5534278) Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed South 6 miles 4200 feet well 900 feet 16. Proposed depth (MD & TVD) 5700' HD & 5260' TVD feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 31°l (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 6/15/82 ~ psig@ . Surface _~~_psig@ ~ft. mD (TVD) SIZE Casing 20 13 3/8 9 5/8 Weight 9Mt 61~t 47~t Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH Grade MD TOP TVD MD BOTTOM TVD Surf I ___ +100I, +100 Surf ~ -- ' - i --- +_20001 H-40 K-55 N-80 Describe proposed program: Coupling Length Plain 100' Butt.12000' IButt-15700' Surf ' --- I Hole 17 1/2 12 1/4 22. +57001+5260 I QUANTITY OF CEMENT (include stage data) Driven +llO0 sxs to surface ~1500 sxs inside 13 3/8" casing 1. Move in and rig up. 2. Drive 20" to refusal ~ +100' & install diverter. 3. Directionally drill 17 1/2" hole to +_2000'. 4. Run & cmt 13 3/8" csg to +2000'. 5. Install & test BORE to 3000 psi 6. Directionally drill 12 1/4" hole to +--5700' TD. 7. Run logs. 8. Run and cement 9 5/8" csg to +5700' TD. 9. Test and complete well as dual 3 1/2" gas producer. RECEIVED JUN 1 6 ] ' 982 Alaska 0il & Gas Cons, Commission Anchorage 23. ' hereby certl~e f r~oing is~and ~rrect to ~ beverly knowledge The space below for Commission use / %~ Samples required I--lYES ~NO Permit number APPROVED BY CONDITIONS OF APPROVAL I [~.YES []NO DATE ~/~/~,~,~ Mud log required Directional Survey required APl number [--]YES ~NO 50-- /"~,.~- Z0~.~6~'7 Approval date /'9./_ /, ,.., i., ~ 'y~] SEE COVER LETTER FOR OTHER REQUIREMENTS ~ t / / by order of the Commission / '/ Eorm 10~,01 Submit in triplicate i ii i · i iii i / ... iiii T RE£EIVED JUN ~ 5 ~982 Oi~ & Bas Cons. Commission Anc.horags O~AWN ~J~' CKD. ~ ~- m, .o CHECK V.~L V£ \. · o 5000 e~',- .* · o I } ~ HYDr?IL' , , . So'oo ' e$~ .. · o ,' o. · · '~ ' · ?/,oE · 20" ~.ooo e~'~ ~ ~S/b# 5000 ' C~ ~'~C~ ~oo~. Zooo es'~ ~OT~ ' ALL CHANGES hlUST HAVK WRIT.TEN ORILLING SUP~RIrITENDCNT · . VALVE "' :i ' ~. i.": ' ' · '" :~'"': '. ~ECU/RED' . ". '.' ' : ~ .' · · · .4/(G£ EO . ?//-L I7° L/I~ · RECEIVED JUN 1 6 iB82 j O~ TE V~f L VE · A!~ska 0il & Gas Cons. Commission Anchora~ie · ' f/RE , 20" Zooo ~,,i~ ~, i~,S/~,- ~ooo ·s'c I~OTE: ALL. CHA,~II~ES NUST HAVE WRIT..T~N APPRCVSL BY THE DISTRICT ORILLING SUPERI~TENO[NT RECEIVED JUN 1 6 1982 Oil & Gas Cons. Commissi~ SCALE ., Oh/JON OIL COMPANY O;'-CALIF-.ORNIA · SHE..k~$ j ~ECI' XI~V~ LE~C,~,H D~SCRIPTION ',WIGHT ~NSION ~4 ~F ~/~ -to~ o~ 's~~ ~ttom ~P Wt. Grade Thread W/O ~ section TEh~ION lbs lbs 1~0 lbs · o COLLAPSE COLLAPSE CDF PRESS. ~ RESIST. bottom tension psi psi BUPST !I;T£Hi~ PR~SUaE YIELD psi. psi_ BDF PP2~ 0 m Y=Ten$ile Load/Pipe Yield Strength ¢0 .2 .1.: ,6 .8 1.0 'i':..F;::'::::~:'.::-i:;:' :.:.; :::4I'.E~ i::: :.:-':,' :;::i;.::IF.-:':I':[':'I,';:~|i::;I::i:V~".'~,I · ..,..- {.~ .... · ...... {*.l ',' .... ~' 91 .......... ,..1:::':~:::' ~.-..._.~.---I..~'/~ " ........ ! ........... ,.., .... ~, ....... { i' ' .... ~''"~ ' ..... ';a' "'=t''"'° '~" ~"' ' '~!°' ~ ........... .... ~__~'~!~...~.j/.~.~i.ll..' 1 ....... I.,~: .',.-|~,o, · .'-' , .......... ~, ............. { . .,,, 1~ .............. ~'.'2':;.::r:.': <."'1'. ~(722~.%S;:2~ ,.:::~::.:,::.::U.::.}..: ....... ~ I ....~ ...... !' '~, .... °"°'~ ' ','~"i~ :::::::::::::::::::::::::::: :':.,.:Ii|- :!J .... ~'" ....... ! e ...... . ..... J · ,i 'l. o0-:l-' I .r.. '_'", .... } ........ t ....-"l.J.~.' ":~ -' {' ', ....... {"t' '2';: .;: ;;;: ;:;; ..4.:.: ;.' ;...::: :. :.-.1 ::: :,::,', I:: ! :/.'r~l r.,,.li, .il ~..; ...... ~ ~... ~... ! .~/_,.:.:.~. ~ ..... ~...- -,---:-':'- ~ .... ~.' :-----~' "':. (:I;'; :"'"""T. i,' :.:" ;:,::: I' · :.:-,.=: ..-:_,.,. ,, ~ ..... . :i.f:l~'t~': .,. ,~.. ~:.:.:+~.-::.I.., .... ~1,., ....... I..,..,,...I,..! .... ! .~ ...... ... ...11.,~ I~''''~ ' *'~1~ ..... 2..I.' ....... |, ,1, ...L,,,.., I., .... ..... I. Formulae: ' Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = ~mP +.Depth ( Hy4. ~r. II --.5) ~F (~ouyanc7 F&c'tor) = :..oo- (o.o3.5:~ x ~4ud Wt. 'r) Calculations: Total Cost _9%' .. CASINO AND 'i~JBIl~ DESlOH MUD 4//~ HYD. OR. II p.~i/'£t. , Ds'-. IIcrI~WLL Bottom Wt. DESCRIPTION '.TIGHT TENSION RrrN!MUM %4/ BF -top of 'STRENG~K Grade Thread W/O B.P.~__ section TENSION lbs lbs 1000 lbs TDF 0 ~7oo COLLAPSE COLLAPSE PRESS. @ RESIST. bottom tension psi psi CDF BUP2T II:T£RNAL BDF PRESSURE 1.ff '.',q!-~l/M YIELD psi psi PRiG PER COS2 2%9 : _{~870 ?.3/ Y=Tensile L. oad/Pipe Yield Strength 4. ,~:':.:7:: ..... :::' t::: -.,,.I ...... ~j--._1~.72; ii', I..., ........ I .... I ......... I ..... " '' "1''"'' .......'' ' """ · 't"l "' · ,.,*~.,."' i ' ,.*.1~,.,I cecil ,1 I,.,.:, i,* .............. , I · j ....;-'nit't-';':'.'..':;';~;:.::;;;:: ;::'.t: I:-:;:':'-.I .... ~...~.1.,,: .',.- I,.. .. j. .... . .... . ..... ....' .... ,..-i .... ...i ...... ,. ............ I ...................... /_ r::..'l;~::l · --, t'~' '"~ .'~" .... ~ .-~. ~ , '""J !,~ I .' .... , .....~ · ../_... ..... :: ;:.".. :":::;:::'. :;,:i;::: ;;': .:::1'...;'.:'I;:'/'.'~.' ' · ~x'r..o-w.1 ........ ',':: I....-"~....--r F/M ~ .-7' ! .-..'~I~ ,l:.'::;:;:uz:;':l:'r:l';:'.'::;" :i;:l::..J;il; :'[ · C~;::: ::,:: I::'"",':l':::i:'~i:t:t::::''' .I-".'f;J J" '. .... ' ' "1 ........ : "''" ::-.:::::.-:::::::::::: :::' .:u ::-';J,:;, ::;',:1.,,:, r~.;;;;,.. , .... I'''";;'~'-1~ ;" "1" ';':';l'j" ~ ::.:.':.~': ..;:J.." :: :.1:;~'.. :,.T.J":-,, .'", :.:: ..,,.~..,~...'TT;. ,i.~. ,..., . $.~ -,. :..,, .... ,~. I ..... ..S..,,.I...t.,. · I... .'.,I... ! ..|..: ...1: ,, ...I.. ~ .... '~ '1'" Formulae: ._ Collapse ~esistance in tension X (Collapse pressure ratir4) Burst Pressure ,, ~mP +.D~pth (Nya. Or. II.--.5) BF (Bouyancy Fac'tor) = 1.oo- (o.o~53 x ~lud we. z) Calculations: Total Cost Pc;;d 14~~ X I ; , 2, L, NO 4 . RECE.IVED JUN 1 6 0il & Qa~ Cons. Commission Anchorage T ! ! ! I ! I I · ..... ! ! ! ! ! ! ! ! ! ! I I I ! I I I I ! -- I ! I I I I I ! I I ( l I . I I SITE I I I I i I I I 1 I I I I I I I I I ! I Il ..-- .... · I I ( I I ! I I I I ( I 12 W I I . . · ITU 43 · I. DU ol -F 16 " A!~ka t~il & Gas I CO n S. Anchorage :b~ .... _ .... ~ , · '~' + l ..... IT,, .-.. ......... .l ~ r .... :-~ ..... :~" ' PRODUCTION FACILITIES .... ",,w_._ I I I t ! ! ! ! I 16 I CHECK LIST FOR NEW WELL PERMITS Lease & Well No. //-~ ITESI APPROVE DATE Fee Loc (.2' thru 8) (3) Admin / ~' / ~' -- ~92 thru ~:1'1 ) (4) Casg ~~ ~'g~ ~'2 thru 20) (5) BOPE~i~--~ ~ -/&'~ ' (21 thrJ ]-~ (6) Add: · · 3. 4. 5. 6. .7o 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Company YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ........................... .~ 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 and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... R~MARKS Is conductor string provided ..................................... Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................. Will surface casing protect fresh wa~er zones ................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore .......... eel Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation ,proposed .................. Is a' diverter system required ...................... ..~~_.~ Are necessary diagrams of diverter and BOP equipment';~g~;~ ...... Does BOPE have sufficient pressure rating -Test to psig Does the choke manifold comply w/AP1 RP-53 (Feb.78).- ....... ''''. Additional requirements ............................................. Additional Remarks: Geology: Engineg~ing: rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , Well Hisiory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. PROGRAM=LISTER LEVEL SPACING 0,5000 ................................ ~ ~ ~ ~ ..~- ~ ...... ~,~ ............ ~: . ......................... PAGE UNION OIL OF CALIFORNIA 198q. 22.9 22.9 1~.~ ~ (':~sF:~:;.~,;:~; g:~;;~s~;;; :,' ;;>;,.: ;~ ?(~;' ~;,$~ : F ~ ::;' 1...9.86,~ .20 ,,5 1988, 25,5 1997. 25.7 5 .I_ 1999. 2001. 28.9 2003. 35.0 2005. 2007. 39.8 39.8 1~.1 -76.2 2.i 33,6 .2 8_,,_ n,8 0_1 2009. 37.3 37.~ 15.2 ~.~.~.~7 ~.5 '~ ~_n ~ n_n. 2011. 40.9 qO.9 ' ' " 5 2027. 50.8 50.8 1~-101~9 2~ 2029. ~9.0 ~9.0 PAGE 2 204'7. 42.8 2049. . .2.051. 33.8 2053. 2055. 35.5 · P~_~ .~ ............... ~~ ........ ~-~";"'~ .............. '~'~'",-"~ ................ i'S'~ z - s~ .~ ...... s o s ~.~ .... ~.... ~..~ s.....~ ...................... 2065, 3~.0 3q.O 13.2 -8~. ~ ~ ~-.~ :: .. 2067. 3~.6 3~.6 ~ 3.9~,8 ~.,.~.5...,~ PAGE 35 UNION OIL OF CALIFORNIA DEPTH GR GRi , ~AL . ~SP__. ~ ...... P~ ........... C~.._ ~ ........ rn. RR~ 2081, ~6,7 56,7 1~,~ -78,0 2, i~~ ~9 ~ 5.. · 2085, 34,1 3~.1 15.2 -8~0 ~ 4' ~ ..... ,:;,~';~;' '~' - '~ ~ ~-~3-''F"~ ...... 2095, 56,7 36.7 2097. 355 5 -79 ~ 2 2099 2101. 5~.8 2105, ~1.8 9105. 31 2 2107. 32.3 32.5 13 _1.3 ~io9. 3~.2 .3~.e. 13. ~111. ~9,5 ~9,5 13.2 -82,8 2,~~ 1~.7 12.1 1~.8 1~.5 O_n 2115. 33.5 33.5 13.2 -83,8 2,P 29.~ ~.6.2 1~8.2 12.8 2115, ~5,~ ~5,~ 1~,5 ~12Z, 36.5 ~.~.~ ....... 2i2'7. 35.8 a5~a l~i - 2~ PAGE 21~7, 34 8 21~9. 2151. 32.3 215B. 2155. 2157. 30.7 30.7 12.9 -77.2 ._~!_,_0__L_~8_.~_~~ lZ..9 2159, 33.5 33.5 13.1 -75.4 ...,~,,.. ~ 28._~__~. 2161. 33.~ 33.~ 13.1 -7G.2 2.~ 32.2 39.2 ~, ............. ..,. ;~: ,.: ;~, ; ~: .... :; ~m~'r~'~~m ~.¢~.. ........ :~4 .. .~ ............. 2167, 33.0 33.0 12,9-7&.2 ~~~ ~' 2173. 33,3 33,3 1~,~ -7%.6 2.2 29.0 ~_O~~ 11.~3_2 2Z75. 33,6 33~ PAGE 5 UNION OIL OF-- CALIFORNIA 2181. 31.9 51.9 15.0 -77.9 2183. 32.8 32.8 12.8 -77.~ 2195. 3~.~ 3~,q 13.0 82 1 2197. 33 6 2 2199. 2201. 2203. 2211. 35.8 35.8 12.9 -7~. ~+ 22i3. 33.7 33.7 13.0 -7G.8 2.1 32.7 : :: ~:: .,. ,;,; ;,::: ,;,;; :,,; ,:,::. ;:,,, ,: ~ ;>,~;: ,. .:.,,;~:... .....,..~ 2219. 35.~ 35.~ 12.9 -72.9 .~~ 1~_~ r)_n.~ ~2~. s~. ~ s ~ ......... ~.~..-.~ ................... o....~.e ..... 2225. 34 -7 PAGE 6 UNION :~:'~ 2231. 3~.2 3~.2 13.0 ~233. 32.8 32.8 12.9 ..................................... . .......... ~ ' · 22 .s. 5o.o , ::~:~::~.; ':;r;;::~:'~ ' ;:~~ :~ c~.~:;~.s 22~5. 32.8 32.8 13.0 22~9. 33.2 2251. 31.~ 2253. 35.5 2255. 2257. 32.2 32.2 !2.~ -75.6 2.p 30.3 38.0 2259. 33.~ 33.~ 12.9 r_7 Z~ 8 22~. 29.0 29.0 ~2 2~ ;'~: :':):' ~:~: :::': :'~ :: ; :~~'~2:; :: .~,.:-.:::~'~- ~:~' .: .................. s;~:::)2~'""~,. 2265. ~.6 5~,6 12.9 -7i.9 ........... 2269, 36,9 36,9 12,8 -76~5 ..... 2~ 30 ..... Z PAGE 7 UNION OIL OF CALIFORfJIA .................... 2287. 2291. 55.0 ~5 0 12 29 ~2 5 2 3. 2295, 37,0 37,0 12 9 -~1. 2297 2299. 2301. 2303. 2305. ¢~o~. so.z ~o.z z~.o-~s.~ ~o~. ,~.Y ~,~.7 ~.o-~.5 2_.__~ _~~ .. 2313, 38.0 38.0 12.9 2317, ~0,~ ~0,9 13,2 -6~,0 2,1 31_.,~__ ~~&~ ...................... 2323, ~.~6 3~ 6 PAGE 23~9. 2351. 2353. 2357. 3'~'.'8 37.8' 12.8 -77.g .... 2.~ 30.2 ._~_0__,_3__~~~9j_9 ............................ 2359. 33.9 33.9 Z2.8 -7t.9 2~ 2361. 35.5 35,3 12,8 '75,~ 2~6~. 51.9 ~1.9 12.~ -77.5 2.1 2365, ~.1 3~,1 12.8 -77.8 ~ ~1.8 ...... ~.~..~~~~ ........................... 2569. 39.3 39.3 12. ~ ........ . ,..,.~ ...... : :: .:~:~,~~~?~ :: ~.::.::~:"~~. .......... ¢~%~::.. ................. ~: ........... .:~:~,~:~.:~.:. .................. ~.~<~% ......... .:<~;~j:~:~ ......... <~........:<..~:~?....<<~ 237:. 33.6 ~6 ~2 2~ PAGE UNION OIL OF CALIFORNIA 2381. 35.3 35.;5 1,2.7 -73.3 2.1 32.6 53. _ 238.~. 33. ~ 33.6 12.8 - Z7.8__~~..~.~__~.0_.~~~_ ~ .......... o ..... o ...... ~: ~:~:~ ~ .s ~=,,~,~;~..~ ..,~;- ......... ~. ~ .. ~,~.~,~,~z ......... ¢~,~:~4........ ........................................... 2395. 37,7 37.7 12 2397. ~2.0 0 2 2399. 50.0 2401. 2~03. 35.8 2~05, 2~07o SS. 4 35.~ lc. 9 2411. ~0.5 ~0.5 15,0~-36, ~6,9 129. · - . ~"~ 2~15..~.~ ... _' ~7. 3~,3 3~.~3 ~8 -~~ z~ ~ L.::.:,~_~ ~-'~::: _~._~ ~:8_: PAGE 3.0 F UNION OIL DEPTH GR GR~ C~L SP Ag~ ~-~' C~ I.,..n ~ .. ~5. ~2.8 ~. 2_.44'7 · P~9. 2%51. 2%53. 2%57. 29.0 29.0 3.2.8 2%59. .31.2 51.2 12.6 3 ~5 2~6$. 33.5 ~-~. ~,o 2477. 33.~ 33.q PAGE 2~97 2~99. ~8 9 2501. ~7.2 2503. 53.~ 2505. 2507. ~8.~ ~8.~ 1~.1 ,~ 0.2 z~.7 ~?~? ................... 25o~. ~3.~ ~ ~3.o -~ ~.~ 2511. 40.9 ~0 ...... .~1,5 53. ~.~ .,:.~ 2513. 37.7 37.7 13.1.....:~.~. 6 2.1 31.2~ ~_3 25~'7. ~6.9 ~6.9 13.~ -~9.7 2.P 29.8 ~8. 2521. ~1.0 ~ .... .: :~ :~ ~: ~.. ............. .~.~ ..........~;~. ........ .~ ............. ...~.~ PAGE 12 UNION OIL OF CALIFORNIA ~? :~: _A~._!,:-:,6B.~! ..... :_L_!N . :: : :::t~::.;..::.::~:?:~::.......4~;~:.:~:.~.z~:~:~.~:..~:~.:~2~?s:~:~:~s~?.,~..::..~..~:.~:~.~.~.~:?/:.~:::.:..:~:::~::..:.:~:~2~:;~C~.~:~:~.:.~. 25%5. ~8.0 58.0 1~.2 ~,2 25%7. ~8.~ %8.~ 15.2 -q' 8 2 2551, 2553. 2555. 2557. 2561. ~7.9 ~7.9 13.2 -q.~. 9 2~31 .__6___ ,;..., ,~:.-, ~,.-:;! ::,, : !,~'" , ~?~ ~--"~--'~ ~:7~C 2563. q7.2 ~7.2 13. ~ 1 ..L 2 32 2571. ~5,'+ ~5.~ 13.2 ~7 ~:,~ . ....., .-.~ ,R.575. ~~_~~__? PAGE UNION OIL OF CALIFORNIA ~:.~:~':, L:~:: .................................................................... : ............. ::::::::::::::::::::::: 2583. ~.2 ~.2 13.2-39.3 2. 3~ ~5~. 2~.o 29.o ~2.~ -~7~.~ ~e~- _. ~~ ~ ~ ............................ .0....-_~.~ 2597. ~7.5 ~7.5 zg=Z - 259~, ~7.0 ~7.0 12 8 5~ 6 2 0 2 2603. 2605. ~.2 260 '7 · 2609. 261i. ~1.1 ,1.i i2.7 ~0.5 2.i s3.5 55.6 13!.._8 26i5. ~.~ ~.~ i3.o-~o.~ 2., 32.3 50.7 2617. 55.6 53.6 12.8 -~1.~ 2.0 ~1.7 ~7_.7._ !aS, 1 2619. ~2.9 ~2.9 12.5 -47,8 1.~ ~ 7 _ 2621. 35t3 35.3 12,5 -55.7 ....... 2.,_! ........ ~_~9 ~ :,,;~'t,:: T;: < t;:~:' :: : ::: ::~ ~.'.~...¢.~-:.::~:: ?.~? ......................... ~;:~: ................. .~:.~t~3~::~ ..................... ~:~.:~ ............. 2627, 3,~. 5 ~.3,~,~ .... PAGE UNIO, N~ OF CALIE__Ot.~j_N!.A_ ......................................:_._ ................................................................ ~ ,, DER,TH, ......... GR_ ........ _G_R_~ ............ .C_...A_.L ................. _S..e. ........ ~.EN ..................~~ ~ 2655, 3~,3 2655, 30,0 2657, 30.2 2659. 30,5 2665, 57,5 37,5 12,~ -69,6 2,1 ~ ............ ~8. 11.9 1~.7 la.7 ~_fl 66'6 ' ~ 35' 3 35 ' 12 ~ ~ 2 :~:'~:~':::'~':2~ :~':~'~':~'~:~''~?~ ~'~' '"'""?~ ....... "'~?"~"~'"'"' ''~ ................ ~' 2669. 29.R 2679. 29.3 2~.~ .. PAGE 15 UNION OIL OF CALIFORNIA 2685. 26,,7 26.7 12.4. -70.__2... ........ 2.P ~$~ ........... 4'0.8 155.4. 12.4. ~:!,,;!:~ ~~T~T:";~'T'~'~:~:?~:~77~:'~.~ :!:~ :; · ~ ~ ...................................... ~~:' ::'~L'~, ~:,~ ~ ~;~ ~ ~.~ 'i: :; ~2~:.t,~,~j.~:~,.~,_~j~_~; ""~'" ..................... ~;~ o.o o.o z2 2 2703 2705 2709. 2711. 4.~.7 4.3.7 12.B :4.1..22..1 31.1 4,7.3.~.~__.! ....... jB~_7 _ 2713. 4. .1 4'6.1 12.6 -4~1 2.1 30.5 .8.8 129.0_ _B.~_ 7_~ .~__ .~_ 5~ 1~ ~ 12~%~ ~ ~ ~'~'~ ~ :~:~'~~: '~ .... ~'~'~: .... ' "~ -~ ..... ' ................ "'~ 2715. g6.7 q6.7 12.6-~ 2.i 3~ 52.8 1~4.1 8.8 2717. ~5.7 ~5.7 12.6 ..-~8.8 ~~ 3~ ~ 132.1 8.3 2721. ~5.2 ,5.2 12.~ -66.7 2.1 2723. 37.6 57.6 12.~ -~5.q 2.~2.2 ~3.~27.~ 8.3 2725. ~0~ ~0.9 12.~ -~3.4 2.~ SO.O 50.7 1~.5 7.9 A_A ~_~ n_l .... .~:<. ~ .............,.~.,..~ .~ .......... 2727. ~6, ~ 46, * 1~~~ 2731, ~ ~7 ~ -t~R l~i 1 ' PAGE o75~. 33 7 2755. ~.9 2757. 32.7 275':). ~0.0 30~ 2761. ~0.~ SO.5 i2.q. ?.721.8 2.;i' ~0.6 ~ ' 2765. 31.6 51.6 1.~,5 -70.9 2.1 32.8 ~3. ======================= :~ _:~i :::.::: :.a ::~'.:~ .............................................. . ......... _ .............. < ..................................................... _ .: ....... ............ ............ 2773. 33.9 33.9 12.6 -7~.1 2 3 ~36 ::: ...... ::,.~_ ..... .~?~~.~ ~ ................ ~ .......................... ~:. ~:~:~:~:.~, ~:..~:~, ........ ~:_:::_.::...~.::~: ............ . :::::::::::::::::::::::: 2777. SO.8 30.8 12,6 -72~3 2 ~ 3 ~ :::::::::::::::::::::::::::: 21~:~:g.~_ .......... .~.~-'-6 ............ ~.61,....61 ........... _~.18.:~:.~._::::::::::::::::::::::::::::::::::::::::::::::::: PAGE 17 UNION OIL OF CALIFORNIA ................ .,,,.,~. , .... . , r---~"~------~'"' ~'~ ~r?~?~'~? 7-~-? ~, ~:~ , 2785. ~5.0 ~5.0 12,6 -75.7 2 1 ~787, ~ 2, ~ ~ 2, * . ~ ~, ~-. - Z!, ~ ~t ~.~ a ._,._-..a ................. o.-.i.~ 2797. ~.~_....~6.6 ._~.~_~ -7~ 2799. 35.9 ~5.9 12 6 72 2803. 2805. 33.1 2807. 36.8 2809. 3~ 7 2811. 37.1 37.1 ....... 9.5 ...9_ 2813. 38.6 38.(5 13.0~9.9 ~ ..................... ~B15. ~.2.8 ~2.8 13.0 -3~.7 2.1. ~~~...~ _ _. 2817. ~6.2 ~6.2 12.9 -~0.7 2.0 3_7~}_. 5 ~ ............... ~22. ,a., ,~~~~ ......................... 2825. ~0.9 ~0.9 i 3. O. ~,..;~ ~ 2827. 31.1 31.1 1~ ~s31. 50.6 ~6 l~i -~8~& 2 ~ ~5 - 2833. ~.7 ~.7 13.1-5i 5 ..... ~:~ ..... ~.~ ;,;: : ,,,~: ; ;c.: ~ ~;7~~~;~ ?::;:~':.~;.-~s'~i;~! ................... :~ ..... ~ ................... ~,.~.:~ ~, ............ PAGE !8 UNIgN OIL OF CALIFOR[ilA 2835. 41.5 41,5 1;5.2 - q~ Q~.I 2.1 2837. 46.0 46,0 13.2-38~0 2.1 33.0~~~~6 28q7. ~5.3 q5,3 13.2 -39~ ~. 28~9. ~.9 ~,9 13 i 38 3 2 36 9 2 2853. 48.0 2857. 2859, 2861. 51.0 51,0 13,1 -~4.1 2.1 35.0 50&l 126,0 286;5, ~5.7 ~5.7 i3.2 -~a.9 2 5. .2 qq.2 13.1 53.6 2.~. 33.7 5i.~ ~35 '; ;7: 7'~%~~~%~ ............. 2867, ql.~ 41.4 13.1 -42.6 2,~ ................ ~~ ~ 2869, ql,6 ql,6 13,2 28 ? 1 · ~ 6 . i 46 . 1 15.2~ ~ . 2 . 2.1 ........ 52_._6 ....... 5_0 ,..!~.12_6 ,_1 2877. 40.7 ~0.7 15~ ~~ 5 2 2881. 39.9 ~9.9 13.3-3~.& 2~? ~ ~~' PAGE 19 UNION OIL OF CALIFORNIA ~':?~ ?,:~:~;'~ '" .~' .... '.'7; --':.~- --7 ........... CFTF~"X'; ........ '~- -7''''''T''-~'':~-' "'~'~?' 77~'?~" ~'.~} 2889. ~2.~ 42.4 . ~1.9 ~1',9 13~0 2899. ~2.7 ~2.7 12 8 4~ 8 2 ' 2901. 45.1 4~ 3 2 290~. 51.7 2905. ~1.~ 2¢07. ~3.2 2909. ~1.3 3: 2911, q.q-,8 q. 4,8 12,8 -q. 5,7 2,~i 30.9 50,2 1M1,7 7.5 9 2 i:ii~:, ~ ~?~.~' ~-'~i ~._.:.: ~_.~'~"_~"~_~ ]~.i~ ;;~' ' ....... '~ '~'~:: ...................... ~~ ......... ¢'~ *~ ................ 2915. ~1.2 ,1.2 12~7-54.2 2.1 32.3 ,8~ 1~5.7 2915. ~9.1 ~9,1 12.8 -57~.5 ~7.9 2917, 38,5 38,5 12,8 -65,0 ~~ ~1.2 1~7.1 11.6 12.7 291~, ~5,0 ~5,0 1~,7 -61,5 2,1 ~1~ ~3.1 13~.1 10.2_._ 13...~ 2921. ~3.7 ~3.7 12,~ -67. 2925. ~5.5 ~5,5 12.7 ~71,1 2.1 51.6 ~1.~ 2927. ~0,5 ~0,5 Z2,7 %7t,2 2 2 3 ~ 8 6 2929, 37.7 37.7 ~ -7 2933. 38.1 58,1 12~7 -7 2, PAGE 20 UNION OIL OF CALIFORNIA DEPTH GR GR1 CA~ ,S,P ~& D~ ~, ,C,~ ~,~__.B,.T.,~ M .... R? 2951. 38 2955. 38 5 2955. 2957. q2.q 2960. 29~,~. ,,5., ~5.~ z2...8 ~5~.~ 2966. ~o.a ~o.a z2.6-~9.~ 2968. 39.2 39.2 12.8- ~ 1..,~7 2~ 2972. q2.2 q2.2 Z2.8 -~O.1 ~2 297q. qq.6 qq.6 12.9 -39~8 ............. , ~:~. :~,~ ....... .~: ~ ~. :=~ ~-~~.~-~T~--~: ?~?~: ~.::~;::~? ......... PAGE 21 UNION~L OF CALIFORNIA 3003 2 3005. 3007. 3009. 301~. 3018. ~0.7 ~0.7 12.9 3030. ~6.0 '5032. ~.3 ~2.3 13.0 -~~ 3o3~. ~6.~ ~6.~ _!~~:~ .6 PAGE 22 UNION OIL OF CALIFORNIA ...,.,..,.... ................. ......... ~..~.,.~,~>~., .,c.,,, ..~, . O PTH GR GR~ CA~ SP D ~ 'PDD ~??::~:' ;;;~,;~: · ~ L,.....;,:,.L ............... :~7 '~C''~. ~_.~' ~ ~ o~ 5. s 0,0 s o~ o . ~ ~ .... ~.~. ~ ~.~~~, ~ ................... ~,~.~ .... .............. ~ ........ ~9,~Z~ ~ 05 ~. 3055. 3059 3061. 3063. 50.l 3065, 3067, 49.5 q9.5 15.0 -ql .... ........ ?,.,~,.,.,~ ........... , ,~: : . ,~? ~:~-~~~Z~':~7~s~:.,,..,.,,:,,<: 2;~:' ~8 ~..;;~.8~._~.;~ ~oTs. ~.~ ~.~ ~.~-~.~ 3077. ~9,1 ~9,1 12,9 -37.9 ~ 0.0~ 3o79. ~.9 23~9 ~.o-~s.~ ~ sobs. ~9.7 29.7 ~s.o PAGE UNION OIL OF CALIFORNIA DEPTH GR GR1 CAL .. SP_ Q.E_~_~.~2 .......... .~ ..... ~~. ~ i 3107 2 3109. ~111. 3115. 5115, 3119. %2.8 .2°6 12.8- 55. ~ ~..~.~ 1 52.2 ~z2z, ~,7 ~a,7 z2,B -sg,~ ~.~.~ ~~~~............ ~12~. ~1.2 ~1.2 ~.2..'~7.~ 2.~ ~5._9 3z25. ~.5 ~.5 z~..o ~z~7. .s.z .s.z z3.0 ~7.~ 2..~ ........ D~o ~~ _~. ~._~_.. ...........~ ..-,.: ~.~ : :::~~~~-~:~" ~ ..... ........ ..: ~_~-~.! :_. 3139. 45.2 ~5.2 i3,~_ PAGE UNION O:L~] OF CALIFORNIA,~ .i~i]~.~.~ 31~7, ~7.5 ~7,5 12,9 :: ~.~,~ :~- : ~,~:_~,~:~:~ ~ ::~: :<:~' :: ,: : :: 3155. ~8.1 ~8.1 12 9 3157. 43.1 7 1 2 ~159. 42.5 3161. 41.4 ~16~. 39.8 3165. 3167. :37.7 37.7 12.8 -62.0 2,,1. 3:3.8 ~175. ~5,1 55,1 12,~ ~58.1 .... ~.,1 1~2 1A.i ~5 0.1 ~177, ~8.0 ~8.0 1~,0 -59.8 2.l ~.7 ~.0 1~2.0 ~.& 16.1 1~.7 ::::<:: :,: :::: :: : :: : ~ ::: :: : : ::. : ::.::>.:.: :::::::::::::::: :::::::::::::::::::::::::::::::: ===================== :<..-~'~:~.:?F~:::>::.~:.~.:.FT~-:.~<-.~%:~<%-.:~;:::. ..... PAGE 25 UNION OIL OF CALIFORNIA ~19~. ~2,0 62,0 12,7 -57,~ 2,_.1 ..... ~.~~.~_e _~_ ~~_ ~ .... 5205. ~5.0 ~5.0 12.8 -39.9 2 3207. ~6 7 3209 ~211. 3215. · ~5219. ~8.8 q. 8,8 1~. g.O ._.n 3221. ~9.6 ~9 ~7.7 ..~,-.:~i,~ ':: !~:i~ ~:~:~: . . ..... 'S~ ::~ S S: ...... ~"~' ......................... - .................. -- -- - 522~, 5~,7 5e,7 ~5.2 -~2,~ 2 ~_~ 5225, 50.8 50,8 ~3,~56_,.~__ 2,t .~~~..2....__~ 7.0 ........ ~-~ .... ~_0 0_[._. ............. . ~~ ............. .~.~. ' 5229. 55.6 5~.6 1~.0 -57.0 2.1 ~.2 ~8.5_..~~ %~,,,.~;, ~, ,~ ': ~ ;s ~:~.~r~:~:~~r~:~?~ ~:" ............................... 7 '0 ~7' 0 PAGE 26 UNION OIL OF CALIFO&N!A_ : 5259. 3261. 3263. 50.3 ~265. 326,7. 50.2 50.2 12,,9 =5..,~.8 2.i 30,Y 45.9 117,4 7.9 8.0 c~.4, .0.1 3273. 53.6 53.6 12.9 3279. ~6.2 ~G.2 PAGE 27 UNION OIL OF CALIFORNIA I 3307, 50 5 2 3509° 3311. 3313. 3315. 3319. q.*.'~ ,~.., 12.8 ~5,~ aa21. ,1..~ *1.6 i~.~ ~-~Z~ ~ .s ..... o_~. 3sea. 38.9 s8.9 i2.8 -5~Z~2~~. ~ ~ ._. 3325. ~1.1 ~1.1 12.8 -56.2 33,27. ~. ~ -6~. 5 2. ~ .S.~_.._O ...... ~~~~ 4 ........ 3333. ~2.9 ~2.9 ~2.~ -~.0 2.P 30.3 ~2~ 13. A~ ~L~~~~ 2 2 12 7 5 1 2 ~3 ' ' :,~-~]_..;.~..?..?.:L:.:~1::.8_.*?.L.?~5~ PAGE 28 UNION OIL OF CALIFORNIA 534.1, 4.0,6 40,6 12,7 -40,2 334.3. ~3.8 4.3,8 12.9 39.1 3357, 49.5 3359, 48.6 3561, 47.5 3363, 52 2 3365, 3367, 51.1 51,1 13,0 ~35,4 2,1 31.~+ ~5,6 122.8 7,2 6.0 ~/.0 0.1 3369. 51,9 51,9 12.9 -3g.l~ 48.9 1~1.5 ~ 3371. 51.3 51.3 12.7 -37.~ ........... 2.~ 27.2 ~6.~ ~ ~~.7 3373, 46,8 46,8 12,6 .~37,~ 2,1 ~~ W8.9 118.~ ~ 7_8 ~.~ n_n 33?5, ~9,9 ~9,9 12, ~....-N6,1 8.1 9_& ~n.s n_l 3377, 46,7 ~6,7 12,7 -~1,1~ 2,1 5S..6 ~1.5 1~4 9.8 3379, 48,2 ~8,2 12,6 -~1 ...... ~.~ 31.0 39.3 ~P~.4 8.~ 7.~ q.~ :~'~: ~: ::::::::::::::::::::::::::::::::::::::::::: , , :~ ~ ..... .,,.:: ~ ..~,:~.~r}~::T: :..:,:;:,,,,. .~ .:::.,. ' ....... >:~.,.. ...... .~:;:~s~:~s~ ....... ~..~% ...~.,-: :~ . ..... 3383, 49.7 ,~.7 1~-3S~8~ 2~ .~.~ ~19 ~ .... ' ' 3385. ~ ~ 51. ~ i e ,~ - ~6 e ~ ' ~~ - PAGE UNION OIL OF CALIFORNIA DEP T t..I GR GR 1 . C.~ ..... ~.~ ......... ~.~.. ~ ............. ~ ._. ,,A,~AL~~.5~5:''.,~2~Z~2::~::;72~ "~;_LL':~: .... %~ ',':"~, ................. ' .................................. ~' 3 ~ 03 · ~ 1 , 8 ~ 1 , 8 12 ~ .... 1 ..5..-..P .............. !.~..-2 ............ 3~05, ~0,~ ~0,~ 12,5 -6~ 9 2 3~07. 3~09 3~15. ~17. 36.5 36.5 12.q -6~.2 2.1 31.2 q'1~7 !3.__q-.__.._5~2 1&.5 3q21., 39,9 39,9 12,~-69,7 2,1 31_,~_~ qO 3 132,2 !~1~9.0 0.1 3~23. 39.9 39.9 12.}~ -~9.8 ~1~~.. ~27. ~o.5 ~o.5 ze.a 3~33. 38,7 38.7 ~ ~.~ o.n 3~35. 39.4 3~.q 12.~ ~,.,~ PAGE 30 UNION OIL OF CALIFORNIA :__~L,.i ..L:L : L._:.:....., _::_..,._L...:,.:._.!.::.: :..:~ _.: .L : ..i.. DEPTH GR GRi CAL SP DEN CN __ ~,~__~ ' . ................ :AP1 34~1. ~.5 Q~.5 12.6 3~5, 55,~ 53,q 12,8 -~ .~ 53 ~ 7 I n n _n~n~ i 5~ 1 2 3~59, ~7 8 3~61. ~6.6 3~6~. 53.7 3~65. 3~7i. 45.5 ~5.5 i3.i -3~.3 3~75. ~9.2 69.2 13.0.. ~ : .: -:-:-:~~~ . :~r~:::~::<:: ..... ========================================= ................... .~:::~:.:.:..:...:.:::::..~::::.. ....... ::~:~: .............. ::.::: :.. .......... :.:~ · ~ ~~:~~~: S~81, 55,8 55,8 1~,~ ~85. ,2.1 ~2.1 12.8~. 1 3~89, 49,7 ~9,7 12.8 PAGE UNION OIL OF CALIFORNIA DEPTH G~ GR1 CAL ~P ~491. 4~.0 4~.0 12.B -55.~ 3~93. 50.0 50.0 12.8 -~.0 3505. 37.~ 37.$ 12.7 -57.0 ~509. ~0,6 3511. 42 3513. ;5515 · 35i7. 38.a 38.8 ~'S~"8 ' 39: ~ 59.~~' i~e-;% ::~-~:'?o:::: :~:?~:~:~~ ~:: ~521. ~9.~ 39,~ 12,6 ~. "-9, · '.:: ~: :~~~ :::: ....... ~.>;~.~-?~ 3529. ~+0.2 ~0.2 12. 3531. 35.8 35.8 12.5 -67.2 PAGE UNION ~IL OF _C..A_LIFORNI.A_ ......................................................... . ................. 3553, 37.8 37,8 !~7-~~ 2~ .~~ 3556, 29.6 29.6 12 8 62 7 1 7 57 355S ~560 3562. 356%. 80.2 ~566. %6,0 3568. %6,6 %6,6 15,2 -%0,5 2,~i .8.7. .. 8_.8._ ln..9.. 3572. ~3,7 ~,7 ~.2 -3~.~_,~?.~ 3~.~ ~~~ .~ ~.0 o.~ S~:: :::~~~::~_ :LO_:~: ]::, ~~.~;~_:~~~~~ ........ ~ ......................... t~:;~ ,~:~~': ' ~~~~ :~ ~?~" ~-.~,..., ............. >.~ 3582. ~5.7 ~5.7 z~.~-~7.0 ,~ 5~.9 ~5.~ z29..7 !~ ~..~,&~.:.__..~.:~,~:_~..~_,,L~..:_~ ? ~, :~ :-~,~.6~*~~. PAGE 33 UNION OIL OF CALIFORNIA 359~. ~1.8 ~1.8 13,~ .:~~'~~~C~T~?"~3~T~ ~:~:, ;~:.~ .... :~.:.:~.~ .?..~<.:~:~.. ......:.:~ ........ ~...~ 3604. 4~.0 ~q.o 13.2 -37.5 ~606, 4T.7 ~Y.7 1~.2 -3B.B 2 3610. 3612. 38.9 38' 3621. q. 7.9 ,7.9 1;5.3 .-,3~.5 2,.2..~6,2 ...... ~.Y~3...~123,8 ~,.9_, .................. 5.:.9. .... :'.:.~:~.~>~,~+:..~.:~.~.;~>~>;: : ,~.~!S.~!~:~:::~.~...~ ' ~." '.~ "~:: ~ ~ : '~ ~ ~ ~ : ~ ~~ ~ ~: ~ -'. . .... .-..~'~"~ ~' s:~ ........... ,~ .......... .~.~ 3623. 50.8 50.8 13.2- 3 ~.~,...,.. ~~ 2 3625. ~9.~ ~9.~ 13.3 -31.9 2.~ 29.~ .3 .....7.1 ~.:~ ;: : :~~~~: ~... ............ ~ ~- ......~.:.:~ 3627. ~2.7 ~2.7 13.2 -~G.6 2 ~.2 ~ ............... z~2~. ,o., ~o.4.. ~ ........... 36~1, 37,6 37,6 15, ~...~6.8 2~1 ~0.5 .....~._6_ 122.7 10_.8~_~~ 3637. qq.7_, q~.7 13,2 ~ ....... !0. 36,3. 37.9 37.~ Z3., -3,.8 2.~ ....15~.5. ~ -~ PAGE UNION OIL OF CALIFORNIA 36~5, 3 ,3 39,3 13,5 -3D,1 2,~ 25.6 ..................................... . ................... ~,~,; .... ~;g~:~ ~T3~ : ~ ........... 3663. 29.3 29.~ 13.6 r.3~.~ ............. 2 3665. q6.~ ~6.~ 1~.6 -3~,5 2 ~669, 3671. 3673. 3679. q~.4 ~.q 13.q -,3.6 2.1 32,6 3681. ~1.7 41.7 13.3 -40.2 2.1 32.2 46.8 ~685. ~5,~ ~.~ 9 2.1 5~.9 3693. ~3.0 ~3.0 Z3.7-3~.7 ~.g~~ ~3.6 PAGE 35 UNION OIL OF CALIFORNIA ................. AP I AP i 3719. 3721. ~1.2 3723. 5725. 51.6 ~727. 372~. 3735. 51.2 51.2 13.6 -35.2 .0 ~2.0 37 ~ 7, 5 ~, 3 5 %. 3 1 ~. 6 - 5_~~ ~~.~~~ .... _6... ~7B9, ~6,8 q 5 120.~ 57~9, ~8,5 ~8.3 15.6 -37.,..~ ~~ 28.0 .... PAGE UNION OIL OF CALIFORNIA 3755. ~6.2 ~6.2 13.7 -~ 2~~~ ~ ~ . 3765. ~,7 ~7 1~ - ~ ....... ~ : ' 5769, ~8.9 ~8,9 15.6 -~ 8 2 3771. 44 3 3773, 46.2 ~775. 46.7 3777. 46 1 3779. 3781. 48.2 q-8.2 13.6 -35.6 2.1 ~30.5 ~785. ~.l ,,,~.1 _ 13.,~- ~:::~ : ~ : ~ : ....... ~;~..-,~.,-~ ............... ~, ~:.~ PAGE UNION OIL OF CALIFORNIA ~812, ~5,6 ~5,6 1~,5 -~5 ~1 ~ ~ 50 0 50_~L~ ~818. 51.0 51.0 1~.5 -5~5 2 2 2~ ~ ~ ~ ~ a 3820. q9.7 ~9.7 13,6 -35 I 2 3822. ~8.8 2 ~82q. q8.7 ~826. 50.7 3828. PAGE 5872. 387~ 3878. ~880, 3882 · 38. g 38 . ~ 12.5 -6G · 1 2 . 1 ..... · '-~4-'~"¥; ........ -~'~':i' ................ -~'g-'; i- ............ i'i":¥-"~6'~-'~' ~ 3886, ~8,5 ~8,5 12,~ -67,8 2,1 ~1.9 3888, ~5,2 55,2 ~2,~ -67,2 2.! 3Z~5 , 3892. 5~.0 5q,O 12,~ -66.2 2.2 .... 589~+. 55.0 55.0 12.6 -57.7 _,....,~ PAGE UNION O.I,L OF CALIFORNIA 3922. 392q. 3926. ~6.2 ~928. 39;52. 38.5 58.5 12.8 -62.9 2.~ 29.6 58.7 1,Ki_,2 15,2 ~!~'" ~'~ :__'i:~? ..- .... ~,o. ,7.o ,7,o z~.p-~ ~G.o ..... ~... ~.o ..... o_~.~ 39~q. q2.~ ~2.3 13.5 -36 ~_1 39~6 · ~8.2 ~9~8. 51,2 51,2 ~ ~ 50 '~L,L~O:'~. ~ 1 PAGE 40 3980. 5~.2 54.2 15.2 3982. ~7.8 47.8 1~.0 -~.8 ~986 ~988. 51.1 399~. 25.9 PAGE 41 UNION OIL OF CALIFORNIA DEPTH GR GRi CAL SP DEN D~ C~ ~._J~',~ RII M RT, n r~R= i ~036. ~1.0 13 9 -38 2 2 ~038. qi.8 ~0~0. 51.2 . .............. ~o,+a. 32.,,_ 9~.=~ ..... ~.~ e8.9 ~0.o ie. 7.o_ 7.8 ~ ~OS~. ~S.7~,~S.7 ~.~.e -~.~ e.1 ~3e.~ ~p~s ~~~_ ~062. ~7.7.~.:~..t7 13.7 -37.2 1.R 53.3 48.g 1~5.1 14.7 ~065. 5z.9 52.9 14.0-~7,6 2.2 2~.5 ~ ~~~~~ ::::: .: .......... ~..,.:: ~.:::~::~: :~:::: ........ :.::.. ::::::::::::::::::::::::::::::::::::::::::::::::::::: .: :: : :~:<~ ~?a. .... ~o., 5o.~ l~ -3~ .....2~ ...... ~0~~~ .... ~~~---~~ PAGE UNION OIL OF CALIFORNIA 407q. 55.6 53.6 ~088. q7.9 ~7.9 ~092. ~$.7 qogq. 43.7 ~09&. ~7.2 ~098. q7.5 5,9 PAGE OIL OF CALIFORNIA DEPTH GR GR1 CAL ~P ~2~. ~5~ .... ,5.5 ~2.~ ~2B. ~5.~ ~5,4 ~2.8 ~128. 39.8 39.8 12.8 -39.8 ,.~':c.:~; 4136. 3B.8 3~ ~_~.7 -3B.7 1.A .B 22.0 11 .~ l~_g _n_n ~S9, 17,9 17,9 12,~ -~a ~ 2 4143. 34.9 41'5. 42.5 %1*'7 4149. 45.3 4151,~42o5 %2.5 ~0.0 - 3 9 .~ 4153. 43.3 ~3.3 -0.2 -31.~ 2.~ 32~ ~~ 7.6 ~.~ V.~ n_~ ~155. 44.9 ~.9 -0.1 -32,7 2,1~31.2 %157, ~9.5 %9.5 -0,% -35,5 2~ ~0.9 ~i~..~,:......,.,.,,,~%~,.,~.~,.. ~;::,,:~I,~......~,..!~{:'~?:~.~:..~.L~:....~<..'.~?:~.: F~.~: ~:~'~:~..,.~:~ .':::~.,..i~:~:~;~.~'..%~.L..~'L .~:~'i,~::::~:~i~E~ 4!59~ ~9,~ 3~,...~ -0.7 -~ ......... ~161. ~3.0 43.0 -0.~ -52.1 2.1 53~ ~3.7 1~8.1 12.3 .. lB.5 1~.3 O-O ~ 4167. 40,..,~,....~0.5 0,0 -57,5 2.~_ ~G~D 3~ ~~~~~ 3A-3 0-.0... PAGE 44 UNION DEPTH GR GR1 CAL .~P q. 175, 4.0,0 q-o,o -0,~ -56°6 2,1 35.2 27.7 155.0 26.5 39 ~¥~*'~ ~;-. ........ ~7~ .... ~ ........ ~ ¢-~ ............. ~.* ~ ............ .. ........... ,.~,~; ~ ~;;, ;.~ ~ ~;~ ,~,' <: ;::,~ ~z*~,~.~,~,~ ,~'~: ~ ~.~.~:~.~.. ~179. 39.0 39.0 -0.3 -5 9 2 ~181. ~5.2 ~5.2 -0.2 -5 7 2 ~185, ~0,9 ~0,9 0.0 - 2 2 29.~ 25 0 ................. ~187.~2.8 ~2.8 -0.2 -59.2 2.~ ~.7 3n.q ~l.v ~SD, ~5.5 ~5.5 -0,0 -59 5 2 4.195, ~5,0 ~199. q3 7 PAGE ~5 UNION OIL OF CALIFORNIA i ~2~6. 39,9 -0 ~ 56 ~ 2 42~8. ~250, 39.8 ~252. 36,8 q25~. ~260.~ ~*.8 ~,8~Z0,7 -58,8 2,~ 3~.~ ~3~2 %~8.8 20.6 27.7 31.1 . 0.8 ~262, ~6,1 ~,1 -0,9 -59,9 ......... ~,I ~~ 32~ ~67._8 19.7 27.0 3~.1 ~_~ ~26~. ~3,0 ~3,0 -3,9~60.~ ~~~1 3~.~ ~5.2 20.& 3o.J 3~.$ O.. n._ ~... '....~...~<~ '~ ......... ~- :~' :~:::.': -~::.":,.~:~ .... ::-<.5~::.:~.-..~;<;: :::::::::::::::::::::::: ::': 7::: :::: :~: ~268. 38.9 58,9 58~.7 -61.1 2~2 3~B 28.5 152.2 21.8 :: ....:¢~ .....:.:.~,.:.:.:.::;~~%~ .::.,.::.:;::;~%~::.....:.::-;~'~ ............ :~; ======================= ::~%~ ........ ~;:::'~ ~ , :- PAGE 46 UNION OIL OF CALIFORNIA 0 7 ~0,7 2 ~298 q~O0. 50.1 ~B02. 55.5 q30~. 5 ~20. 55.0 55.0 -0.: r:~9.~ 2,,~ :~2~, 5~,0 5~.0 -0,~ 11~.7 2~: 22.5 38.8 ,~526.~.~. 6 55.6 -0.2 -~m7 2.2 PAGE UNION OIL OF CALIFORNIA DEPTH GR GR~ .... CA~.~ SP DE~gENP C~ ......... ~ ~.O..C~RTI M RTl D rg,~ 4331, 27.6 2~ -0.2 -3 ~ ...........~.~.~ ~'"'~ ~....,.~ ~:.:~:~.- 4335. 4-~.~ B4~ 0,1 -~1.~ 2.P 25.1 ~5.5 1~7.~~,9 ~ .... ~-~ ~,,.;~ 4337, ~o,7 45.7 -0,3-3~,3 2.~ :.~.~ 4~5. 38.~ 38.3 1.2 -52 2 2 i ~3~7. 56.8 37.7 4351. 37.0 4353° 37 1 ~555. 39 7 4559. $8.5 ~8.5 -0.1 -q.q.4~2. 2 ;51~:0 122.~0.q. ~7 8 In ~ 0-~ ,.,. "'~:~'"~ ~ . ~'~:~ ::~::':~:~:~; ..... ~;;::~:. '~%~:.:~'-'~'~.- ....,.:.~ ~.s,..:.,,~:..: ....... ?::~.::.,,.,:.....,.,:.~;:.:~.,.. ' ......~.:,.~ ............... ;:~ .......... s };::~:~ ~+365. 5~.7 5~ ~-33.8 2.~ 21.3 qg.~ 112.8 6.0 ~ ~ .,.~:.'~ .~;:~ ....... ~,:~,; .. ,.~.~: ....... ~ ...... ~.:.,.. ' ........... ~:~ .... ~' '~ ~0: ::::::::::::::::::::::::: .... ~::~:~:~ .::::::>~?:~:~ ~::~:.~:~:?~:~:~:::':~::~: .::"::..:: 50. 50. -0..- ao.5 4369. 53.5 53.3~?-0.1 -30.8/2.~~1.0 48.8 116.~ 5.9 ~.2 ~.~ ~71. 51.9~51.9 -0~ ~~ 19.~ ~9.~ 11~.9 6.2 ~ 5 ~ I O 1 ~' ~, ~' .~ 5~.~ -0,~ -31,7 2.~ 20.~ ~5.q 1.'1~.0 6.~ ~575, 52,~ 5~,~ -0,7 -5 2 5 21.0 59.9 115.9 6.1 ~377, 5~,~ 51,~ -0,~_..,.,?~ 2.~ 25.5 ~1.~.~~ ~.~ PAGE 2 ~399. ~05o PAGE UNION O~L OF CALIFORHIA DEPTH GR GRZ CAL SP DEN DENP ~D~ _~. ~.OC_~~ RT~ D ~ COR~ .... ~. ~1.9 2~.9 -0.8 -~0.5 ~435. 50.7 50.7 -0.7-~1.6 2~ ,~~ ~2~~Q ~~ ~.A ~ n_~ ~5, ~5,7 ~5,7 -0,~ -~,~ 2 qqq9, ~q.O qq51. 37.0 4455. 39.5 ~q57. frO.6 40.6 0.0 -~9,4 2.1 31.0 ................. 4~6T, o .5 38.5 0,0 -D4,6 2.1 33.1 38.6 133,3 10.~ 14.7 15.5 0.1 ~7~, 37.z ~7.z -0.3 -57.~ 2~ 3~.0 PAGE 50 UNION OIL OF' CALIFORNIA DEPTH GR~. GR1 ...... GAL $.~ ~B DEStP.~ gM ~ ~£ RTL~ BT, n RQDI~ ~95. 35.2 35.2 0 0 ~q, 99 4501. ~50`5. 3q.3 ~505, 57,3 ~,507. ,57.5 37.5 -0,0-~,8 2,.1 ,6 !38,0 ~5Z5, ~9,0 39,0 O. ~.~%62,6 2,~ 35.3 ~5~7. ~0.~0.~ =~.3 -62.7 :~_~ 56.5 ~5Z9, ~7,3 37.3 -0.2 -62,Z 2.~ 35.1 ~525, ~32,6 32.6 -0,1 -62,1 2.L 32.~ ~527, 38.3 38,3 -0,5 - ~ 9 2,.~ 32,~0 PAGE 51 UNION OIL OF CALIFORNIA DEP TH GR GR1 CAL ~ D~ DENP C~ ~5~1, ~5,2 ~5,2 -0,0 -~8,9 e,~ 29,2 ~0 9 45~5, 35.5 35,5 -0.0 -5~ 7 2 ~ 39 i 4547. 54,7 0 5 -5: 9 2 ~551, ~0,0 ~555, qO,5 ~555, ~557, 50.8 50.8 0,3 -30,0 2,~ 22,3 43.3 1:1.3,8 6.2 ~+.3 .... ~.~. 0.3_ ~+559, 50,6 50.6 -0.5 -30,8 2. ~24.0 __q-. 2_L'~__~.l]~~-u~ a. m9 0_1 .... ~561 . ~9.1 49.1 0.6 -31,2 2.3 23.8. q563, 5~,0 54,0 -0,1 -~1,5 ~ .......... 22.~ ~567, 51.6 51,6 O.q -31.~ 2.~ 22.~ 6.3. ~, ..... ~ ..... ~~ .... 6~,7 ......... ~ ~ 8 ....... ~.~.6 ~ O. ,. ~ ..... q571, 47,7~.. 7 0,5 -38.9 2.~ 25.1 _~q_7 ~.u n~.l ~575, w7,6 q7,6 0,3 -5~,.~ ._2,.2 ...... 28..~5_ PAGE 52 UNION O~L OF CALIFORNIA 0 B -q5 6 2 ~599 ~601. ~2.0 ~605. 39,3 4607. 36.0 36.0 ~,~.0 -60.~ 2.1 31.3 461i. 4e.~ ~2.q 0.o -58~_ ,~6i~. ~6.5 ~6.5 -0.0 -sa.-~ 2.] ~s~,~.~ ~619, ~0.9 40.9 0.~ -56.3 ~,::,~:,~:<:.~ .............. ~ ~ :~27. 00.7 50.7 -0.2 -30.0 PAGE 55 UNION OIL OF CALIFORNIA ~651. 63.~ ~653. 56.2 ~655. 62.5 ~657. 66.6 4659. 67.1 4661L 69.5 69.3 0.2 %~p.~ 2.B 20~2 ,~..p.8 112.1 5.9 ~./, ~.~ .o.1_ ~667. 47.9 47.9 0.0 ~,~~0 2.~ 1~ 42~1 ~671. ~8.~, ~8.7 0.0 ~673. ~1.8 41.8 0.5-40.5 2 .............. ~ ......... ~ ...... ~~ ~r.~-~ ~-~ -~~?~;s~r ~ s~ q. sT$, ~5,a ~5,A o..~._..~.-~,~ ~ ~s.s s~.~. z~.~~~~~ ......... ~681. ~8.5 ~8.5 -0.0 -~9.7 2.2 28,~ 50,11~m9 $~5 q-1 la.2 0.1 ~68~. ~6.~ ,6.6 -0.8 PAGE 54 UNION OIL OF CALIFORNIA : 4699. 50,5 50.5 -0.2 ~+'70~, ~0 ~705. q4,,9 4707, ~.~ 4709. 39.6 4713. ~0.5 39.6 q717. ql.6 57.2 ~' :~.~ ........... ~Tz~, ~5.~ :':~:?~ PAGE 55 ~753. 43.9 ~755. q5.1 4757, ~7.! 4759, 41.5 · ~761. 48.! 4~A~ -O.Z -65.6 2. ~'763. ~3.9 q5.8 -0,5 -65,2 2.P 30.2 ~1,__7 112.~ ti~S. ~.~ ~.~ -0.7-~.1 ~767. ~1,7 35.9 O,O -59.~ 2.2 29.3 38,9~~q ~769. q7.5 ~ q~.8 ,. 0..~p_~-5~.2 2.P 28.~ ~771. ~3,5 ~2,~ 0,~. ~, 1 ~773. ~1.2 ~1.3 0.~ -60.8 ~..~ 4779. ~5.~ ~8.3 O.O '65. ~ ~ ~ 2~.2 ~ 3.._ ~__...10~.~ :::::::::::::::::::::::::::::::::: :::: ':~:: PAGE 56 UNION OIL OF CALIFORNIA 4801. ~7.3 0 1 5 2 480B 4805. 45.9 4807. 4q.7 q811. q7.3 45.7 -O.q -68.9 2.2 ~7.9 39.q 112.~ 9.2 ~.. ..~. :~ ........... :.:?~::. ....... ' . . ...<,>:: ~..:.:..:...: :~ ....... ~815. 42.7 59.5 0.1 -6~.~7....' 2.~ ~:~!~9~ 9.~ ~7 ~:: ............. ..:.:~:--- ...:::: ...... ..:.::. ,::;~::..: ................ :::::::::::::::::::::::::: .......... ....... ~ ............... ::::. ........................ :~..~.~..:...~..~.::.: ?~...::::~ ............ ::::::::::::::::::::: ................. ,~,:.~::..:...:::.:~::::::: :::::::::::::::::::::::::::::::::::::::::::::::::: :::~:~ ,:~:..~_~:~:~:~~ ~ae~. ~5.i ~5.s 0.4-Ge.~ 2~ ~~~l l~ ~825. 52.7 43.2 0 1 '62 7 2 50-2 q2 ~3 a ~ n _ ~833. 4q.~ qO.~ 0.0 -65.1 2.2 ~7~ 3~.q liO~ ~~~ PAGE 57 UNION OIL OF CALIFORNIA 03 52 ~ 2 4853. 40.5 4855. ~1.2 ~857, 42.7 4859 ~5 8 8~ q-865. ~2.9 3~.~ -0.0-56.6 2.2 24.7 ~,.._6~0~3.~.5 _,.,~,.,L~ ~n,3 ~865. 38,5 ~0.2 -1,1 -59.~ 2.3 23.5 32,9 98.7 9.] ~,9 ......... · ,.~, .... ~ ~ ...... ,,.,..~ ::: :':~:~ ,,., ':~~2~' ~-~ ~ '~869. ~,~ 37.~ 0.0 -55.1 2.3 2~ ........ 32.~ ~96~ 8,9 ~,a ~n,O O_O._ ~671, ~ ,1 ~6,8 -O&~-~8,2 ~,2 50~! 57,1 122,1 ~.8'75. 57.9 59.9 -0.3 -3~ 2,1 ~8 5~)_~ ~~ ~4877. 58.5 59,7 -0,1 -~0.6 2.3 23~3 ~.~ ~O~O ~~1:~,7 ~879. 58,0 58.6 -0.3 -~+~,.,3 ~ 1~,~, 3%,~.~~_~~ ~:~_:~ ~.~ ~883, 55,5 5~,6 -0,~ -6~,~ 2,5 20,7 ~2 9 9 R 2 PAGE 58 UNION OIL OF CALIFORNIA DEPTH ~R GR1 CAL ~ 885, ~~.5 64,2 0,0 4887 · 53, ? 58,3 0,0 -~ ~ 2~ .~Z~ 4D~.~_.~~,6 ~ n. A ~ .~..-0 ........ 0.~.~ ..... ~869, 53,~ 52.6 -0~ -~.~ 2~ 12.9 .~6_~ ZO.O ~n.~ I~_A n_l ~897, .~,1 60,7 0.0 - ~ ......15_~ ~~ ~~L 12.~ 13_1 la._~ n_l ~899, 59.9 58.2 0 0 5~ 0 0 5t ~ 2 q. 903, 5'7,3 4905. 55.6 4907. 57.1 4909. q. 91!. 55.1 51.6~-0.Li· ,-5.3.7 2.~ ~6.0 .39.5 101.7 7t 7.6 ~.9 0.,1 ...... ~ ............. ~: ........ :~-..,~%,~..~-. ~. .......... ..~.,.. ~.. ........ ~,::~.~.~.~,.,.,. ,,~::::,., ..... . ~~: :~: ~ T~F ,- :,>.; ,~ :~:~ ~,~.~:~ ~'.~' ~,~ :~:~:~,~'~"~' ~3, 55.~ 51.B -0.~ -37,7 ..... __2~ ~5~6 .........~~.~ .... ~ ~_~ 0-1. ~7. 5~.2 5o.z o.~-~.~ 2.~ z~..~,,... ~8 .~_~.~ ,+92i. ,S.8 39.6 0.0 .9~, ~5.0 39.8 -0.3 PAGE 59 UNION OIL OF CALIFORNIA ~ ~' S'~'' "'"'~D:"' ~i~ 4951. 52.3 ~953 4955. 54.1 ~957 4959 62 4 g96!. 63.9 56.3 0.1 -29.6 q 43.4 128.2 "":'~ ............. ~'~il '~;..~.. ,:?.;~,: .~::;'"~ ..... ~.~ ........... ~-"~D ~' "~¢~" ~ L:_::! ~969. 55.~ 53.0 0.0 -30.7 2.3 21.7 38.7 107.1 ~971. ~7.0 5~.6 ~.0 r~O.~ ~3 22.6 L ~97~. 51.4 53.~ -0.2 30.3 2 7 38 ' ~~~ ~9.a 53.~ -0.~ -29.6 2,2 ~a.i ~_~~~~ 4979, ~9,5 ~9.8 -0.1 -~ 2t~ ~ ~~L~~ ~98~. ~6.5 ~6.~ -0.~ ~8~9 2.1 J~l PAGE 60 UNION OIL OF CALIFORNIA 0 20 500S 5005, 58.7 5007, 55.7 5009, 58.6 5011. 5g'.9 5q,.8 -0,0 -50.6 2.2 25.2 36,5 115,3 .~..~1~, 51.2 55.8 -0.2-55,8 2.2 2~,~7 54~1 ~18 5017. 50.~ 47.7 0,3 -59.1 2.2 25,2 5019. 52.2 ~8.6 -0.6 -~,.5 2~:.~ 25.6 3 ~~ ~,5 0.~_ ~ ..... . ..... ...~::< ~ ~:..: .?: ..::~:~:~ PAGE 61 UNION OIL OF CALIFORNIA DEPTH GR ~B1 CAL ~P ~N DENP C~ 50~9. ~6.2 ~3.8 -0.9 -59. ~ 2.~ ~1.1 32.2 .... ~:z:~.:~;~ 50~1. ~8.2 ~.~ .... 0.0 -62.6 2,~k 5~.~ 32.5 50~7, q~,6 ~2,1 0 6 -60 0 2 o 7 5051. S8.6 -0 5 56 g 2 5053, ~9o~ 5055, ~,5 5057, 51.2 5059. 55.5 5061, 51,5 513..~ -0,1 ~,0 2,;:, 5065, 51,2 ..... ~ 7 ~ 0,0 -~9,5 2,2 26.~ 5067. 52.0 52.5 -0.2 -61.3 2.2 27.2 53.6 106.8 ~.2 5069. 52.1 ~,~ -0,0 -6P.~ 5071, 51,0 ~,q O,q -61,~ 2,2 26.5 ~7.q 115.3 9.2 507~. 56,~ ~8,B 0,5 -~3,6 2 5 $3 ~ 10 5077, ~6.2 ~7,2 -0,5-~.7 2.2 ~;6~5 ~.~ Z20.O ~ ~ 5081, ~7,~ q2,9 -~0 -6~p .... 2~ PAGE 62 UNION OIL OF CALIFORNIA DEPTH GR GR1 CAL ~ DEN DENP 5085. 48.2 q~9~ -0.7 5087, ~8.~ ~3,2 -0,0 -6~,0 2,1 50.6 ............. ~:::": ...............~ ..........'~-.-,.~: ~:. .............. ~:::::: ~,::::::'::. ~: ~.:::-':-::':':': .~ '::: ::~: ':~:: ~:: ':' ': :~ '7~ ~'~ ~;::: :::::: :::::::::::::::: 5099, ~6.~ ~.6 '0.2 '62,1 2 5101, ~8.8 -0 7 63 5 2 5103. 45,3 5105. 44,2 5107. 42.0 5109. 46.4 5iii. 4i,~ ~9.9 0.0 ~~ ........ 2,~_ s~_~ ~..~P. 5.6~ a.~ ln.~, 5113. 4 ,8 ~1,0 0,0-58,9 2,1 S3~L 3.8_~~~ ~_ 8.~ ln.O O.1 5115. q5.5 ql.~ '0.3 '~,5 2,1 S3.3 39.7 125.5 __~.. 10.1 ..11.7 0.0. ~:~. .~: ~. ~:<:.::'~ ~:~:~: ~:::.-~.. .,:~':~~~ .. 51z9, ~0,~ ~2,B -0,5 -Gs,..~.,_:.. 2,: .~ ~2~~,5 10,4 9.5. z~ .... 0._ 5ie9, ~i,5 ~,i -o,i -i~.6 ~.~ ~i~.~i,~ ~7~ ~ ::<. ~:~::;~:::,. :~'~ ,.:..:::' ;~,:::: ~:~T~:'~'~::: :· ':7 ~::: : :':::: ? : : PAGE 6,5 UNION OIL. OF CALIFORNIA 5139. 4~.3 ~0.6 0.0 -6~.~,~,~~ ~2.6 51q:5,.~,q ~1,8 0,1 -66.0 2.9 29~ 2~.~ 1~1.G 51'9, 42.2 38.0 0 0 55 6 1 5151. 35 0 3 5153, 31 6 5155. 52.7 5157. 59.6 5159. 58,1 5161.~,55.9 59.3 -0.0 -~5 2.q 1_.5.2 51~,,.,~61.0 59.i 0.8 -3o,0 e.~ 15.i 5i69. 5i.~ 50.2 g~,9 -57.~ ....~ 5i7i. 5i.q p=%.5 o.q %,~Z ~.~ e~.7 34.1 5173. 50.8 55.6 -~5 -g5.8 2.~ 19.~ ............... 5177. ~ 55 ~ 56.1 ~. ~..% 50 ..~....,. 2.p 25.7 35~ ~ ~ 5179. 56.~ 55.6 -1.2 -57.3 ~ 25 518~. ~5.8 q5.8 '1,0 'q9.7 2.2~.~ 8 ~J ~9~ :;? i~:~8.~?~,.:.'~' ~2~t: :: ~5:LL ~.., PAGE UNION O~L OF CALIFORNIA .............................................................. · ~.~=.:~ .......... ~ ........... DEPTH GR GR1 CAL ..~ ....... ~,.?_ . _..:.~: ..................... ~- ~ 5199. 50.0 50.1 5201 5203 5205. 5207. 5209. 5213A ....... 45.8 50,5 0,0 -62,q. 2,2 27,.2 5217. ~.9 5i.~ 0.0 -6~.5 2.~:..,....: 26~ ~233. ~6.6 53.8 ~o..D.._-6~..~__ ........ ~__a. ....... ~..~ ..... aL.3. PAGE 65 5251, q5.~ '0 2 5253. 49.1 .)255. 46.7 5257. 51 5259. 61,3 D261. 57.2 6q-.5 -O.q- -6~.5 2.2 2q.q- ~+-! I1~.0 8.0 .... 8.2 g.9 fi.1 5265. 53.~ 60.~ 0,0 -~0,2 ~.~ 17.~ ~.9 102.6 9,5~6 g.,9 0.0 5267. ~7,0 5~.7 0,0 -~8,0 2.~ 18.1 ~0_,! ....!_~8~~ ~,6 g.9 0.1 5269. ~8.~..~...:..: 5~:..,~0.0 -39.3 ~_~.~ 16~ ~3.0..lOS.~ 7..8 5271. ~?.3 51.5 0.0 5275, ~7,0 ~8,9 -0,4 -56,6 PAGE 66 5301. 5303. 5305. ~9.4 5307. 5309. PAGE B7 UNION OIL OF CALIFORNIA DEPTH GR ~.~ CAL SP DEN DENP CN~ ~ RI~ i]~ CnR~ 5535. ~+5.o 6~+.5 -o.2-~+e.o ~.e ea.1 ~9~6. 9~~ 1~-~ ~.~ 5a39. ~4.7 51.7 -0,2-6~.9 2.4 1~.0 a6.~ 97.1 10~ 12-2 11.9 5~!. 4S,9 ~9.5 -0~ L!O,3 2,~ 1L9 ~1.6 a~A~~O-S 5a~7. ~.~ 6~.0 0~ ~~ e.s 6.9 ~Z.O ~~ ~n a 55~9. ~5,8 6~.0 0,0 -52.9 2.5 0 ~0 5351 0 0 5' 2 2 5555 5357. ~2.9 5559, ~2.9 5561. ~2.9~99.0=? 0.0 -64.89999,06160.699~?..0 97.1 11.2 11.8 la. Ogggg.o~. 5367. ~2.99999.0 0.0 -6~, ~9999. 06160. 69999 1,3 11.8 17.99999.0 5369. ~2.99999.0 0.0 -6:4.59999.061&0.69999.097.1 ~1.} 11 8 17.99999_~ 5~71, ~a.9~~O ~.0 -6g.19999,06160.69999.0 97.1 11.5 11 8 18.09999.0_ 5373, q2.99999.0 0.~...:6~, 69999. 06160 · 6~99 LQ 97.!~1.5 11.8 1~. 09999~ ~75. ~a.9999~ 0 0.0 -6g. 79999,06160. 6999 17.a9999.0 5a77. q2.99999.0 0.0-65,19999,06160.699p~a~ 9~~,~ 11~ 17-99999.fl 5579, ~a, 99~99,~ 0,0 -6~, 89999~06160. 69999.0 97.1 11.5 11_8 5583, ~, 99999 ~9= 0,0 -6~, 79999,06~~.9.~9.0 ~1 PAGE 68 UNION OIL OF CALIFORNIA
