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Home My WebLink About167-009- tm -Chee V_ I k Regg, James B (DOA) From: Chad Helgeson [chelgeson@hilcorp.com] Sent: Tuesday, February 18, 2014 3:46 PM �jGt To: Regg, James B (DOA) ( ` Cc: Stan Porhola; Mike Dunn; Paul Chan; Buck Moncla; Spook; Grimaldi, Louis R (DOA) Subject: Incident investigation - fire at beaver Creek Attachments: 1302_001.pdf; 2014-01-05_NKE_BC_Pad1_Fire.xlsx; HAK Lessons Learned 1-9-14.pptx Jim, I apologize for not getting all this information to you earlier, like I told you that I would in January. Attached are all the incident reports that have been filled out for the fire incident. One report is Moncla's incident report investigation, one is the initial report by Hilcorp, and the final attachment is a bulletin that we developed the same week of the incident and shared with our folks and all of our contractors, to learn from this incident. We feel that we have taken the necessary steps to prevent this event from being able to occur, starting with operating practices, to equipment modifications. As a result of this incident we found several flaws in the equipment we had and our arrangement of the winterization package for the Moncla #405 rig. This was the 1" well that the #405 completed work for outside of Swanson river and there was a new winterization package that was erected and steps were taken in the procedure before all the equipment was rigged up and operational. Since this incident we have worked with Moncla to identify safety hazards by contracting a 3`d party safety group that is familiar with rig operations to work with the rig on a daily basis. We continue to find ways to improve the system and equipment to make it safer and more efficient, and committed to this as long as the rig is located here in Alaska. I will complete a follow-up email to Lou's email this week to address some of the other issues identified in his email and provide some clarity of what we are doing and have done to address them. If you want more dialog around this incident, please let me know and I can come down to your office and we can meet with you to discuss. Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907-777-8405 OCT 0 3 204 Mobile: 907-229-4824 � ;re, C. r ee l& 1 rwwM Incident Investigation 71 i Hilcorp Alaska, LLC A&I Lessons Learned Share Y amu Complete Description of the Incident Prior to a well workover, existing pressure in the well bore needed to be relieved. Hard pipe from the well was connected to a choke skid and then to a mud/gas separator (MGS) also gas buster. The MGS is designed to vent gas out of the top and liquids to a mud tank below. A choke skid, MGS, mud tank and mud pumps were inside a temporary enclosure with the MGS gas venting outside of the enclosure. The enclosure was heated with indirect fired heaters. As the well was depressured, gas exited through the mud leg introducing gas into the enclosure and displacing the ambient air. The gas concentration increased until it found an ignition source resulting in three distinctly separate fires inside and outside of the enclosure. Impact or Result of incident? One person received a superficial burn to the face, no other injuries were reported. The liner used to cover the enclosure and liner on the ground was burned. What are the Lessons Learned? (P-"[) X67 uta) • MGS and mud tank shall have adequate ventilation • Consider static discharge during any fluid transfer Causal Factors • Gas detection systems in indirect fired heaters not installed or not functioning • No fluid seal in the gas buster • Equipment not grounded and bonded • Static discharge not anticipated Root Cause Categories • Inadequate assessment of needs and risks • Inadequate assessment of operational readiness • Inadequate adjustment/repair What are the corrective actions? • Ensure all gas monitors are in working condition. • Adding a P -Trap to the MGS • Properly bonding and grounding all equipment • Move equipment to better suit rig for winterization Hilcorp Alaska, LLC Lessons Learned Slide � i/Z— IN[ Hilcorp Alaska, LLC Incident Investigation Lessons Learned Share �41,\ C(6c ,10 s 151A,4,-(7eei6-- 1/k - A, 16 JuC9z) Hilcorp Alaska. LLC Lessons Learned Slide /VZ IV -61U, k 12-c5 140 s All Other Incidents ��i - I CPN /l>?70U�tu) Other Incidents Complete all the required fields on this tab within 24 hours and e-mail the form to Alaska Incident Reporting AlaskalncidentReporting(cDhilcorp.com Field Name Data Incident type Fire or Ex losion Facility Name NIKE - Beaver Creek If "Other", please elaborate Incident Date 1/5/2014 Incident Time 14:00 Name of employee or contractor involved Moncla Employee type Contract Company (if applicable) Position title On -scene supervisor this was reported to James Ostroot Facility name where incident occurred NKE - Beaver Creek Exact pad, location or structure on site Pad 1, well 1A Contributing weather conditions 32 - 80 F 0 27 C Other weather Names of witnesses Crew Moncla Apparent primary cause Hazards not identified Was a JSA prepared for this job? Yes Incident detailed description A fire occurred while killing and depressuring well 1A. Choke manifolds, gas buster, and pump were placed inside an enclosure. Enclosure was metal framed with pit liner used as cover for roof. One of two direct fired forced air heaters was in service heating the interior of the enclosure. While blowing well down, gas accumulated inside the enclosure and ignited. There were three loud reports (blasts) with three reported fireballs outside of the enclosure. The enclosure was unoccupied at the time of the incident and damage was limited to liner and 1 hose. An investigation is in progress. Immediate actions taken Shut down all equipment and initiated pad shutdown. Incident Classification Level Near Miss Analysis Near miss category Near Miss Classification Level Comments: Describe how this incident was a near miss: What did you think could have happened? Why did you call it a r miss? Internal and Contractor Notification Reported to (HAK) Bruce Hershber er Date reported 1/5/2014 Time reported 14:00 Method of report Telephone Reported by James Ostroot Reported to HAK Date reported Time reported Method of report Reported b Reported to (External person w/company name) Date reported Time reported Method of report This report may contain confidential and/or privileged information and is intended for the recipient(s) only. Do not distribute or print confidential information. revised 10-18-12 All Other Incidents Reported b Reported to External person w/com an name Date reported Time reported Time reported Reported b HAK Property/Equipment Damage Short description of property / equipment damage or loss Damage or loss Equipment descri tion Estimated cost of loss This report may contain confidential and/or privileged information and is intended for the recipient(s) only. Do not distribute or print confidential information. revised 10-18-12 E Basic Information 1�4�c a�S 1Pleettlt—CPee_�(6 IX CPm 147(jorio) Incidents - Incident Investigation Incident Number FY14-0010 Preparers ID 437-51-8476 Preparers Name Brandon Lege Preparers Title HSE Director Involved Employee ID 427-13-2343 Name Johnny Hibley Job Title Supervisor Supervisors ID 433-39-1730 Supervisors Name Druis Trahan Supervisors Title Superintendent Worker Type Moncla Emplovee Date of Incident 01/05/2014 Time of Incident 11:30 AM Incident Type Property Damage Was a Vehicle Involved? No Was an employee or directly No supervised contractor injured? Was Property Damage Involved? Yes Initial Incident Description While bleeding off the well, the gas buster didn't have water in the vessel, allowing the gas to escape into the covering. Static electricity discharged and the gas ignited. This caused an explosion and burned the herculiner. Incident Details Can Time Be Determined? Yes Shift Dav Reported to: Employee ID 433-39-1730 Reported to: Name Druis Trahan Reported to: Title Superintendent Date Reported 01/05/2014 Location Alaska Business Group Moncla Offshore Operations, LLC Client Hilcorp Rig 405 Location On City Kenai State ALASKA Description of Location Beaver Creek, well BCU 1A Weather Cloudy Description of Incident While bleeding off the well, the gas buster didn't have water in the vessel, allowing the gas to escape into the covering. Static electricity discharged and the gas ignited. This caused an explosion and burned the herculiner. Witness Information Number of Witnesses 0 Property Damage Estimated Property Damage $2000.00 Responders Identify Emergency Responders ❑ Fire/EMS Report # ❑ Police Report # Incident Analysis Number of Primary Causes 0 I N D U STRYSAF E Date Report Generated: 2/11/2014 Page 1 of 2 �9 It, 7&01-0) Incidents - Incident Investigation Incident Number FY14-0010 Was a drug or alcohol test No performed? Did the involved employee work the previous shift? Additional Remarks Report Status Complete Corrective Action Corrective Action System ID 1120 Status Complete Responsible Party Brandon Leqe Problem/Description While bleeding off the well, the gas buster didn't have water in the vessel, allowing the gas to escape into the covering. Static electricity discharged and the gas ignited. This caused an explosion and burned the herculiner. Recomendation 1: Ensure all gas monitors are in working condition. This was inspected by an inspector and they indicated that they were working properly. 2. Adding a P -Trap to the Gas Buster will help keep gas from escaping through the bottom of the device. 3. Properly bonding and grounding all equipment to prevent static discharge. 4. Move equipment to better suit rig for winterization. Estimated Start Date Estimated Completion Date Actual Completion Date 01/08/2014 01/09/2014 01 /09/2014 Corrective Action Taken Bonded and grounded equipment to the well head, Added P -trap to the Gas Buster; Repaired/exchanged gas detectors on heaters; Moved equipment to better suit rig winterization. INDUSTRYSAFE Date Report Generated: 2/11/2014 Page 2 of 2 *4 Basic Information Corrective Action Report 1 v -4 4.n4,4 5i System ID 1120 Originating Type Incident Originating System ID 1842 Source Incident Number FY14-0010 Date Identified 02/11/2014 Location Alaska Business Group Moncla Offshore Operations, LLC Department 405 Investigator Brandon Lege Nearest Milepost Repaired/exchanged gas detectors on heaters; Moved equipment to better suit rig Detailed Location Beaver Creek, well BCU 1A Problems/Description While bleeding off the well, the gas buster didn't have water in the vessel, allowing the gas to escape into the covering. Static electricity discharged and the gas ignited. This caused an explosion and burned the herculiner. Recommendation 1: Ensure all gas monitors are in working condition. This was inspected by an inspector and they indicated that they were working properly. 2 Adding a P -Trap to the Gas Buster will help keep gas from escaping through the bottom of the device. 3. Properly bonding and grounding all equipment to prevent static discharge. 4. Move equipment to better suit rig for winterization. Notes/Comments Resolution & Responsibility Responsible Party Second Level Responsible Party Third Level Responsible Party Brandon Lege Phone Number Estimated Start Date Estimated Completion Date Number of Days Until Due 01/08/2014 01/09/2014 -33 Status Actual Completion Date Complete 1/9/2014 12:00,00AM Corrective Action Taken Bonded and grounded equipment to the well head; Added P -trap to the Gas Buster; Repaired/exchanged gas detectors on heaters; Moved equipment to better suit rig winterization. Estimated Cost 0.00 INDUSTRYSAFE Date Report Generated: 2/11/2014 Page 1 of 1 STATE OF ALASKA RECEIVED • ALAz,..,1 OIL AND GAS CONSERVATION COW/1106'10N WELL COMPLETION OR RECOMPLETION REPORT AND i=b6 1 201 4 la.Well Status: Oil ❑ Gas El SPLUG ❑ Other ❑ Abandoned " ` lb.Well Class: � 2OAAc 25.105 3�K/20AAC 25.110 4 D elopment ❑✓ , x oratory GINJ ❑ WINJ ❑ WAG ❑ WDSPL El No.of Completions: _1 3'11 1,44,A,A Ll5ice ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,S�24 or Mit,-top.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 1/11/2014' •167-009/313-630 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Anchorage,AK 99503 3/13/1967 50-133-20008-00 • sir K' (3e-t< 4a. Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: /d Surface: 11T FSL, 1338'FEL,Sec.33,T7N,R1OW,SM 6/13/1967 Beaver Creek Unit(BCU)01A • Top of Productive Horizon: 8.KB(ft above MSL): 153' 15.Field/Pool(s): GL(ft above MSL): 138.4' Total Depth: 9.Plug Back Depth(MD+TVD): Beaver Creek I Sterling-Beluga Gas 1003'FSL, 1966'FWL,Sec.34,T7N,R1OW,SM 5,250'MD/4,927'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 314428.2 y- 2430086.4 Zone- 4 • 10,296'MD/9,390'TVD ' FEDA028083 TPI: x- y- Zone- 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 317749.5 y- 2430925.8 Zone- 4 N/A 18. Directional Survey: Yes ❑ No Q 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94 H-40 0 526' 0 526' 26" 1,000 sx 0 13-3/8" 61 J-55 0 2,209' 0 2,209' 18-5/8" 3,500 sx 0 9-5/8" 40-43.5 N-80 0 5,101' 0 4,794' 12-1/4" 1,800 sx - 0 7" 26-29 N80/P110 0 9,697' 0 8,807' 8-1/2" 730 sx 0 24.Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A N/A 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. NES MAY 1 3 BA hydraulic fracturing used during completion? Yes❑ No 0 Sr'SNI` MAY DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED �"" " 7"c-. QJa:...., 3 0 d/.9- 13ej,-•--, -SQL G-. -7705' N10 `f BB` /rho. 7' cr P 6 525CYM6 27. s PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A _ N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate ..► 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No El Sidewall Cores Acquired? Yes❑ No❑ 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 laboratory analytical results per 20 AAC 25.071. N/A RBE,At',::: MAR 21 `2.1:33/4- Form =; 1Form 10-407 Revised 10/2012 CONTINUED ON REVERSE ,/,_ L/l ,;//. Submit original only /a 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? n Yes 2 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email:_sporhoIa p hilcorp.cot11 Printed Name: Stan Porhola Title: Operations Engineer Signature: to-r1s1 - "i (://11 � Phone: 907-777-8412 Date: 2/f0/! I 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: 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 30: 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 10/2012 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-01A 50-133-20006-00 167-009 1/3/14 1/11/14 Daily Operations: 01/03/2014- Friday MIRU Moncla 405. Start equipment, troubleshoot rig issues. Move wellhouse and ND flowlines. Move rig and equipment. Move and spot containment. Spot basebeam and rig, troubleshoot frozen air lines. Shut down for night. 01/04/2014-Saturday Thaw frozen air lines on rig and spot rig. Attempt to raise derrick, SRL line got in a bind and parted. LD derrick and found bent hinge on SRL boom. Welder to repair. Spot choke/kill manifolds, tank, and pumps. Begin RU of new winterization package. Spot accumulator and generators, electrician replacing damaged connections. Shut down for night. 01/05/2014-Sunday Continue RU and winterization. Repair bent SRL boom bracket and install new SRL line. Install corrugated metal on sides and pit liner on top of winterization tent. Prepare to raise derrick while blowing well down. Heater ignited gas inside winterization tent and melted off all pit liner on top and spots of containment underneath. Mustered and everyone accounted for. Shut well in and extinguish smoldering plastic. Shut down for safety investigation. Clean up debris and begin moving pump, tank, and choke/kill manifolds to repair containment. Shut down for night 01/06/2014- Monday Move equipment off damaged containment and add new section of liner. Raise derrick. Spot equipment and install winterization. Added new pit liner to carrier and winterization tent. Shut down for night. 01/07/2014-Tuesday Continue RU of containment and winterization. Repair heaters and troubleshoot broken chain on pump oiler. SITP: 600 psi. Pump 20 bbls KCL down tubing to 0 psi. Finish RU containment. Blow down well, unloaded 6 bbls KCL and flowing @ 400 psi. Pump 20 bbls KCL down tubing and well dead. Monitor for 15 min -well dead. Set BPV and ND wellhead. NU 11" BOPE. 01/08/2014-Wednesday Waited on State Inspector for BOPE test witness. Tested BOPE Valves 250-3000psi, Rams 250-3000psi, Annular 250-1500psi. During test the Kill Line split. Shut Down. Replaced kill line and shell tested. Sent the gas buster into the shop and welded a p-trap onto the water leg. 01/09/2014-Thursday Finished Testing BOPE, 2 failures recorded, choke line valve f/p, and the Kill Line Hose failed- replace and shell tested good. Completed BOPE Test and Rig Inspection with State Witness Lou Grimaldi. Pulled TWC and pumped 50bbls of FSW down tbg. With tbg on a vacuum MU landing jt and PU tbg hgr and pulled the tbg 15k in tension. Well started flowing. SI TIW. RU the Kelly Hose and pumped 40 bbls down the tbg. Well on vacuum. MIRU EL. Test lub to 2,500psi -test good. RIH and cut tbg at 7,750' ELM. POOH-Cut good. RDMO EL . SOOH with 249 jts of 3-1/2" IBT and 1 chem injection mandrel. PU a 7" cement retainer and TIH with 110 stands of 3-1/2" IBT at report time. 01/10/2014- Friday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-01A 50-133-20006-00 167-009 1/3/14 1/11/14 Daily Operations: Set the 7" cement retainer at 7,705'. Stung out of retainer and stung back with 10k in compression. MIRU SLB cement, Tested iron to 2,800psi-Test Ok. Pumped 5 bbls of fresh water. (Batched mixed 33 bbls of 16 ppg cement). Pumped 30 bbls of cement and displace 10 bbls of fresh water, 54 bbls of FSW. Screen out 4 bbls shy of the retainer. Stung out of the retainer and dumped,4 bbls cement on retainer. Reversed Circulated 240 bbls of FSW around to clean up well. POOH and lay down tubing. 01/11/2014-Saturday MIRU EL, MU GR/CCL, setting tool and 7' CIBP. RIH and logged up from 5,600'to 5,100'. Correlated to cement bond log. Set CIBP at 5,250'. Top of CIBP 8' above collar at 5,258'. Tagged CIBP to confirm set. POOH and RDMO EL,Tested CIBP to 2,500psi for 30 mins and charted -test ok. ND BOP, NU Dry Hole Tree. RDMO WOR to BCU-14. . _ BC-1A ACTUAL Pad 1A Ililcorp Alaska,LLC 117' FSL, 1,338' FEL, SCHEMATIC Sec. 33, T7N, R10W, S.M. Permit#: 167-009 API#: 50-133-20006-00 Conductor Property Des: A 028083 A ` 20" H-40 94 ppf KB Elevation: 153.2' (14.8'AGL) ' Tg Bottom Spud Date: 3/13/1967 DV Collar MD o' 526' TVD 0' 526' TD Reached: 6/13/1967 _ @ 2,080' Lat: 26"hole cmt w/1,000 sks of Class G Long: Bridge Plug g Tubing String Set at 5,250 3-1/2" L-80 9.3 ppf 2.984"ID Top Bottom Cement Retainer MD 7,750' 7,890' Set at 7,705' TVD 6,979' 7,093' Perforations: ,‘ r :: Surface Casing MD MD TVD TVD .+, I Baker 80-40 Anchor on Baker 13-3/8" J-55 61 ppf B-18U 8,087'-8,107' 7,627'-7,284'(9/12/96) _ \-' 84 SAB 40x30 Permanent T� Bottom B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) Packer MD 0' 2,209' B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) is. 3.25"ID @ 7,764' TVD 0' 2,209' 13-20 8,284'-8,312' 7,444'-7,470'(9/4/96) B-21 8,374'-8,404' 7,528-7,556'(5/10/96) PI r t. 2.813"Camco X Nipple 18-5/8"hole cmt w/3,500 sks of Class G 8-22 8,439' 8,459' 7,589'-7,608'(5/8/96) . @ 7,815' B-23M 8,500'-8,520' 7,646'-7,665' 3/15/96 I i Intermediate Casing ( ) 9-5/8" N-80 40/43.5 ppf B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) 1 [� 2.813"Camco X Nipple Tom Bottom _ @ 7,853' MD 0' 5,101' TVD 0' 4,794' Wireline Re-entry Guide Thru-Tubing Magna Range Plug -712-1/4"hole cmt shoe w/1,100 sks of Class G Set at 8,608.5' _.f E @ 7,890' Cmt w/700 sks thru DV Collar @ 2,080' Dump Bail 12.5'of cement to 8,596' - 3.25 OD x 2.984 ID . a= 1 Production Casing , 7" N-80/P-110 26/29 ppf . kap Bottom AT. i MD 0' 9,697' Baker SC-1 Packer Velocity String a TVD 0' 8,807' 1-3/4" QT-700 0.125"wall -1 4"ID @ 8,607' (***Pulled 8/21/13***1 7" N-80 26 ppf 0'-4,700' 7" N-80 26 ppf 4,700'-6,300' Perforations: - 7" P-110 26 ppf 6,300'-9,697' B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) a 8-1/2"hole cmt w/730 sks of Class G 2.313"Otis X NippleWell Screen @ 8,894' I 4.5"OD x 2.438"ID Gravel Pack Screen 4-1/2" L-80 17 ppf Perforations: C Top Bottom MD 8,607' 8,984' B-28 8,956'-8,976'[8,085'-8,104'TVD)(11/21/88) ° TVD 7,747' 8,110' Model D Packer Capillary Tubing �( 11 0 .11' / 3.25"ID @ 8,984' Gravel packed 3/8" 2205 Stainless Steel , r _ Top Bottom rn-MD 0' 0' Cast Iron Bridge Plugs TVD 0' 0' . @ 8,994'MD, 9,001'MD, 9,003'MD (***Pulled 03/04/2013***) e_ Ali. Perforations(Squeezed): MD Tree cxn:6-1/2"Otis '. 1. Sterling 131 5,300'-5,310'(Sqzd 6/30/67) TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD:8,994' Sterlign 133 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Csg(6/20/67 CBL)-5,230' TVD:9,390' TVD:8,122' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 5,655-5,675'(Sqzd 11/11/88) Well Name&Number: Beaver Creek-1A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 1.8°/100 ft @ 2,300' Angle/Perfs: 29°-*19° Maximum Deviation: 39°@ 4,450' Date Completed: 02/13/96 _ Ground Level(above MSL): 138.4' _ RKB(above GL): 14.8' Revised By: Stan Porhola Downhole Revision Date: 1/11/2014 Schematic Revision Date: 1/30/2014 r SOF T� I I/7, s THE STATE Alaska Oil and Gas 9a ° Ll AS KA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OJA, ,f P Anchorage, Alaska 99501-3572 �1q Main: 907.279.1433 MAY 6 ZU!k Fax: 907.276.7542 SCANa° Stan Porhola Operations Engineer I)0q Hilcorp Alaska. LLC I 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit (BCU) #1A Sundry Number: 313-630 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, -114 19) — Cathy P. oerster Chair DATED this Gdday of December, 2013. Encl. . yek. • �,� RECEIVED STATE OF ALASKA '►' ALASKA OIL AND GAS CONSERVATION COMMISSION ` DEC 0 ZO13 APPLICATION FOR SUNDRY APPROVALSst� � 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑, - Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑✓ • Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other.❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ 167-009 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service El6.API Number: Anchorage,Alaska 99503 50-133-20006-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Beaver Creek Unit(BCU)#1A . Will planned perforations require a spacing exception? Yes ❑ No 2❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 • Beaver Creek/Beluga Gas Pod ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,296' -- 9,388' ' 8,994' 8,120' 8,994' WA Casing Length Size MD TVD Burst Collapse Structural Conductor 511' 20" 526' 526' 1,530 psi 520 psi Surface 2,205' 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,115' 9-5/8" 5,130' 4,824' 5,750 psi 3,090 psi Production 9,682' 7" 9,697' 8,805 7,240 psi 5,410 psi 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" 9.3#,L-80 7,890' Packers and SSSV Type: Baker SAB Perm Packer;N/A Packers and SSSV MD(t)and ND(ft): 7,764'MD/6,998'ND;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n- Service n 14.Estimated Date for 15.Well Status after prorosed work: 12/19/13 Commencing Operations: Oil ❑ Gas Qr-p,f19 WDSPL ❑ Suspended 2//0 16.Verbal Approval: Date: WINJ [11 GINJ ❑ (2' WAG ❑ Abandoned ❑ l'�`' Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email sDorholat hilcoro.cortl Printed Name /�/Stan Porhola Title Operations Engineer 1 Signature Lam. PC71/4*--- Phone 907-777-8412 Date l2(01-7/3 ��// COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\3— L.30 Plug Integrity ❑ BOP Test E7 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4‘ 33Ot- los:- $Of /� *- A(h./n 4& P f la c_Gt+a,y,d— �.,rre� /A t AA' a 1(Z (c....) RBDM MAY ' :' 2014 Spacing Exception Required? Yes ❑ No [f Subsequent Form Required: /d— /C7- ` APPROVED BY Approved by: t_/..617 (�r�_ /� COMMISSIONER THE COMMISSION Date: /2 -�_�� 12.17/i D I i J cp /\ Submit Form and 1�j Form 10-403(Revisbff 10/2012) Ap �J�plfliVa�'., 17/d�>� 12 months from the date of approval. Attachments in Duplicate 17-9 6 • Well Prognosis Well: BCU-1A Hilcorp Alaska,LL) Date:12/05/2013 Well Name: BCU-1A API Number: 50-133-20006-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 19th, 2013 Rig: Moncla#405 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: December 19th, 2013 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 167-009 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,695 psi @ 7,748'TVD (Based on static survey March 2013 run to 8,608' MD) Maximum Expected BHP: — 1,695 psi @ 7,748'TVD (Based on static survey March 2013 run to 8,608' MD) Max. Allowable Surface Pressure: —920 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#1A was originally planned as a relief well in 1967 to the Beaver Creek#1, but was eventually completed as a gas well to target gas sands in the Sterling and Beluga formations. A workover in 1996 ran gravel pack screens across the lowest perforated intervals, squeezed off the remaining Sterling perforations, and ran a tubing and packer above other Lower Beluga.The velocity string was pulled in August 2013 and the lower gravel-packed interval was abandoned in September 2013.The well was swabbed to bring on gas from the Beluga intervals but attempts to produce were unsuccessful.The well is currently shut-in. The purpose of this work/sundry is to abandon the current perforated intervals and prepare the wellbore for ✓ re-drilling operations. A drilling permit application will be submitted separately for the sidetrack. OpCv/s, Notes Regarding Wellbore Condition I C "Or i"-NP • Last tag at 8,596' RKB on 9/12/13 w/a 2.50" Dump Bailer. WO Rig Procedure: 3 1. MIRU Moncla#405 WO Rig. 2. NU BOPE.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. c. BPV in hanger profile. 3. Bleed any pressure off casing. Pull BPV. 4. MU landing joint and pull 15k tension over string weight on tubing hanger. 5. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 6. RU 3.5"Tubing Jet Cutter. 7. RIH and jet cut tubing at 7,750' MD a. Have backup cutters on location if tubing does not part. 8. SOOH and rack back 3-1/2"tubing. • 11 • Well Prognosis Well: BCU-1A Hilcora Alaska,LL Date: 12/05/2013 9. MU 7" Cement Retainer and RIH on 3-1/2"tubing out of derrick. 10. Set cement retainer at+/-7,725' MD. 11. Circulate well clean w/Produced Lease Water. -r St3RLs �. 12. Sting into retainer. Mix and pump 30 bbl cement below retainer. Tp 7 13. Unsting out of retainer. POOH. LD 3-1/2"tubing, and retainer setting tool. b/ 14. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. �-'-�` 15. RU 7" CIBP and GR/CCL tools. 16. RIH and set CIBP at+/-5,250' MD in the 7" 29#casing(set 3-5 ft above a casing collar). 17. RD E-line. 18. Test casing to 2,000 psi for 30 min and chart. ofr-- 19. Set BPV. ND BOPE. NU dry hole tree. Pull BPV. 20. RD Moncla#405 WO Rig. 21. Turn well over to production in preparation of moving in the Saxon#169 Drilling Rig. 22. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Wellhead Schematic • BC-1 A ACTUAL Pad 1A n;h.,,,•„ ,l.,a.,.„if 117' FSL, 1,338' FEL, SCHEMATIC Permit#: 167-009 Sec. 33, T7N, R10W, S.M. API#: 50-133-20006-00 Property Des: A-028083 A �, • r k Conductor H-40 94 f KB Elevation: 153' (16.8'AGL) " ¢ T� Bottom 4 41 Spud Date: 3/13/1967 yy " MD o' 526' TVD o' szs' TD Reached: 6/13/1967 Lat: 26"hole cmt wl 1,000 sks of Class G Long: A . Tubing String 3-1/2" L-80 9.3 ppf Camco Injection Mandrel 2.984"ID Top Bottom 5.25"OD @ 898' i' .0.•)-,,(0) MD 0' 7,890' TVD 0' 7,101' Perforations: - Baker 80-40 Anchor on Baker -- k 84 SAB 40x30 Permanent MD MD TVD TVD i r . Surface Casing 9/12/96 - - Packer 13-3/8" J-55 61 ppf B-18U 8,087'-8,107' 7,627'-7,284' (9/12/96) lL-� 3.25"ID @ 7,764' Top Bottom B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) - I MD 0' 2,220' B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) li , 2.813"Camco X Nipple TVD 0' 2,220' B-20 8,284'-8,312' 7,444'-7,470'(9/4/96) - 4 @ 7,815' B-21 8,374'-8,404' 7,528-7,556'(5/10/96) • ii " . - 18-5/8"hole cmt w/3,500 sks of Class G B-22 8,439'-8,459' 7,589'-7,608'(5/8/96) - II l' - 2.813"Camco X Nipple B-23M 8,500'-8,520' 7,646'-7,665'(3/15/96) • 7,853' B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) - Intermediate Casing C @ 9-5/8" N-80 40/43.5 ppf Wireline Re-entry Guide Top Bottom =I C @ 7,890' MD 0' 5,130' Thru-Tubing Magna Range Plug I E 3.25 OD x 2.984 ID TVD 0' 4,824' Set at 8,608.5' =1 C Dump Bail 12.5'of cement to 8,596' . is= 12-1/4"hole cmt w/1,800 sks of Class G , Production Casing ►� 7" N-80/P-110 26/29ppf :. Baker SC-1 Packer T� Bottom Velocity String 4"ID @ 8,607' MD 0' 9,697' 1-314" QT-700 0.125"wall i TVD 0' 8,805' (***Pulled 8/21/13***) 7" N-80 26 ppf 0'-4,700' Perforations: 7" N-80 26 ppf 4,700'-6,300' B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) =1 /I- C 7" P-110 26 ppf 6,300'-9,697' c 8-1/2"hole cmt wl 730 sks of Class G 2.313"Otis X Nipple - Well Screen @8,894' NO4.5"OD x 2.438"ID Gravel Pack Screen f Perforations: I c 4112 LTo-80 Bo17ttom B-28 8,956'-8,976'[8,085'-8,104'TVD)(11/21/88) C MD 8,607' 8,984' Model D Packer ND 7,747' 8,110' II -i / 3.25"ID @ 8,984' Capillary Tubing Ir/ Gravel packed 3/8" 2205 Stainless Steel Top Bottom MD 0' 0' a •; Cast Iron Bridge Plugs TVD 0' 0. 0 i. .L--7:: . ' @ 8,994'MD, 9,001'MD, 9,003'MD (***Pulled 03/04/2013***) I Perforations(Squeezed): is - ,. MD Tree cxn:6-1/2"Otis - Sterling B1 . 5,300'-5,310'(Sqzd 6/30/67) TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD:8,994' Sterlign B3 • 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Csg(6/20/67 CBL)-5,230' TVD:9,388' TVD:8,120' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 . 5,655'-5,675'(Sqzd 11/11/88) Well Name&Number: Beaver Creek-1A Lease: A-028083 County or Parish:_ Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: _ 1.8°/100 ft @ 2,300' Angle/Perfs: 29°-.19° Maximum Deviation: 39°@ 4,450' Date Completed:_ 02/13/96 Ground Level(above MSL): 153.2' RKB(above GL): 14.8' Revised By: Stan Porhola Downhole Revision Date: 9/12/2013 Schematic Revision Date: 9/30/2013 BPCad-1IA A PROPOSED ttiIcorpAlaska,1.t,C 117' FSL, 1,338' FEL, SCHEMATIC Sec. 33, T7N, R10W, S.M. API#: 50-133-20006-00 Conductor Property Des: A-028083 J ` 20" H-40 94 ppf KB Elevation: 153' (16.8'AGL) lop Spud Date: 3/13/1967 ih: MD 0' 526' TD Reached: 6/13/1967 ND o' 526' Lat: 0"..., 26"hole cmt w/1,000 sks of Class G Long: (►S Bridge Plug et at 5,250' Tubing String Kg', 3-1/2" L-80 9.3 ppf Cement Retainer 2.984"ID Top Bottom Set at 7,725' MD 7,764' 7,890' . , • TVD 6,998' 7,101' Perforations: re✓ - MD MD TVD TVD ��' -"" r Surface Casing t - Baker 80-40 Anchor on Baker B-18U 8,087'-8,107' 7,627'-7,284'(9/12/96) 13-318" J-55 61 ppm 84 SAB 40x30 Permanent Tom Bottom B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) .2.__..,........... Packer MD 0' 2,220' B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) I, a 3.25"ID @ 7,764' ND 0' 2,220' 8-20 8,284'-8,312' 7,444'-7,470'(9/4/96) B-21 8,374'-8,404' 7,528-7,556'(5/10/96) i'1 2.813"Camco X Nipple 18-518"hole cmt w/3,500 sks of Class G B-22 8,439'-8,459' 7,589'-7,608'(5/8/96) @ 7,815' B-23M 8,500'-8,520' 7,646'-7,665'(3/15/96) ' B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) q ) '' 2.813"Camco X Nipple Intermediate Casing @ 7,853' 9-5/8" N-80 40/43.5 ppf Top Bottom MD 0' 5,130' Thru-Tubing Magna Range Plug = c Wireline Re-entry Guide ND 0' 4,824' Set at 8,608.5' 1E @ 7,890' Dump Bail 12.5'of cement to 8,596' c 3.25 OD x 2.984 ID 12-1/4"hole cmt w/1,800 sks of Class G =, e Production Casing • 7" N-80/P-110 26/29 ppf Velocity String �= - s Baker SC-1 Packer Top Bottom g, i 4"ID @ 8,607' MD 0' 9,697' (1-3Fulled 8121 QT-7001 0.125"wall l ■ ND 0' 8,805' 14 II 7" N-80 26 ppf 0'-4,700' Perforations: C 7" N-80 26 ppf 4,700'-6,300' B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) 7" P-110 26 ppf 6,300'-9,697' =311 1 8-1/2"hole cmt wl 730 sks of Class G 2.313"Otis X Nipple . Well Screen @ 8,894' 4.5"OD x 2.438"ID Gravel Pack Screen f Perforations: i„ 4112 Toa BoL-80 17ttom B-28 8,956'-8,976'[8,085'-8,104'TVD)(11/21/88) =I a- MD 8,607 8,984' Model D Packer D 7,747' 8,110' " N I Lr/ / 3.25"ID @ 8,984' Capillary Tubing 3/8" 2205 Stainless Steel [!, Gravel packed Top Bottom MD 0' 0' `; Cast Iron Bridge Plugs TVD 0' 0' it @ 8,994'MD, 9,001'MD, 9,003'MD ("`Pulled 03/04/2013**") i, Perforations(Squeezed): MD Tree cxn:6-1/2"Otis - Sterling B1 5,300'-5,310'(Sqzd 6/30/67) TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD:8,994' Sterlign B3 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Cs (6/20/67 CBL)-5,230' D:9,388' D:8,120' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 5,655'-5,675'(Sqzd 11/11/88) Well Name&Number: Beaver Creek-1A _ Lease:_ A-028083 County or Parish: Kenai Peninsula Borough _ State/Prov: Alaska Country: USA Angle @KOP and Depth: 1.8°/100 ft @ 2,300' Angle/Perfs: 29°-119° _ Maximum Deviation: 39°@ 4,450' Date Completed: 02/13/96 Ground Level(above MSL): 153.2' RKB(above GL):_ 14.8' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/5/2013 . .. .. 14 Beaver Creek Moncla #405 BOP 12/05/2013 Ililrnrp vr.►a.I.I.(: f 3.98' - Hydrilo GK 11"-5000 111 iii iii 111111 mime III '11' I 06U 4.54' rPii:ll m - 2 7/8 -5 variables II 11"- 5000 0 mama , I H Blind ill Illlliii t ® n 2 1/16 5M Choke and Kill • Valves Ti, 111 III 111 111,1 ] . 1 T : 1 €1 • 200' 1r liIjjIl 111 . 4 •ll Beaver Creek Field BCU-1A :u.t.p AI.aka.t.I.c: 08/12/2013 e Beaver Creek Tubing hanger,FMC-TC-1A- BC 41A EN-CCL,11 X 3''A EUE lift and 20 X133/8 X 95/8X7 X334 susp,w/3"TypeH BPV X 1% profile,T seal neck%control line port Tree cap,Otis,3 1/8 5M FE X 6''A Otis Quick Union 11 iduiVirtiel IIIIIIIIII •.r� eyl 6 4. .c'•'��y100 Valve,Swab, MA C Ja,''" 57' xxv4,-o��• WKM-M,3 1/8 5M FE, �4'gyp• J , 4'pF HWO,DD trim Lj i.• 4. .�• I, 5, 5$ J0•e o 1.1 r*1 •IT11 P} i —ill f- ( ?). i 0 /- - 44' IC i ` Valve,upper master, •,o WKM-M,3 1/8 5M FE, (th G HWO,DD trim �. �� uu FC'' c�.`�F untTiuer `1,:r F ,,,,, ro OOa. 4,-4,,;,- Ja ryti� c. Coiled Tubing head,Vetco = --- •.1' - -4 ...I,004•co Gray,3 1/8 SM FE X n.�'�. JV + Nis aha 3 1/8 5M stdd,w/1- I Coiled tubing hanger,VG- ' f i/... . :I' . CTM,3"nominal X1.900 lord susp X 3"GS Baker Fish Neck Lift,w/2"Type H BPV 1.1 .r and grapple for 2"coil I MI 1111101;Mao c•, a Valve,master,WKM-M, , 3 1/8 SM FE,HWO,DD O'_ trim I u .�u=y 4i Adapter,FMC-A4-CCI, 1 I B 11 5M stdd X3 1/8 SM,prepped for 7.115"extended neck Tubing head,FMC-TC-60, E 11 5M X11 SM,w/ • ^1;Y l"+ 2-21/165M EFO,BG • I • I_1I • bottom lil 1.1 Valve,VG-100,2 1/16 5M FE, � r' HWO -.•L_ Ill *�- 1.1 'i: Casing spool,CIW-WF,11 SM X A Valve,CIW-F,2 1/16 5M FE, 135/83M,w/2-21/16 SM 550, 1.� I,!i W. �■1. \ . HWO X bottom Pref ■I1III Ir.x 1:ItIn-f•_ 1.; Ili i • Casing spool,CIW-WF,21%2M1.1tl: 1 X135/83M,w/2-21/165M 1.1 / I11 Valve,CIW-F,21/165M FE, EFO,X bottom prep - - ,0 HWO II • SIIII��A� 11 i.1' 101rIli , 1.1 Casing head,CIW-WF,21%2M Xlir 1111 SOW,w/2-21/162M EFO it, = ni Valve,CIW-F,2 1/16 2M FE, illinlit HWO _ .r 0114 ) Pillir`4$ii4u? MI- STATE OF ALASKA . ALAIDA OIL AND GAS CONSERVATION COMMIION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other P] Pull Velocity String Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development IS Exploratory ❑ 167-009 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20006-00• 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 ' Beaver Creek Unit(BCU)01-A , 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas-Beluga Gas 11.Present Well Condition Summary: E" Total Depth measured 10,296 feet Plugs measured 8,994 feet true vertical 9,388 feet Junk measured N/A feet or f 0 3 20 Effective Depth measured 8,994 feet Packer measured 7,764 feet t ', . true vertical 8,120 feet true vertical 6,998 feet `� Casing Length Size MD TVD Burst Collapse Structural Conductor 511' 20" 526' 526' 1,530 psi 520 psi Surface 2,205' 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,115 9-5/8" 5,130' 4,819' 5,750 psi 3,090 psi Production 9,682' 7" 9,697' 8,805' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 7,890'MD 7,101'ND Baker SAB Packers and SSSV(type,measured and true vertical depth) Perm Pkr 7,764'MD 6,998'TVD N/A;N/A (typ P ) 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 0 380 423 Subsequent to operation: 0 0 0 380 542 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development® ' Service U Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas El • WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-441 Contact Stan Porhola Email sporholac hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ' / ., Phone 907-777-8412 Date c�/3C.'I f RBDMS OCT 11 24 Form 10-404 Revised 10/2012 4,-,- „ff, 7, / Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-01A 50-133-20006-00 167-009 8/13/13 9/12/13 Daily Operations: 08/13/2013 -Tuesday RU slickline unit. RIH(1) w/ 1.25" GR to locate and tag XN nipple profile at 8,332'. RIH(2)w/ 1.27" brush to clean profile. RIH(3) w/ P plug with 1.258" packing pinned with steel pin. Attempt to set plug. Pin didn't shear. RIH(4)w/same pinned with brass. Set plug. Sheared off. POOH. Blow down V string to atmosphere. V string is dead. RD slickline unit and leave loc. 08/19/2013 - Monday Lay liners under spare coil, coil ops unit, and pump units. Lay liner under flow back tank. Spot choke skid in tank containment. ND tree cap. NU coil BOPs. Build containment around flowback tank using 12" x12" beams and Swanson River containment rack. Install 2" flowback iron from flowline to choke skid and to flowback tank. Install 2" hard line to BOPs and T into flowback iron w/isolation valves. Stab coil into injector. Fuel equipment. Secure wellhead, equipment, and location for the night. Leave loc. 08/20/2013-Tuesday PU Injector assembly. PU 10' of lubricator. Prep coil end. Carry injector to WH. Function test BOPS. OK. Prime up lines and establish circulation to flowback tank. Preform draw down test on accumulator. Test good. PTest BOP shell P- low P 250 psi/high P 4,000 psi. Test good. (Witness waived by Jim Regg, AOGCC). Close upper B/S rams. PT 250 low/4,000 psi high. Test good. Close lower B/S rams. PT 250 low/4,000 psi high. Test good. RIH w/coil. Close slips. Preform push/pull test. Good. Close pipe rams. PT rams 250/4,000 test. Stand back lubricator. Set down injector. Vac rain out of sumps on equipment. Fuel equipment with LSDiesel from Beaver Creek. Prepare for pulling Vstring in the morning. Notify GE Oil and gas and Baker. Secure well and all flow lines. Close choke valves. Secure equipment and location for the night. Sign out and leave loc. 08/21/2013 -Wednesday PU injector and 10' of lubricator. Install external coil grapple. Pull test to 27K. Pressure test BHA connection to 3,600 psi. Carry injector to wellhead. PTest shell to 3,500 psi. RIH 10'. Set down on hanger. PU to 26K. GS latched in hanger. Slack off to 18K-string weight. Back out hanger lock down screws. PU to 31K to pull hanger free. PUH into lubricator. Close slips. Pull test. Close pipe rams. Bleed lubricator pressure. Walk injector up coil. Cut coil. LD Baker GS and MHA. Prep coil ends. Install Dual Dimple on. Walk injector back down coil. Pull test dimple on to 25.6K. Unlock slips and POOH w/velocity string. OOH. Close swab and upper master valve. Cut bleed hole in coil. Drain into tote. Cut BHA off coil and LD. Set injector down. RD injector assembly. ND BOP's. Break out iron and load injector and BOP. Roll up hydraulic lines. Secure well and loc. Ready to move out in morning to BC-18. 09/11/2013 -Wednesday RU Priority E line unit. PU lubricator. MU tool string-RS, 1-11/16" x 10 stem, bow spring cent, CCL, bow spring centralizer. RIH to 8,616.5'. Log correlation pass. POOH. RIH with CIBP. Get on depth to correlation log. Set CIBP at 8608.5'. POOH. RD Priority. RU Pollard slickline to dump cement. PU lubricator. PU tool string w/2-1/2"x10' bailer. Mix 4 gals cement. RIH(1) w 2-1/2" bailer to 8,608'. Mix 4 gals cement. RIH(2)w/2-1/2" bailer to 8,608'. RIH(3)w/2-1/2" bailer to 8,608'. RD for the night. 09/12/2013 -Thursday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-01A 50-133-20006-00 167-009 8/13/13 9/12/13 Daily Operations: RU Pollard slickline to dump cement. PU lubricator. PU tool string w/2-1/2" x 10' bailer. Mix 5 gals cement. RIH(1) w/2- 1/2" bailer to 8,620' SLM. RIH(2)w/2-1/2" bailer to 8,620' SLM. Mix 5 gals cement. RIH(3)w/2-1/2" bailer to 8,620'SLM. 2-1/2" bailer 8,620'SLM. RIH w/swab cups and swab well. RD for the night. RIH(4) w/21 ba a to8,6 O S • • • BC-1 A ACTUAL Pad 1A nih.,,r.„ \Ia'ka.i,ii 117' FSL, 1,338' FEL, SCHEMATIC Permit#: 167-009 ' Sec. 33, T7N, R10W, S.M. API#: 50-133-20006-00 Conductor Property Des: A-028083 ` 20" H-40 94 ppf KB Elevation: 153' (16.8'AGL) Top Bottom Spud Date: 3/13/1967 MD o' Szs' TD Reached: 6/13/1967 rvD o' szs' Lat: 26"hole cmt w/1,000 sks of Class G Long: Tubing String 3-1/2" L-80 9.3 ppf Camco Injection Mandrel 2.984"ID Top Bottom 5.25"OD @ 898' 0 MD 0' 7,890' TVD 0' 7,101' Perforations: - Baker 80-40 Anchor on Baker r 1 84 SAB 40x30 Permanent MD MD TVD TVD r P-.' : Packer Surface Casing B-18U 8,087'-8,107' 7,627'-7,284'(9/12/96) 3 25"ID @ 7,764' 13-3/8° -55 s1 ppf B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) r Top Bottom B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) " 1 MD 0' 2,220' ( ) t r r 2.813"Camco X Nipple TVD 0' 2,220' 1 B-20 8,284'-8,312' 7,444'-7,470'(9/4/96) t . @ 7,815' B-21 8,374'-8,404' 7,528-7,556' 5/10/96 ° II 18-5/8"hole cmt w/3,500 sks of Class G B-22 8,439'-8,459' 7,589'-7,608'(5/8/96) s ( ) A l) ]I \ 2.813"Camco X Nipple B-23M 8,500'-8,520' 7,646'-7,665'(3/15/96) y @ 7,853' B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) Intermediate Casing C 9-5/8" N-80 40 143.5 ppf Wreline Re-entry Guide Top Bottom " =It C @ 7,890' MD 0' 5,130' Thru-Tubing Magna Range Plug Set at 8,608.5' C 3.25 OD x 2.984 ID TVD 0' 4,824' Dump Bail 12.5'of cement to 8,596' C � r 12-1/4"hole cmt wl 1,800 sks of Class G . Production Casing y��t4 7" N-80/P-110 26/29 ppf Velocity String r a • , Baker SC-1 Packer Tom Bottom 1-3/4" QT-700 0.125"wall r , 4"ID @ 8,607' MD o' 9,697, (***Pulled 8/21/13"') E TVD 0' 8,805' 7" N-80 26 ppf 0'-4,700' Perforations: 7" N-80 29 ppf 4,700'-6,300' B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) 7" P-110 29 ppf 6,300'-9,697' � c 8-1/2"hole cmt w/730 sks of Class G 2.313"Otis X Nipple Well Screen @ 8,894' ( 4.5"OD x 2.438"ID Gravel Pack Screen Perforations: C 4-112" L-80 17 ppf Tom Bottom B-28 8,956'-8,976'[8,085'-8,104'TVD)(11/21/88) c MD 8,607' 8,984' Model D Packer TVD 7,747' 8,110' 3.25"ID @ 8,984' Capillary Tubing Gravel packed 3/8" 2205 Stainless Steel _ . .t1 . Top Bottom MD 0' 0' 1 Cast Iron Bridge Plugs TVD 0' 0' @ 8,994'MD,9,001'MD, 9,003'MD ("'Pulled 03/04/2013***) _ ' ii. ; Perforations(Squeezed): - MD Tree cxn:6-1/2"Otis - Sterling B1 5,300'-5,310'(Sqzd 6/30/67) TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD: 8,994' Sterlign B3 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Csg(6/20/67 CBL)-5,230' TVD:9,388' TVD:8,120' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 5,655'-5,675'(Sqzd 11/11/88) • Well Name&Number: Beaver Creek-1A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 1.8°/100 ft @ 2,300' I Angle/Perfs:l 29°-.19° Maximum Deviation: 39°@ 4,450' Date Completed: 02/13/96 Ground Level(above MSL): 153.2' RKB(above GL): 14.8' Revised By: Stan Porhola Downhole Revision Date: 9/12/2013 Schematic Revision Date: 9/30/2013 iiimmoN■ii■111■1111■ ,�O��j: THE STATE Alaska Oil and Gas F °f 1sK 1 ��, ® l Conservation Commission 1 GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Stan Porhola • Operations Engineer SCANNED N 0 v 2 5 `013 7 0 0 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit#1A Sundry Number: 313-441 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Cathy P. ' oerster Chair DATED this ' day of August, 2013. Encl. �e,�; E _ STATE OF ALASKA AUG tP. ALASKA OIL AND GAS CONSERVATION COMMISSION Tu /2D' QT'S 1)5��3 APPLICATION FOR SUNDRY APPROVALS AO G CC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations El • Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. Pull Velocity String 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. • Hilcorp Alaska,LLC Exploratory ❑ Development El. 167-009 3.Address: 6.API Number. 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ • Anchorage,Alaska 99503 50-133-20006-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Beaver Creek Unit(BCU)#1A ' Will planned perforations require a spacing exception? Yes ❑ No 151 1 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 • Beaver Creek/Beluga Gas Pool • 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,296' • 9,388' . 8,994' 8,120' 8,994' _ N/A Casing Length Size MD TVD Burst Collapse • Structural Conductor 511' 20" 526' 526' 1,530 psi 520 psi Surface 2,205' 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,115' 9-5/8" 5,130' 4,824' 5,750 psi 3,090 psi Production 9,682' 7" 9,697' 8,805' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 7,890' Packers and SSSV Type: Baker SAB Perm Packer;N/A Packers and SSSV MD(ft)and ND(ft): 7,764'MD/6,998'ND;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development U ' Service U 14.Estimated Date for 15.Well Status after proposed work: 08/19/13 Commencing Operations: Oil ❑ Gas El . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporholatCl_hiIcorp.com Printed Name Stan Porhola Title Operations Engineer Q Signature � 1 Phone 907-777-8412 Date U /1 /3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 4 tT� 313,40 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,------ 80r l& AL 3coo fis RBDMS SEP 17 i ;a Spacing Exception Required? Yes ❑ No Or Subsequent Form Required: / 0 -1014 o APPROVED MM S 8 /5—l ✓ Approved by: � � A� COMMISSIONER THE COMMISSION Date: C/ )4, ci.19.1 n Submit Form and Form 10-403(Re ised 10/2012) Approv pRalie f�oo Laths from the date of approvaI� /Ate m nts in Duplicate lv' ` T • • • �n"mA'Fp4 q[4i� y� gLgq i' E` 3 i. Hilcorp Alaska,LLC AUG u 1 3 2013 Post Office Box 244027 Anchorage,AK 99524-4027 ,°6(";g ,t°�* " 3800 Centerpoint Drive x"41 J' ',J Suite 100 Anchorage,AK 99503 Phone: 907/777-8412 August 12, 2013 Fax: 907/777-8310 Cathy Foerster, Chairman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Coiled Tubing Work at Beaver Creek and Sterling Fields Dear Commissioner Foerster: Attached for your review includes proposed Coiled Tubing work for the Beaver Creek and Sterling Gas Fields. The coiled tubing work involves pulling a coiled tubing velocity string, fill cleanouts, and nitrogen lift. This work typically does not require sundry approval, however we are including a sundry application for the initial work proposed on Beaver Creek #1A (PTD 167-009) to pull the velocity string. Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial BOPE test. Below is a list of the wells and the proposed coiled tubing work: Beaver Creek#1A (PTD 167-009) Pull Coiled Tubing Velocity String/Plugback Beaver Creek#18 (PTD 208-185) Fill Cleanout Beaver Creek#10 (PTD 200-192) Fill Cleanout Beaver Creek#11 (PTD 203-025) Fill Cleanout Sterling Unit 41-15RD (PTD 207-088) Nitrogen Lift If you need any additional information, you may contact me at 907-777-8412. Sincerely, HILCORP ALASKA, LLC Stab Porhola Operations Engineer stp Attachments cc: Chad Helgeson • Well Prognosis Well: BCU-1A Hilcorp Alaska,LLC Date:8/12/2013 Well Name: BCU-1A API Number: 50-133-20006-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: August 19th, 2013 Rig: N/A Reg.Approval Req'd? None Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 167-009 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,695 psi @ 7,748' TVD (Based on static survey March 2013 run to 8,608' MD) Maximum Expected BHP: — 1,695 psi @ 7,748'TVD (Based on static survey March 2013 run to 8,608' MD) Max. Allowable Surface Pressure: —920 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft) Brief Well Summary Beaver Creek Unit#1A was originally planned as a relief well in 1967 to the Beaver Creek#1, but was eventually completed as a gas well to target gas sands in the Sterling and Beluga formations. A workover in 1996 ran gravel pack screens across the lowest perforated intervals, squeezed off the remaining Sterling perforations, and ran a tubing and packer above other Lower Beluga.The well is currently producing sporadically at very low . rates. Notes Regarding Wellbore Condition • Well is currently shut-in with 415 psi of tubing pressure. r • Wellbore deviation at the perforations is less than 30 degrees. Maximum deviation is 39 degrees. . OBJECTIVE OF WORKOVER Pull coiled tubing velocity string and plugback the Lower Beluga sands(B-26 and B-28)to isolate water production and bring the well back on production. . Slickline Procedure: 1. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. 2. RU 1.00" bailer. 3. RIH and tag fill at+/-8,600' MD. POOH. a. Collect sample of fill. 4. RU 1.25" PX plug. S�`'�-- 5. RIH and set PX plug in PXN profile at 8,296' MD. 6. Bleed off tubing pressure to confirm PX plug set. 7. RD Slickline. 8. Turn well over to production. Coiled Tubing Procedure: i • Well Prognosis Well: BCU-1A � !corn Alaska,LLC ' 143/1 ate•8/12/2013 9. MIRU Coiled Tubing, PT BOPE to 3,000 psi Hi 250 Low. 10. RU 1.75" coil BHA. 11. RIH and latch onto coiled tubing velocity string hanger. 12. POOH with 1.75"coiled tubing velocity string from 8,296' MD. 13. RD Coiled Tubing. 14. Turn well over to production. Slickline Procedure: 15. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. 16. RU 2.50"gauge ring. 17. RIH and tag fill at+1-8,600' MD. POOH. 18. RU 2.50" bailer. 19. RIH and bail fill as necessary to make enough rathole for plugback. 20. RD Slickline. 21. Turn well over to production. A-line Procedure: 22. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 23. RU 1.7"thru-tubing Bridge Plug. j P 24. RIH and set thru-tubing Bridge Plug at+1-8,585' MD.V a. Set plug between bottom perf of B-23L(8,567' MD)and top of SC-1 packer(8,607'). b. Last known fill depth is 8,600' MD. 25. RD E-line. 26. Turn well over to production. Slickline Procedure: 27. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. 28. RU 2.50"gauge ring. 29. RIH and tag plug at+/-8,585' MD. POOH. GMT 30. RU 2.50" bailer. om 31. RIH and dump bail 5'of cement on top of plug./ 32. RD Slickline. 33. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Current Wellhead 4. Coiled Tubing BOPE . , . . . EL BC-1 A ACTUAL Pad 1A n;l,,,,.,, „„:,.i.i.f 117' FSL, 1,338' FEL, SCH EMATIC Permit#: 167-009 Sec. 33, T7N, R10W, S.M. API#: 50-133-20006-00 Conductor Property Des: A-028083 J ` 20" H-40 94 ppf KB Elevation: 153' (16.8'AG L) T-O B526otto'm Spud Date: 3/13/1967 6J. TVD 0'MD o' Szs' TD Reached: 6/13/1967 Lat: 26"hole cmt w/1,000 sks of Class G Long: Tubing String 3-112" L-80 9.3 ppf Camco Injection Mandrel 2.984"ID Top Bottom 5.25"OD @ 898' p 1 MD 0' 7,890' TVD 0' 7,101' Perforations: Baker 80-40 Anchor on Baker MD MD TVD TVD _ 84 SAB 40x30 Permanent Surface Casing Packer 13-3/8" J-55 61 ppf B-18U 8,087'-8,107' 7,627'-7,284'(9/12/96) - 3.25"ID @ 7,764' lop Bottom B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) , r - MD 0' 2,220' „ B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) . , 2.813"Camco X Nipple TVD 0' 2,220' B-20 8,284'-8,312' 7,444'-7,470'(9/4/96) . @ 7,815' B-21 8,374'-8,404' 7,528-7,556'(5/10/96) . " �" 18-5/8"hole cmt w/3,500 sks of Class G B-22 8,439'-8,459' 7,589'-7,608'(5/8/96) - II ll ` 2.813"Camco X Nipple B-23M 8,500'-8,520' 7,646'-7,665'(3/15/96) . @ 7,853' Intermediate Casing B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) " 9-5/8" N-80 40/43.5 ppf Wireline Re-entry Guide Top Bottom Tagged fill @ 8,600'(3/10/13) c @ 7,890' MD 0' 5,130' w/1.00"Blind Box A IE 3.25 OD x 2.984 ID TVD 0' 4,824' c IC Velocity String c 12-1/4"hole cmt w/1,800 sks of Class G 1-3/4" QT-700 0.125"wall 1.40"ID Top Bottom MD 0' 8,296' f,r_,,r,: Production Casing TVD 0' 7,455' d 7" N-80/P-110 26/29 ppf 4S� Top Bottom 2.50"BHA w/: Grapple ( �� Baker SC-1 Packer MD 0' 9,697 10'Straight bar P t, r_ 4"ID @ 8,607' (1.135"No-Go)1.25"PXN nipple �' TVD 0' 8,805' 1.75"Re-ent sboe '__. - _ 7" N-80 26 ppf 0'-4,700' F'-6Th rations: € 7" N-80 26 ppf 4,700'-6,300' B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) 7" P-110 26 ppf 6,300'-9,697' C 8-1/2"hole cmt w/730 sks of Class G 2.313"Otis X Nipple Well Screen 8 @ 8,894' 4.5"OD x 2.438"ID Gravel Pack Screen 4-112" L-80 17 ppf Perforations: C Tom Bottom B-28 8,956-8,976'[8,085'-8,104'TVD)(11/21/88) ( c MD 8,607' 8,984' 1 IF Model D Packer TVD 7,747' 8,110' Capillary Tubing / Gravel packed 3/8" 2205 Stainless Steel - 1 984' � 3.25"ID @8, Top Bottom _" ': � MD 0' 0' '7r Cast Iron Bridge Plugs TVD 0' 0' @ 8,994'MD, 9,001'MD, 9,003'MD ("""Pulled 03/04/2013"') Perforations(Squeezed): MD - Sterling B1 5,300'-5,310'(Sqzd 6/30/67) Tree cxn:6-1/2"Otis TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD: 8,994' Sterlign B3 . 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Csg(6/20/67 CBL)-5,230' TVD:9,388' TVD:8,120' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 - 5,655'-5,675'(Sqzd 11/11/88) Well Name&Number: Beaver Creek-1A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 1.8°!100 ft @ 2,300' I Angle/Perfs:l 29°-+19° Maximum Deviation: 39°@ 4,450' Date Completed: 02/13/96 Ground Level(above MSL): 153.2' RKB(above GL): 14.8' Revised By: Stan Porhola Downhole Revision Date: 3/10/2013_ Schematic Revision Date: 8/12/2013 . , . . in BC-1A PROPOSED• Pad 1 A ,Iih rp „aska.I,LC 117' FSL, 1,338' FEL, SCHEMATIC Permit#: 167-009 Sec. 33, T7N, R10W, S.M. API#: 50-133-20006-00 Conductor Property Des: A-028083 J ` 20" H-40 94 ppf KB Elevation: 153' (16.8'AGL) Top Bottom Spud Date: 3/13/1967 Lk MD 0' 526' TVD 0' 526' TD Reached: 6/13/1967 1: Lat: 26"hole cmt w/1,000 sks of Class G Long: 1' Tubing String 3-1/2" L-80 9.3 ppf Camco Injection Mandrel 2.984"ID Top Bottom 5.25"OD @ 898' p I MD 0' 7,890' TVD 0' 7,101' Perforations: Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent MD MD TVD TVD , Surface Casing Packer 13-3/8" J-55 61 ppf B-18U 8,087'-8,107' 7,627-7,284'(9/12/96) lit '� 3.25"ID @ 7,764' Tom Bottom B-18L 8,118'-8,148' 7,294'-7,321'(9/10/96) 'Ii /^` MD 0' 2,220' B-19 8,183'-8,223' 7,352'-7,388'(9/6/96) h ii' 2.813"Camco X Nipple TVD 0' 2,220' B-20 8,284'-8,312' 7,444'-7,470'(9/4/96) . @ 7,815' B-21 8,374'-8,404' 7,528-7,556'(5/10/96) " °� 18-5/8"hole cmt w/3,500 sks of Class G B-22 8,439'-8,459' 7,589'-7,608'(5/8/96) II II ` 2.813"Camco X Nipple B-23M 8,500'-8,520' 7,646'-7,665'(3/15/96) @ 7,853' B-23L 8,527'-8,567' 7,672'-7,710'(11/24/88) Intermediate Casing �� C 9-5/8" N-80 40/43.5 ppf Wreline Re-entry Guide Top Bottom =111 IC @ 7,890' MD 0' 5,130' Thru-Tubing Bridge Plug Set at 8,5r85' - 7 C 3,25 OD x 2.984 ID TVD 0' 4,824' S --.1 Dump Bail 5'of cement to 8,580' c C 12-1/4"hole cmt w/1,800 sks of Class G Tagged fill @ 8,600'(3/10/13) °- w/1.00"Blind Box ►�;fap+.; Production Casing 7" N-80/P-110 26/29 ppf Baker SC-1 Packer Top Bottom Velocity String MD 0' 9,697' 1-314" QT-700 0.125"wall ' _ 4"ID @ 8,607' TVD 0' 8,805' ***Proposed to Pull*** 7" N-80 26 ppf 0'-4,700' Perforations: I 0 7" N-80 26 ppf 4,700'-6,300',, B-26 8,797'-8,817'[7,931'-7,950'TVD)(11/21/88) l 7" P-110 26 ppf 6,300'-9,697 8-1/2"hole cmt w/730 sks of Class G 2.313"Otis X Nipple Well Screen @ 8,894' -:.:11 4.5"OD x 2.438"ID Gravel Pack Screen .I C ,0 t_k' r. 4-1/2" L-80 17 ppf Perforations: Top Bottom B-28 8,956'-8,976'[8,085'-8,104'TVD)(11/21/88) = i c MD 8,607' 8,984' Model D Packer TVD 7,747' 8,110' " 3.25"ID @8,984' Capillary Tubing l Gravel packed 3/8" 2205 Stainless Steel f Top Bottom MD 0' 0' Cast Iron Bridge Plugs TVD 0' 0' @ 8,994'MD, 9,001'MD,9,003'MD (***Pulled 03/04/2013***) Perforations(Squeezed): MD Tree cxn:6-1/2"Otis Sterling B1 5,300'-5,310'(Sqzd 6/30/67) TD PBTD Sterling B2 5,430'-5,445'(Sqzd 11/12/88) MD: 10,296' MD:8,994' Sterlign B3 5,488'-5,520'(Sqzd 2/8/96) TOC 7"Csg(6/20/67 CBL)-5,230' TVD:9,388' TVD:8,120' Sterling B3 5,490'-5,540'(Sqzd 2/8/96) Sterling B4 5,655'-5,675'(Sqzd 11/11/88) Well Name&Number: Beaver Creek-1A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: 1.8°/100 ft @ 2,300' I Angle/Perfs:I 29°-.19° Maximum Deviation: 39°@ 4,450' Date Completed: 02/13/96 Ground Level(above MSL): 153.2' RKB(above GL): 14.8' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date:_ 8/10/2013 . , .. • . Beaver Creek Field BCU-1A 08/12/2013 IAileorp tla.ka.1.1.(: Beaver Creek Tubing hanger,FMC-TC-1A- BC#1A EN-CC.,11 X 3%EUE lift and 20 X 133/8 X 95/8X7 X371 susp,w/3"TypeH BPV X 1% profile,T seal neck%6 control line port Tree cap,Otis,3 1/8 5M FE X 6%Otis Quick Union•ild AVAINISTA -.Valve,Swab, !L" �� 1\ ' S‘41‘,,, ' WKM-M,31/85M FE, RH,s='� ,�, p�O JT,3�'\,t,x HWO,DD trim �uu 4�Q , ' �i muT ur 4e' e$ili i 0.,e...1:411 0 : i i 1 —.ciao—ma Valve,upper master, .�.� WKM-M,3 1/8 5M FE, �u� '�. \ HWO,DD trim ►^ .# uu� F,. pot FF".�. ,•Ta., yC9.' S,Gy O,i• Ja y,1\1 Omit° Jx�ry'�\.',k O Coiled Tubing head,Vetco - ti O ' oQ Gray,3 1/8 SM FE X -MN'1]. J(14•40 �.E 0"° 31/85M stdd,w/1- �,� 2 1/16 5M SS0 !IL!CMubmghanger,VG-Neck Lift,w/2"Type H BPV and grapple for 2"coil MIMI lin ewe., Valve,master,WKM-M, litA0 "-J 3 1/8 5M FE,HWO,DD trim �wu° 7� Adapter,FMC-A4-CCL, --" 11 5M stdd X3 1/8 SM,prepped for 7.115"extended neck Tubing head,FMC-TC-60, _ _E��„ 11 5M X11 5M,w/ �- ` � -,iii 2-2 1/16 5M EFO,BG bottom 1L-11 . 'I li.D Valve,VG-100,2 1/16 5M FE, s HWO *..4 /-,■''O .W. • KW' ,..I.1 1114W 02h7 III ii Irl'e el 011114-. la T+� Casing spool,CIW-WF,11 5M X 11i _ Valve,CIW-F,21/16 5M FE, 135/83M,w/2-21/165MSS0, - HWO X bottom prep / �i.i A Ill s o u Casing spool,CIW-WF,2134 2M 11,,,X 135/83M,w/2-21/165M 1.1 iii Valve,CIW-F,21/16 SM FE, EFO,X bottom prep • - � ,,,�+++�� ,� HWO i III . 1n , 1.1 IIII = Casing head,CIW-WF,211142M X l . SOW,w/2-21/162M EPO iri — Valve,CIW-F,2 1/16 2M FE, - - i re f' HWO co. 1..0,.7-Z1,04... 1. IOW M • • , _ • • Beaver Creek Field BCU-1A 08/12/2013 il,k.,r,, v...k3.1.1(. Beaver Creek#1A 20"x 13-3/8"x 9-5/8" x 7"x 3%:"x 1-a/" Coil Tubing BOP Lubricator to injection head r ° 1 •1.1.I Blind/Shear 4 1/16 10M _— Blind/Shear 1.111-1 011111111 Blind/Shear _ ■ G _ MIL, Blind/Shear (.I.'•BI - • 0° _ 1411 Pipe/Slip • _• Pipe/Slip 1011 am. F.M11 14111/1=111 OF 1 IIIIII[ llNN!I C1 iI'1'�_�■6.1 10 0 li$�I 0 111" - - .•. sal . _ - - Mud Cross .— 4 1/16 10M X2 1/16 50M Crossover spool Outlet 41/1610M X3 1/8 5M w/4-21/1615M full opening plug valves 4,,' yr\ Valve,Swab, �4C\�� e�4e'�y�04` -4e"‘ o9et WKM-M,3 1/8 5M FE, `— • � O, Je �ti,Z,P HWO, DD trim (✓ �'E-�� ti01' , uu ("3:_,.e4'.e`. ..nT rte. �. ■ is • ..,r. •., Valve,upper master, .,..T.,,WKM-M,3 1/8 SM FE, ou� �C+i \ HWO,DD trim *�V..�Cam' v 4"' •�t`ad 4<'' m.`Ti m \,ey1`ybyCr� e e 0 ,c5) Coiled Tubing head,Vetco Gray,3 1/8 5M FE X ;,�, ,� • 34.��eo 3 1/8 5M stdd,w/1- .� 2 1/16 5M SSO I :110. i Coiled tubing hanger,VG- - ■ / {.. I O CTM,3"nominal X 1.900 � •/ ��• lOrd susp X 3"GS Baker Fish i Neck Lift,w/2"Type H BPV MI as and grapple for 2''coil mo^r:r K•UU Valve,master,WKM-M, 0�(:� 3 1/8 5M FE,HWO,DD _ trim �u• U� ��iTinr Adapter,FMC-A4-CCL, 11 5M stdd X3 1/8 5M,prepped for 7.115"extended neck , , e • BC-18 ACTUAL Pad 3 1,055' FNL, 1,628' FWL, SCHEMATIC Ilileorp Alaska,LI.0 Sec. 34, T7N, R10W, S.M. Permit#: 208-185 Conductor API#: 50-133-20584-00-S1 X56 129.25ppf Prop.Des: A-028083 Jj Top Bottom KB elevation: 181' (21'AGL) MD 0' 101' Latitude: 60°39' 29.533"N ND 0' 101' Longitude: 151°01' 11.195'W X: 317,475 (NAD 27) T. 2,433,986 (NAD 27) Surface Casing Spud: 1/18/2009 04:00 hrs 13-3/8" K-55 68 ppf BTC TD: 2/5/2009 13:30 hrs Top Bottom MD 0' 2,097' Rig Released: 2/12/2009 06:00 hrs TVD 0' 2,045' PA#: 891008868A 16"Hole Cmt wl 658 sks(290 bbls)of 12.0 ` - ppg,Type 1 cmt, 91 sks(40 bbls)cmt returned to surface Tree cxn:6-1/2"Otis ' i ,. Intermediate Casing G, i 9-5/8" L-80 40 ppf Butt TOC 3-1/2"Csg ,. Top Bottom CBL(2/10/09)-6,860' 'r, MD 0' 7,612' i?' TVD 0' 7,058' Excape System Details 12-114"Hole of Cmt wl 290 sks @ (171 15,8 bbls)of Class(45 bbls G Lead Class @ 10.5 G Tail ppg followed ppg.w/216 sks Module 1-no flapper ) Module 2-6 -reClosing flapper 67 sks(40 bbls)returned to surface Flappers MD(RKB): ; Module 6 = 8,040' Module 5 = 8,130' _ Production Tubing Module 4 = 8,480' - --" LB-20 3-1/2" L-80 9.3 ppf EUE Mod Module 3 = 8,579' -. I-= Top Bottom MD 0' 9,230' Module 2 = 8,715' TVD 0' 8,675' Module 1 = NA , I 8-1/2"Hole Cmt w/737 sks(154 bbls) q.- TVD G @ 15.8 ppg, 100%returns, Z- LB-21 Did not bump i Tag @ 8,108'MD(7/27/13) e_--------------=" 2.00"Drive Down Bailer } f`▪ ' Excape System Details ~ - 6 Excape modules placed along Chemical Injection Mandrel Y with 1 chemical injection mandrel @ 8,174'MD(RKB) {I -Red contol line fires modules 2-6 Tll(t - - control line fires Modules 1 ` I Y' &chemical injection mandrel 111.?. _____ The bottom @ 8,825'is open 8,190'Opens @ 9,545 psi ,� },r Beluga Perfs MD(RKB): ___ _VO 2-1/2" 12 spf=8,010'-8,020'(LB-20)(7/11/13) Module 6 = 8,020'-8,030' (Lower Beluga) tij 2-1/2"12 spf=8,020'-8,030'(LB-20)(7/11/13) Capillary Tubing % 2-1/2"12 spf=8,030'-8,037'(LB-20)(7/11/13) 3/8" 2205 Stainless Steel 2-1/2"12 spf=8,106'-8,110'(LB-21)(7/11/13) Top Bottom I Module 5 = 8,110'-8,120' (Lower Beluga) MD 0' 0' 2-1/2" 12 spf=8,110'-8,120'(LB-21)(7/11/13) TVD 0' 0' 2-1/2"12 spf=8,120'-8,140'(LB-21)(7/11/13) (***Pulled 04/08/2010***) Module 4 = 8,460'-8,470' (Lower Beluga) TD PBTD Module 3 = 8,559'-8,569' (Lower Beluga) 9,244' MD 9,193'MD Module 2 = 8,695'-8,705' (Lower Beluga) 8,689'TVD 8,638'TVD Module 1 = 8,825'-8,835' (Lower Beluga) Well Name&Number: Beaver Creek Unit#18 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:/ USA Angle @KOP and Depth: 2.7°/100 ft @ 941' 1 Angle/Perfs:l 2° Maximum Deviation:- 29°@ 4,352' Date Completed: 04/06/09 Ground Level(above MSL): 160' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 7/27/2013 Schematic Revision Date: 8/9/2013 . . • BC- ACTUAL Pad 3 10 flihorp.alaaka.LiA 943' FNL, 2,958' FWL, SCHEMATIC Permit#: 200-192 Sec. 34, T7N, R10W, S.M. API#: 50-133-20482-00 Conductor Property Des: A-028083 13-318" K-55 68 ppf KB Elevation: 179' (21'AGL) T� Bottom Spud Date: 3/26/2001 MD 0' 113' TVD 0' 113' TD Reached: 4/08/2001 Lat: 60°39'31.42"N Long: 151° 1'5.15"W Surface casing 7" L-80 23 ppf BTC-Mod Top Bottom Tree cxn:6-1/2"Otis MD 0' 2,374' TVD 0' 2,3 8-112"hole cmt w/350 sks plus 156 sks top-job Sidepocket Chemical Injection Mandrel 2.992"ID @ 1,209' Production Casing 1/4"OD,0.049"wall SS control line loaded w/1"double-check injection 3 1/2 EUE-Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' TOC 3-1/2"Csg . 6-1/8"hole cmt w/125 sks(47 bbl)of 12.5 ppg Estimated-4,500' Lead Cement and 500 sks(105 bbl)of 15.7 ppg Tail Cement Directional Data: 2.313"Otis X Nipple KOP-1,250'at 3 deg/100'build @ 7,182' ► EOB-2,326',27.5 deg hole angle Drop-4,000'@ 1.5 deg/100' Hold-5,719', 1.2 deg hole angle to TD i C LB-16 c Perforations: -j C 2-1/2" HSD 6spf,60 deg, 10.7 gm PJ2506 Tagged fill @ 7,778'(2/10/13) _� - LB-17 MD w/2.25"Bailer r LB-19 LB-16 7,400'-7,413' (10/2/01) ICLB-17 7,507'-7,527' (10/2/01) LB-20a LB-19 7,595'-7,602' (5/22/02) Damaged Pipe r:r:i LB-20b LB-19 7,650'-7,658' (5/22/02) Stuck 2-1/2"GR @ 7820' ;f;:.tif1J'c LB-21 LB-19 7,683'-7,692' (5/22/02) r r r•r•r t;...;r'�'tii1E LB-20a 7,717'-7,737' (10/2/01) -,I;f;tN}f;ry._ LB-23a LB-20b 7,758'-7,778' (10/2/01) ,,Zi a.:2= LB-23b LB-21 7,828'-7,848' (10/2/01) r.S.r•r•r. Capillary Tubing tir,M7fti; LB-24 LB-21 7,833'-7,853' (5/22/02)reperf 3/8" 2205 Stainless Steel -� t•�° rti{y.{r. LB-23a 7,927'-7,966' (10/2/01) Top Bottom �IrS•r-r•}•;7C LB-26 MD 0' 0' ,,,m130, LB-27 LB-23b 7,996'-8,001' (5/22/02) TVD 0' 0' }}4'3-}�}•}� LB-24 8,085'-8,100' (10/2/01) (***Pulled 02/14/2013"`) 0.ig LB-29 LB-26 8,257'-8,277' (12/3/01)LB-27 8,334'-8,354' (12/3/01) fr•"g5,; C LB-30 't�. �ti!' LB-29 8,530'-8,545' (11/30/01) ti LB-30 8,634'-8,654' (11/29/01) TD PBTD MD: 8,854' MD:8,754' TVD:8,560' TVD:8,460' Well Name&Number: Beaver Creek Unit#10 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 3.0°/100 ft @ 1,250' Angle/Perfs:J 0°-■2° Maximum Deviation: 28°@ 3,708' Date Completed: 04/13/01 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 2/10/2013 Schematic Revision Date:_ 8/8/2013 • • • IIBC-11 ACTUAL flilcorp Alaska.[JAL Pad 3 1,123' FNL, 1,481' FWL SCHEMATIC Permit#: 203-025 Sec. 34, T7N, R10W, S.M. API#: 50-133-20521-00-S1 Prop.Des: A-028083 Conductor KB elevation: 183' (21'AGL) 20" K-55 133ppf Latitude: 60°39'30.98"N ` r Top Bottom Longitude: 151°01'06.25"W ' MD 0' 112' Spud Date: 15:00hrs 3/28/03 TVD 0' 112' TD Date: 6:00hrs 4/16/03 Rig Released: 6:00hrs 4/23/03 Surface Casing 13-3/8" K-55 68 ppf BTC PA#: Tog Bottom MD 0' 2,198' TVD 0' 2,198' 17-1/2"hole Cmt w/802 sks(354 bbls)of 12 ppg Type-1 cmt.68 sks(30 bbls)to surface Tree cxn:6-1/2"Otis i. . L Intermediate Casing 9-5/8" L-80 40 ppf BTC Promore down hole sensor 1022; Bottom 7,203'MD (6,965'TVD) MD 7,,000 @ ( ND 7,000' w/7/16"electric cable 12-1/4"hole Cmtw/592 sks(269 bbls)of dual-armored,7-strand conductor to surface, Class G,Lead&537 sks(175 bbls)Tail. Did one 15K press sensor&one temp sensor not bump plug. 44sks(20 bbls)to surface. 7 1 "� Production Tubing TOC 3-112"Csg 3-112" L80 9.3 ppf EUE 8RD Estimated-0'(Surface) r �Y Top Bottom ' `7 MD 0' 8,888' TVD 0' 8,641' 8-1/2"hole Cmt w/1,070 sks(230 bbls)of 15.7 ppg,class G cmt Tagged fill®7,806'KB(12/27/07) w/2.25"Bailer ``+-•- r Excape System Details: -11 Excape modules placed - -Red control line for modules 5-11 Excape System Details: ''', -115. ` -Green control line for bottom 4 modules• 10 Conventional flappers ,)r. k -All modules w/flappers above module 1 -Mod 1 -no flapper 1,2 -15 • are conventional flapper versions. -Ceramic flapper valves below each module as follows: 1fj Perfs MD(RKB): Flappers MD(RKB): (6spf) 7,370'-7,388' (10/22/03) Module 11 7,507' U (6spf) 7,417'-7,431' (10/22/03) Module 10- 7,579' LLL... Module-11 7,487'-7,497' Module 9 7,644' �- Module-10 7,559'-7,569' Module 8 7,818 'v!f ' (6spf) 7,582'-7,599' (10/22/03) Module 7 - 7,978' Module-9 7,624'-7,634' Module 6 - 8,033' (6spf) 7,686'-7,703' (10/22/03) Module 5 - 8,074' +''. Module-8 7,798'-7,808' Module 4 - 8,360' (6spf) 7,903'-7,921' (10/22/03) Module 3 - 8,440' r Module-7 7,958'-7,968' Module 2 - 8,536' , �) Module-6 8,013'-8,023' Module 1 - NA Module-5 8,053'-8,063' (6spf) 8,088' 8,100' (10/22/03) (6spf) 8,116'-8,129' (10/22/03) 3.5"EZ drill squeeze packer @ t ' 4 Module-4 8,340'-8,350' 8,400 MD,8,154'TVD In ' Module 3 8,420' 8,130' Isolated set on(4-03-04) ICJ Module 2 8,516' 8,526' Isolated 1, Module 1 8,615' 8,626' Isolated Directional Data: KOP-3,500'at 2.4 deg/100'build EOB-4,786',28.0 deg hole angle Drop-4,848'@ 1.1 deg/100' TD PBTD Hold-7,720',2.0 deg hole angle to TD 8,931'MD 8,400'MD 8,684'ND 8,154'TVD Well Name&Number: Beaver Creek Unit#11 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: 2.4°/100 ft @ 3,500' I Angle/Perfs:I 2° ■13° Maximum Deviation: 28°t 4,723' Date Completed: 04/23/03 _ Ground Level(above MSL): 162' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 12/27/2007 Schematic Revision Date: 8/10/2013 • * 0 SU 41 -15RD ACTUAL Pad 43-9 27 SCHEMATIC Flacon,Alaska,LLC 23 , ' L Sec. 9, T5N,FSL R10W437 ,FE S.M. Fogerty#: 207-088 Conductor 20" K-55 133 ppf PE ' I#: 50-133-20484-01-00 Top Bottom operty Des: MD o' 79' AOGCC= ADL-2497 TVD 0' 79' BLM = A-028063 KB: 21'AGL (245'KB Elevation) ; X= 314,742.19 Surface Casing Y= 2,390,034.43 't' 13-3/8" K-55 61 ppf BTC Lat: 60° 32' 14.914" N Top Bottom MD 0' 2,271' Long: 151° 01' 51.643" W TVD 0' 2,270' Spud: 09:00 hrs 7/07/2007 Cmt wl 1,186 sks of Class G TD Reached: 7/20/2007 Rig Released: 6:00 hrs 7/27/07 �I ' Intermediate Casing 9-5/8" L-80 40 ppf BTC N Top Bottom Tree cxn=4-1/2"Otis I MD 0' 6,281' TVD 0' 5,615' Cmt original well w/2,284 sks of class G. Top of Cement 600'MD above 9-5/8"window .. @ 5,675'MD `N Production Tubing 3-1/2" L-80 9.3 ppf EUE Top Bottom 9-5/8"Casing Window . MD 0' 11,632' milled from _ TVD 0' 9,499' 6,275'to 6,294'(MD) 8rd with 6.25"OD control line protectors. 5,611'to 5,624'(TVD) 1 8-1/2"hole,Cmt w/545 sks(176 bbls)13.5 ppg Class G cmt lead and 1,456 sks(300 bbls) 15.8 ppg Class G cmt tail. Excape System Details: Excape System Details . {i I-- t 4 Conventional flappers ' -Mod 1 &2=no flappers - 6 Excape module system a 1 -Ceramic flapper valves below -iced control line for top 4 modules . RECEIVED STATE OF ALASKA MAY 1 0 201; AL.A OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 0 Repair Well LJ Plug Perforations Li Perforate Li Other L✓J Cap String Removal . Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdowd ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC • Development El Exploratory ❑ 167 -009 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 20006 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028083 • Beaver Creek Unit (BCU) 01 -A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): • N/A Beaver Creek / Sterling Gas - Beluga Gas 11. Present Well Condition Summary: 8,994; 9,001; ' Total Depth measured 10,296 feet Plugs measured 9,003 feet true vertical 9,388 feet Junk measured 8,648 feet 7,764; 8,607; Effective Depth measured 8,994 feet Packer measured 8,984 feet true vertical 8,120 feet true vertical 6,998; 7,747; feet 8,100 Casing Length Size MD TVD Burst Collapse Structural Conductor 526' 20" 526' 526' 1,530 psi 520 psi Surface 2,220' 13 -3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,130' 9 -5/8" 5,130' 4,819' 5,750 psi 3,090 psi Production 9,697' 7" 9,697' 8,805' 9,960 psi 6,210 psi Liner ��/��M 1 Perforation depth Measured depth See Attached Schematic SCANNED MAY A 5 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3 -1/2" L -80 7,890' MD 7,101' TVD Baker 84 SAB 40x30; Baker SC -1; 7,764'; 8,607'; 6,998'; 7,747'; Packers and SSSV (type, measured and true vertical depth) Baker Model D N /A; N/A . ' 8,110' TVD 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 0 190 Subsequent to operation: 0 0 0 480 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas 0 • WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Email chelgeson(hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907 - 777 -8405 Date 57fo/ j RBDMS MAY 1 2013 3\ 5'1 j3 Form 10 404 Revised 10/2012 bmit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU -01A 50- 133 - 20006 -00 167 -009 3/4/13 3/4/13 DafOpera#0 „i; ,. 03/04/2013 - Monday MIRU BJDC crane and deck equipment. Turn off chemical pump and disconnect the cap string from the chemical feed and cap both lines. POOH at 500 feet, 20 feet per minute per 100 feet. Tag FCV at surface. Close swab valve fully. Bleed off WH pressure. Lift injector off of well 1 -2 feet. Unthread WPA. Lift injector up and away from WH, lower injector and remove FCV and WPA. Cap tubing. Remove tubing from chains. Secure tubing tail. Remove tubing spool from unit. Rig -down unit. Secure area. Pump methanol and pressure test string to 4K. Drop spool at edge of pad. WPA, manifold in CICM. a 1 Permit #: 167 -009 BC-1A API #: 50- 133 - 20006 -00 Pad 1A El Property Des: A - 028083 KB Elevation: 153' (16.8' AGL) Spud Date: 3/13/1967 Sec. 33, T7N, R10W, S.M. S.M. ililvorp Alaska, 1.I I . TD Reached: 6/13/1967 conductor J Lat: 20" H -40 94 ppf Long: Top Bottom j . MD 0' 526' TVD 0' 526' 1 26" hole cmt w/ 1,000 sks of Class G Camco Injection Mandrel @ 898' i Tubing String 3 -1/2" L -80 9.3 ppf 2.984" ID Top Bottom MD 0' 7,890' TVD 0' 7,101' 2.813" Camco X Nipple 7,815' Baker 80 -40 Anchor on Baker 84 SAB 40x30 Surface Casing Permanent 13 -3/8" J -55 61 ppf 2.813" Camco X Nipple 7,853' q 1 P acker w / 3.25" ID Top Bottom AI' MD 0' 2,220' 1 1 • , TVD 0' 2,220' Velocity String it I 18 -5/8" hole cmt w/ 3,500 sks of Class G 1 -314" QT -700 0.125" wall 1.40" ID Top Bottom II II ' MD 0' 8,296' TVD 0' 7,455' ■ Intermediate Casing 2.50" BHA w/: Grapple C ilittine Re - entry Guide 9 -5/8" N -80 40 / 43.5 ppf 10' Straight bar @ 7,890' Top Bottom 1.25" PXN nipple c 3,25 OD x 2.984 ID MD 0' 5,130' 1.75" Re -entry shoe DI C TVD 0' 4,824' c 12 -1/4" hole cmt w/ 1,800 sks of Class G Production Casing 7" N -80 / P -110 26 / 29 ppf s Baker SC - 1 Packer Top Bottom • T ♦ 4' ID @ 8,607' MD 0' 9,697' . Perforations: ND 0' 8,805' 8 hole cmt w/ 730 sks of Class G 8 797' - 8 817' ° I c Gravel Pack Screen ^ 4 -1 /2" L -80 17 ppf 2.313" Otis X Nipple - Well Screen Top Bottom @ 8,894' 4.5" OD x 2.438" ID MD 8,607' 8,984' TVD 7,747' 8,110' Perforations: =t _ ii 8,956' - 8,976' °,`� c Gravel packed 1 - _ IN Model D Packer Perforations: ~ 3.25" ID @ 8984' MD MD TVD TVD B -18U 8,087 8,107 7,627- 7,284' Cast Iron Bridge Plugs , B -18L 8,118' - 8,148' 7,294'- 7,321' @ 8,994' MD -11. B -19 8,183' - 8,223' 7,352'- 7,388' @ 9,001' MD _■ B -20 8,284' - 8,312' 7,444'- 7,470' © 9,003' MD _ B -21 8,374' - 8,404' 7,528- 7,556' B -22 8,439' - 8,459' 7,589'- 7,608' B -23 8,500' - 8,520' 7,646'- 7,665' TD PBTD 8,527' - 8,567' 7,672'- 7,710' MD: 10,296' MD: 8,994' TVD: 9,388' TVD: 8,120' Well Name & Number: Beaver Creek - 1A Lease: A - 028083 County or Parish: Kenai Peninsula Borough State /Prov: Alaska Country:I USA Angle @KOP and Depth: 1.8° / 100 ft @ 2,300' Angle /Perfs:I 29 °-.19° Maximum Deviation: 39° @ 4,450' Date Completed: I Ground Level (above MSL): 153' RKB (above GL):I 16.8' Revised By: DMA I Last Revision Date: 5/3/2013 • Mar, Alaska Production LLC Alaska Asset Team AA Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 May 10, 2011 RECEIVED Mr. Winton Aubert MAY 1 2 aal' Alaska Oil & Gas Conservation Commission 333 W 7 Ave Mika ail & f a Cos. Commission Anchorage, Alaska 99501 .incn@r as I ( 00 Reference: 10 -404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek Unit #1A Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for BC -1A well. This report covers the work performed to re- establish gas production from BC -1A utilizing gas lift. Gas lift operations were established on April 14, 2011 achieving stable production on March 1, 2011. Production slowly increased from 90mcf to 165mcf over the ten day period commencing on March 1st. Water production has remained stable, at approximately 35bbd, since gas production was re- established. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, . )dit--114_,' wAtola_ ',Ilk? 1 3 2,01 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS a 'U. L-,- . k•,v►3 Ai sift , WA-- STATE OF ALASKA MAC/ a nil Qs /t3 /LOit ALASKA" AND GAS CONSERVATION COMMISSIOW REPORT OF SUNDRY WELL OPERATIONS r lsaka pi{ & ri [Ans. Doimission 1. Operations Abandon Li Repair Well Li Plug Perforations Li Stimulate Li Other 0 ' ° � mbate Gas Lift Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension operations Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alask Production LLC Development p Exploratory ❑ c) 167 -009 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 ' 50- 133 - 20006 -00 -00 7. Property Designation (Lease Number): , 8. Well Name and Number: FED A- 028083 Beaver Creek #1A 9. Field /Pool(s): ) Beaver Creek Field / Beluga Pool * IY 10. Present Well Condition Summary: Total Depth measured 10,296' feet Plugs measured 8,994', 9,001', 9,033' feet true vertical 9,390' feet Junk measured 8,648' feet Effective Depth measured 8,994' feet Packer measured 7,764', 8,607', 8,984' feet true vertical 8,122' feet true vertical 6,998', 7,747', 8,110' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 509' 20" 526' 526' 1,530 psi 520 psi Surface 13 -3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,113' 9 -5/8" 5,130' 4,819' 5,750 psi 3,090 psi Production 9,680' 7" 9,697' 8,807' 9,960 psi 6,210 psi Liner 377' 4 -1/2" 8,984' 8,110' Gravel Pack Gravel Pack Perforation depth: Measured depth: 8,087' - 8,976' feet True Vertical depth: 7,265' - 8,102' feet Tubing 3 -1/2" L -80 7,890' 7,101' TVD Velocity String 1 -3/4" QT -700 8,296' 7,455' TVD Tubing (size, grade, MD & TVD): Capillary String 3/8" 2205 Stainless Steel 8,330' 7,486' TVD SSSV: NA NA MD NA TVD Packers and SSSV (type, MD & TVD): Packers: Baker 84 SAB 40x30, Baker SC -1, 7,764', 8,607', 6,998', 7,747', TVD & Baker Model D 8,984' MD 8,110' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Gas lift operations were established on April 14, 2011 achieving stable production on March 1, 2011. Production has slowly increased from 90mcf to 165mcf over a ten day period. Water production has remained stable at Treatment descriptions including volumes used and final pressure: approximately 35bbd since gas production was re- established. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 289 Subsequent to operation: 0 165 35 0 375 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 131 \I Service❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ . Gas U WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -408 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature "K Phone (907) 283 -1371 Date May 10, 2011 RBDMS MAY 1 . 2 2011 f j Submit Original 10 -404 Revised 10/2010 ginal Onl y i, Q O'0Dations Summary Report by Job • � Oil Co Marathon ilCo mpany Well Name: BEAVER CREEK IA Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6033007N010W01 BEAVER CREEK ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB Casing Flange Distance (ft) KB Ground Distance (ft) Spud Date Rig Release Date 0.00 0.00 0.00 0.00 3/13/1967 5/2012008 I Daily Operations 1 Report Date: 1/13/2011 Job Category: R &M MAINTENANCE 24 Hr Summary Rig up flow back iron, install flowline from jet compressor to BC -1A velocity string, install soap injection port into injection gas stream flowline, begin gas injection with soap injection Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 16:00 06:00 14.00 PUMP TRET AF Inject .5 MM methane gas from jet compressor down velocity string. Input pressure 850 psi, annulus pressure 324 psi. Gas production rate is .5 MM. No water Report Date: 1/14/2011 Job Category: R &M MAINTENANCE 24 Hr Summary Use jet compressor to provide lift gas down velocity string @900 psi, inject soap into flowline at 3 gallons per day. Rate into wet 1/2 MM per day. Rate out is 1/2 MM per day. No fluid production. Velocity string became plugged. No flow down velocity string, No flow up annulus. Pressure on wellhead velocity string 900 #. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code _ Status Code Corn 06:00 06:00 24.00 PUMP TRET AF Pump methane down velocity string with 3 gallons soap per day injected into gas stream down velocity string at 900 psi. Rate in is 1/2 MM per day. Rate out of well is 1/2 MM per day at 324 psi. During day, velocity string plugged, no rate into well Report Date: 1/15/2011 Job Category: R &M MAINTENANCE 24 Hr Summary Check for blockage in jet compressor flowline and velocity string in well, dump soap at bottom of velocity string. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 SAFETY MTG AF Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, working in cold weather, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, buddy rule, three second rule, stop the job authority, safety drill. Keeping the focus on the job. 09:00 11:00 2.00 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Pressure test lubricator to 1500# - test successful 11:00 12:30 1.50 RUNPUL SLIK AF Run 1.25" OD gauge ring down 1.75" velocity string with 1.4" ID. Hit soft bridge at 6230' MD. Push obstruction down to 8290' MD at "XN" profile. Pull out of hole to run dump bailer with soap down to bottom of tubing and then try to restart gas injection. 12:30 13:30 1.00 RUNPUL SLIK AF Run 1.25" dump bailer down to 8290' MD. Dump approx. one quart of liquid soap foamer on top of "XN" profile. POOH Back at surface, bailer did not dump. RIH to dump soap one more time. POOH. Fluid level appears to be at 6130' MD. Start gas injection back into velocity string when slickline tool string is out of hole. Install soap stick launcher on top of tree. 13:30 15:00 1.50 RURD SLIK AF Rig down slickline unit, lubricator and crane truck. Start gas injection through V string, blow down annulus to flow back tank. No fluid to tank, annulus pressure dies in approx. 15 minutes. Shut in annulus. 15:00 16:00 1.00 SECURE WELL AF Secure wellhead for evening, leave location, turn in safe work permit, return to office i Report Date: 1/16/2011 Job Category: R &M MAINTENANCE 24 Hr Summary . Pump N2 down annulus to bullhead water away, rig up to assist jet compressor with lift gas down V string if needed. Restart lift gas. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 12:30 13:00 0.50 SAFETY MTG AF Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, working in cold weather, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, buddy rule, three second rule, stop the job authority, and keeping the focus on the job. 13:00 15:00 2.00 RURD STIM AF Rig up N2 pumping equipment, flowlines. Cool down N2, pressure test treating lines to 4000# - test good. www.peloton.com Page 1/4 Report Printed: 5/10/2011 M Marathon • ations Summary Report by Job VIZ ® OitCompany Well Name: BEAVER CREEK IA Qtr /Qtr, Block, Sec, Town, Range Fed Name License ;+ ' State /Province Country 6033007N010W01 BEAVER CREEK ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB Casing Flange Distance (ft) KB Ground Distance (ft) Spud Date Rig Release Date 0.00 0.00 0.00 0.00 3/13/1967 5/20/2008 i Ops Trouble I Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 15:00 16:30 1.50 N2 AF Pump N2 into annulus flow line. Calculated volume to displace water back into formation at approx 1250 # surface pressure with fluid level in annulus assumed to be approx. 6100 feet and top perforation at 8100' is 60,000 scf Time Rate P annulus P velocity string 1455 0 500 900 1500 700 690 900 1505` 700 970 1000 l� 1510 700 1050 1000 1515 700 1330 1000 1520 700 1500 1000 18,000 scf N2 used to this point 1525 700 1690 1000 1530 700 1800 1000 1535 700 1900 1000 28,000 scf N2 used to this point 1540 700 2030 1000 32,000 away 1545 700 2170 1000 35,000 away 1550 700 2280 1000 38,000 away 1555 700 2370 1000 42,000 away 1600 700 2480 1000 45,000 away 1605 700 2560 1000 48,000 away 1610 700 2640 1000 52,000 away 1615 700 2730 1000 56,000 away 1620 700 2750 1000 59,800 scf N2 used to this point Shut down N2 at 16:20 hours. Start bleeding off annular pressure at 16:30 hours 1 16:30 18:00 1.50 BLOWDN CSG AF Starting 16:30 flow N2 back from annulus. Beginning pressure 2500 #. Velocity string begin flowing gas at approx. 16:34. Continue venting N2. www.peloton.com Page 2/4 Report Printed: 5/10/2011 -1 tin Marathon CSations Summary Report by Job • i 6 OiiICompany Well Name: BEAVER CREEK IA QtrlQtr, Block, Sec, Town, Range Field Name License # 1 State /Province Country 6033007N010W01 BEAVER CREEK ALASKA ,USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date I Rig Release Date 0.00 0.00 0.00 0.00 3/13/1967 I 5/20/2008 Ops Trouble _ Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 18:00 19:30 1.50 PUMP N2 AF Begin cool down at 15:55 hours. Prepare to pump into velocity string at 700 scf / minute. Time Rate P velocity string P annulus 18:05 700 1070 0 1810 700 1210 100 1815 700 1310 100 8,000 scf N2 away 1820 700 1350 250 fluid return - 1/3 bpm 1825 1830 700 1440 350 18,000 scf away, fluid rate approx 1 -2 BPM 1835 700 1400 350 Fluid rate 1/2 BPM 1840 700 1380 350 Fluid rate 1/2 BPM 1845 700 1360 350 Fluid rate 1/2 BPM 1850 700 1330 350 Fluid rate 1/2 BPM 1855 700 1290 350 Fluid rate 1/2 BPM 1900 700 1240 325 Fluid rate 1/2 BPM closed choke slightly to get annulus pressure up to simulate sales line pressure of 350# 1905 I 700 1170 350 Fluid rate 1/2 BPM 1910 700 1060 350 Fluid rate 1/2 BPM Lots of foam in fluid returns 1915 700 1000 350 Fluid rate 1/2 BPM TEN inches of fluid returns in tank T5 (2.41 BBL / in ?) tank not marked - 24 BBL returns 1920 700 950 350 Fluid rate 1/2 BPM 1925 700 920 350 Fluid rate 1/3 BPM 1927 0 SHUT DOWN N2 Total N2 pumped 56,000 scf this stage. Total 116,000 scf. Fluid returns remaining steady at 1/4 BPM or less 19:30 20:30 1.00 RURD STIM AF Rig down N2 pump truck and treating iron. Fluid returns stopped at approx 7:45 pm 20:30 21:00 0.50 SECURE WELL AF Secure wellhead, turn production into sales line, halt venting. Leave location, sign out, turn in safe work permit, leave field Report Date: 2/5/2011 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU DynaCoil to run cap string to 8330'. Spotted 1 gallon of foamer every 30' from 8300 to 8592'. Tagged up @ 8592'. Spotted 3 gals foamer. PUH to 8330' and hung off cap string. Set fluid control valve pressure to 3800 psi. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:30 1.00 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, working in cold weather, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 08:30 09:30 1.00 PREP LOC Move heater and MEOH skid out of way. Plow snow around well head and prepare location for rig up and work. 09:30 12:30 3.00 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. PU spool onto unit. Displace MEOH in cap string w/ 37 gallons of foamer. RD N2 injection iron from tree cap. MU well head adapter. Set BHA to 3800 psi. Thread cap string into injector assembly. Thread on Pack off. Straighten coil to help run into V string hanger. 12:30 13:00 0.50 `RURD COIL Carry injector to WH while "walking" injector down string. MU pack off to well head adapter. www.peloton.com Page 314 Report Printed: 5/10/2011 • O'ations Summary Report by Job • g Marathon Company Well Name: BEAVER CREEK IA Qtr/Qtr, Block, Sec, Town, Range Field Name license # State /Province Country 6033007N010W01 BEAVER CREEK ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 0.001 0.00 0.00 3/13/1967 5/20/2008 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 13:00 13:30 0.50 TEST EQIP Check swab valve - closed. Close wing valve. PTest Packoff to 2500 psi. Test good. 13:30 15:00 1.50 RURD COIL RIH w/ cap string. 15:00 15:30 0.50 PUMP TRET Start laying in foamer, 1 gal every 30' to 8592. Tag up at 8592'. Lay in 3 gallons @ 8592'. PU hole to 8330' and land cap string. 15:30 16:15 0.75 RURD COIL RIH to 3592'. Bottom of V- string is at 8296' md. Must be carefull exiting wirelirie re -entry guide. PU to 8330' and and land cap string. Set mechanical slips. Set Ratigun. Set packoff pressure to 3000 psi. Pull tubing out the side of injector and set coil up at WH. Reconnect foamer line. Power up foamer skid and set rate to 2.5 gal /day. 16:15 17:15 1.00 RURD COIL RD DynaCoil uint. PU liners and drip pans. Clean up loc. 17:15 17:30 0.25 Place placarding on upper master and swab valves. Install LOTO to swab and upper master. Secure well head. Leave loc. Turn in permits . Sign out and leave field. www.pefoton.com Page 4/4 Report Printed: 5/10/2011 Marathon Citations Summary Report by Job • I ® OiICompany Well Name: BEAVER CREEK IA Qt/Qtr, Block, Sec, Town, Range Field Name j License # State /Province Country 6033007N010W01 BEAVER CREEK 4 ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) I KB Casing Flange Distance (ft) KB Ground Distance (ft) Spud Date Rig Release Date 0.00 0.00 0.00 0.00 3/13/1967 5/20/2008 Daily Operations Report Date: 4/15/2011 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU BJ to jet well with N2. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:30 1.00 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, working in cold weather, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 08:30 10:00 1.50 RURD EQIP Spot equipment. RU N2 pumping equipment. Hammer up 2" hardlines and suctions hoses to the N2 tanks. Start Pump motors. Begin cooling down N2 pumps. 10:00 10:30 - 0.50 TEST EQIP Prime up pumps. PTest pumps and lines to 4000 psi. Test good. 10:30 17:00 6.50 JET N2 Start pumping N2: TIME N2 Pump rate WH Pressure V -AN Press Comments 10;25 860 scflmin 1600 0 10:32 1020 1700 0 No water 10:35 860 1750 0 10:45 800 1850 0 start foamer 10:50 880 1900 0 No water 10:55 860 2000 Water to surface 11:00 800 1900 200 Good water returns 11:10 400 1500 400 Good water returns 11:20 400 1200 250 Less water returns 11:30 300 800 100 Spitting water 11:35 300 700 0 heading and spitting 11:50 300 800 0 Est 8 -10 gal /min 12:00 300 600 0 12:10 300 700 0 12:30 300 625 0 12:42 0 0 Loose prime. Shut down. Switch switch N2 tanks 13:05 Cool down pumps 13:18 360 500 0 13:30 300 650 0 Choke returns to increase ann. 13:45 300 725 0 8 -10 gal /min foamy returns 14:00 300 800 0 P increasing suggests lifting water 14:40 300 800 14:45 300 750 75 Still 8 -10 gal /min foamy returns 15:15 345 750 0 Open backside 15:30 340 725 15:45 340 725 16:00 350 725 16:15 300 700 16:19 0 700 Lost prime. 10 gal /min foamy returns 16:30 700 Wells switched to sales (line 17:05 700 >10 gal /min foamy • returns www.peioton.com Page 1/2 Report Printed: 5/10/2011 A` Marathon Oations Summary Report by Job • MARATHON ® Oil Company Well Name: BEAVER CREEK 1A Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country 6033007N010W01 BEAVER CREEK ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date i 0.001 0.00, 0.00 0.00 3/13/1967 ` 5/20/2008 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 17:00 1 18:00 1.00 RURD EQ)P RD N2 pumping equipment. 18:00 18:15 0.25 SECURE WELL Continue flowing well to gas buster. Well is being powered by sales line gas @ 700 psi. Secure well. Turn in permit. Sign out and leave loc. www.peloton.com Page 2/2 Report Printed: 5/10/2011 411 III Permit #: 167 -009 BC-1A API #: 50- 133 - 20006 -00 Pad 1A A#1 Property Des: A - 028083 117' FSL, 1,338' FEL M ARATHON KB Elevation: 153' (16.8' AGL) Spud Date: 3/13/1967 Sec. 33, T7N, R10W, S.M. TD Reached: 6/13/1967 Conductor Lat: 20" H -40 Long: , Tom Bottom M D 0' 94 ppf 526' { TVD 0' 526' 26" hole cmt wl 1,000 sks of Class G Camco Injection Mandrel @ 898' -` Tubing String 3 -1/2" L -80 9.3 ppf 2.984" ID Top Bottom MD 0' 7,890' TVD 0' 7,101' 2.813" Camco X Nipple 7,815' Baker 80 - 40 Anchor on Baker 84 SAB 40x30 Surface Casing Permanent 13 -3/8" J -55 61 ppf 2.813" Camco X Nipple 7,853' 11 ' ii Packer w/ 3.25" ID Tom Bottom MD 0' 2,220' 'it u TVD 0' 2,220' Velocity String ° 1-3/4" QT -700 0.125" wall It 18 -5/8" hole cmt w/ 3,500 sks of Class G 1.40" ID Top Bottom II II MD 0' 8,296' TVD 0' 7,455' ■ Intermediate Casing 2.50" BHA w/: Grapple c Wireline Re - entry Guide 9 - /8" N -80 40143.5 ppf =ii 10' Straight bar @ 7,890' Tom Bottom 1.25" PXN nipple c 3.25 OD x 2.984 ID MD 0' 5,130' 1.75" Re -entry shoe C TVD 0' 4,819' � c 12 -1/4" hole cmt w/ 1,800 sks of Class G Capillary String (Installed 07/09/08) (Inspected 09/02/10) 318" 2205 Stainless Steel Production Casing 7" N -80 / P -110 26 / 29 ppf Tot Bottom = Baker SC - Packer Top Bottom MD 0' 8330' _ 1- 4' ID @ 8,607' MD 0' 9,697' TVD 0' 7486' _ i TVD 0' 8,807' 1 8 -1/2" hole cmt w/ 730 sks of Class G Perforations: 8,797' - 8,817' c C Liner 4 -1/2" L -80 17 ppf 2.313" Otis X Nipple Well Screen Tot Bottom @ 8,894' 4.5" OD x 2.438" ID MD 8,607' 8,984' TVD 7,747' 8,110' P erforatio n s: Gravel packed 95 ' -8 976' o C 8, 6 , Model D Packer Perforations: .4_ 3.25" ID @ 8984' B -18U 8,087' - 8,107' ' Tr. h4 B -18L 8,118' - 8,148' Cast Iron Bridge Plugs B -19 8,183' 8,223' @ 8,994' MD -♦ B -20 8,284' - 8,312' B -21 8,374' - 8,404' @ 9,001' MD @ 9,003' MD B -22 8,439' 8,459' -♦ B -23 8,500' - 8,520' 8,527' - 8,567' TD PBTD MD: 10,296' MD: 8,994' TVD: 9,390' TVD: 8,122' Well Name & Number: Beaver Creek - 1A Lease: A - 028083 County or Parish: Kenai Peninsula Borough State /Prov: Alaska Country:I USA Angle @KOP and Depth: 1.8° / 100 ft @ 2,300' Angle /Perfs:I 29 °-. 19° Maximum Deviation: 39° @ 4,450' Date Completed: 1 Ground Level (above MSL): 153' RKB (above GL):I 16.8' Revised By: Craig Rang I Last Revision Date: 2/7/2011 S EED ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSER VATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production LLC L1 P.O. Box 1949 r jc Kenai, AK 99611- 1949�� t! Re: Beaver Creek Field, Beluga Oil Pool, Beaver Creek # lA Sundry Number: 310 -408 Dear Mr.Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4� Daniel T. Seamount, Jr. Chair DATED this 3 day of December, 2010. Encl. Marathon Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 s Alaska Production LLC Kenai, AK 99611 Telephone 9071283 -1371 Fax 907/283 -1350 December 8, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 I ,ED DEC 10 2010 Reference: 10 -403 Application for Sundry Approvals maska Oil & 621s Cons. Conlyissron Anch0r&P Field: Beaver Greek Field Well: Beaver Creek Unit 1A Dear Mr. Aubert: Submitted for your approval is the10 -403 Application for Sundry Approvals for BC -1A well. Marathon proposes testing the gas lift concept on the BC -1A well to enhance the liquid unloading characteristics of the well. We anticipate using a lift gas rate of +/ -1,000 mcfd at a pressure of 700 -1,000 psi down the existing velocity string and producing the gas up the annulus. This operation is targeted at returning BC -1A to its previous production rate of 1,100 mcfd (net). If the concept is successful, we plan to utilize this process on an intermittent/continuous bases as required to maintain production. Please contact me at (907) 283 -1371 if you have any questions or need additional j information. Sincerely, s Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File KJS STATE OF ALASKA • '+T �� ALASKOL AND GAS CONSERVATION COMMISSION j APPLICATION FOR SUNDRY APPROVALS �Z1 z oro 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Initiate Gas Lift - ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ❑ Exploratory ❑ 167 -009 3. Address: PO BOX 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50 -133- 20006- 00 -00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No Beaver Creek #1A 9. Property Designation (Lease Number): 10. Field / Pool(s): FED A- 028083 Beaver Creek Field / Beluga Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,296' 9,390'- 8,994' 1 8,122' 8,994', 9,001', 9,033' 8,648' Casing Length Size MD TVD Burst Collapse Structural Conductor 509" 20" 526' 526' 1,530 psi 520 psi Surface 2,203 13 -318" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,113' 1 9 -518" 1 5,130' 4,819' 5,750 psi 3,090 psi Production 9,680' 7" 9,697' 8,807' 9,960 psi 6,210 psi Liner 377' 4 -112" 8,984' 8,110' Gravel Pack Gravel Pack Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,087'- 8,976' / 7,265' - 8,102' Tubing 3 -1/2" L -80 7,890' Velocity 1 -3/4" QT -700 8,296' Capillary 318" 2205 Stainless Steel 8,330' Packers and SSSV Type: SSSV: NA / Packers and SSSV MD (ft) and TVD (ft): NA ! NA Packers: Baker 84 SAB 40x30, Baker SC -1, 7,764', 8,607', 8,984' 6,998',7,747',8,110' & Baker Model D 12. Attachments: Description Summary of Proposal 0 13, Well Class after proposed work: detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 _ Service ❑ 14. Estimated Date for 15. Weil Status after proposed work: :ommencing Operations: January 5, 2011 Oil ❑ Gas �_ WDSPL ❑ Suspended El 16. Verbal Approval: Date: W(NJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ ,ommission Representative: GSTOR ❑ SPLUG ❑ 7. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 ) rinted Name Kevin J. Skiba Title Regulatory Compliance Representative signature . P i e Date (907) 283 -1371 December 8, 2010 COMMISSION USE ONLY (� [� :onditions of approval: Notify Commission so that a representative may witness Sundry Number: �' \/ ' 1 O$ lug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ s I"E Ither: V DEC 1 0 2010 Oil & Gas Cons- Com6ss on ubsequent Form Required: I Q — 4 0 tE. - Anchorap4 APPROVED BY oproved by: COMMISSIONER THE COMMISSION Date: 1Z i3 /eo RBDili4S DEC 13 Wl 15n R t I Form 10 -403 Revised 1/2010 Submit in Duplicate MARATHON Marathon Oil Company Alaska Region Beaver Creek #lA Gas Lift Procedure Date: 12/7/2010 History: In early September 2010 production on BC 1A began to fail. The well was not able to produce fluids to surface and liquid loading was occurring. Since then repeated attempts to unload the well ave been un- successful. Prior to the failure the well was capable of 11 OOMCFD. Objective: Our goal is to test the potential of Gas Lift on BC1A to unload the well. We will utilize gas off the discharge of a nearby compressor to push down the existing V -String and up the annulus in an attempt to bring fluids to surface. We anticipate using lift gas between 700 - 1000psi and + /- 1000MCFD. If higher pressure gas is needed to initially kickoff the well an N2 unit will be utilized. We anticipate returning this well to its prior production of I I OOMCFD(net). Procedure: 1. Begin pumping soap down Capillary String 2. Partially choke back discharge of Saturn compressor to bring system from — 700psi to — 1000psi 3. Open lift gas valve and pressure up temporary piping to I wellhead, test for 5 min @ 1000psi 4. Begin flowing BC1A annulus 5. Open Valve at wellhead and begin flowing gas down existing V -String and Up annulus if water rate not sustained 6. Monitor Flow rates, ensuring gas rate from annulus is greater than V -String rate 7. Lower gas lift pressure to 700 Psi after initial unload. i Permit #: 167 -009 BC -1A API #: 50- 133 - 20006 -00 Pad 1A Property Des: A-028083 117' FSL, 1,338' FEL MARATNIDN KB Elevation: 153' (16.8' AGL) Sec. 33, T7N, R10W, S.M. Spud Date: 3/13/1967 TD Reached: 6/13/1967 Conductor Lat: 20" H-40 94 ppf L ong: TOP Bottom MID 0' 526' TVD 0' 526' 26" hole cmt wl 1,000 sks of Class G Camco Injection Mandrel @ 898' a' Tubing String 3 -1/2" L -80 9.3 ppf 2.984" ID Top Bottom MD 0' 7,890' TVD 0' 7,101' 2.813" Camco X Nipple 7,815' Baker 80 - 40 Anchor on Baker 84 SAB 40x30 Surface Casing Permanent I 13 -3/8" J -55 61 ppf 2.813" Camco X Nipple 7,853' Packer w/ 3.25" ID ' DOW Bottom MD 0' 2,220 ' TVD 0' 2,220' Velocity String 18 -5/8" hole cmt w/ 3,500 sks of Class G 1 -3/4" QT -700 0.125" wall 1.40" ID Top Bottom MD 0' 8,296' TVD 0' 7,455' Intermediate Casing 2.50" BHA w/: Grapple C Wireline Re - entry Guide 9 - 518" N - 80 40 / 43.5 ppf 10' Straight bar @ 7,890' Top Bottom 1.25" PXN nipple 3.25 OD x 2.984 ID MD 0' 5,130' 1.75" Re -entry shoe C TVD 0' 4,819' C C 12 -1/4" hole cmt w/ 1,800 sks of Class G Capillary String (Installed 07/09/08) (Inspected 09/02/10) 3/8" 2205 Stainless Steel Production Casing 7" N -80 / P -110 26 / 29 ppf Top Bottom Baker SC - 1 Packer MD 0' 8,330' 0 _ Tom Bottom TVD 0' 7,486' 4' ID @ 8,607' MD 0' 9,697' a TVD 0' 8,807 8 -1/2" hole cmt w/ 730 sks of Class G Perforations: 8,797 -8,817 c c Liner 4 -112" L -80 17 ppf 2.313" Otis X Nipple Well Screen Top Bottom @ 8,894' 4.5" OD x 2.438" ID MD 8,607' 8,984' TVD 7,747' 8,110' Perforati!2n!g �, Gravel packed 8,956 Model D Packer Perforations: 4 3.25" ID @ 8984' B -1 8U 8,087'- 8,107' B -18L 8,118'- 8,148' Cast Iron Bridge Plugs B -19 8,183'- 8,223' @ 8,994' MD ' B -20 8,284' - 8,312' @ 9,001' MD B -21 8,374'- 8,404' -♦ , B -22 8,439'- 8,459' @ 9,003' MD _♦ B -23 8,500'- 8,520' 8,527'- 8,567' TD PBTD MD: 10,296' MD: 8,994' TVD: 9,390' TVD: 8,122' Well Name & Number: Beaver Creek - 1A Lease: A - 028083 County or Parish: Kenai Peninsula Borough State /Prov: Alaska Country: USA Angie @KOP a nd Depth: 1.8° 1 100 ft @ 2,300' Angle /Perfs: 1 29 19° Maximum Deviation: 39 @ 4,450' Date Completed: I Ground Level (above MSL): 153' RKB (above GL):1 16.8' Revised By: I M. Dammeyer Last Revision Date: 10/7/2010 BC -1 A Gas Lift to Velocity String Gas Lift .._..,�..— ..— .._..- Meter Z -587 BC -1A 7. IL A R, a I Production Meter o Z -400 tc SaI S m Production gas from annulus — L .._.. _.._. ._.. -- Linn H _ Marathon OIL COMPANY LEGEND Beaver Creek 1A Liftsystem Lft Gas — • • — _ Gas Lift Flow Diagram Well ` Production R Lift Gas Production to sales Gas '— • — Beaver Creek Field Production Gas = Z -400 meter - Z -587 meter Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R1 OW, S.M. Kenai Peninsula Borough Alaska Prepaired by. Kevin Skiba Date: 12 -6 -2010 • Marathon MARATHON Oif Company August 8, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations i Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 f„ ,. ~~ , ~, ~~ Field: Beaver Creek Field ~ (p~ ~ Well: Beaver Creek 1A Dear Mr. Maunder: Attached for your records is the10-404 Report of Sundry Well Operations for BC-1A well. This report covers the capillary string instillation work covered under Sundry #308-235. The attached operational summary covers two topics: • Raising velocity string (original work performed under Sundry #307-217) o Raised to 8'296' MD ~~~,~~~ ~u~ ~ ~ 2oas • Capillary string instillation ~~y o Set at 8,265' MD Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD STATE OF ALASKA ~. , ALA OIL AND GAS CONSERVATION ~ ~ ON REPORT OF SUNDRY WELL OPERATIONS ~~d' 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Raise V-String Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ & Install Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Capillary String 2. Operator Name: Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: ; Development ^~ Exploratory^ '~ / 167-00$ 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20006-00-00 7. KB Elevation (ft): 9. Well Name and dumber. ~ 153' (16.8' AGL) \ Beaver Creek #1A 8. Property Designation: ``w~ 10. Field/Pool(s): ~:~ ,~+ ,~ A - 028083 Beaver Creek Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 10,296' feet Plugs (measured) 8,994', 9,001', 9,033' true vertical 9,390' feet Junk (measured) 8,648' Effective Depth measured 8,994' feet true vertical 8,122' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 509' 20" 526' 526' 1,530 psi 520 psi Surface 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,113' 9-5/8" 5,130' 4,819' 5,750 psi 3,090 psi Production 9,680' 7" 9,697' 8,807' 9,960 psi 6,210 psi Liner 377' 4-1/2" 8,984' 8,110' Gravel Pack Gravel Pack Perforation depth: Measured depth: 8,087'-8,976' gross True Vertical depth: 7,265'-8,102' gross 3/8" 2205 Stainless Steel 8,265' 1-3/4" Hang Off - 70 8,296' Tubing: (size, grade, and MD) 3-1 /2" 9.3# L-80 7,890' Baker 84 SAB 40x30 7,764' Baker SC-1 8,607' Packers and SSSV (type and measured depth) Baker Model D 8,984' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 26 0 51 Subsequent to operation: 0 1,025 - 0 352 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-235 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician . t - ~ Signature , ' Phone (907) 283-1371 Date August 8, 2008 Operations Summary Repor# Well Name: BEAVER CREEK 1A Re ort Date: 3/7/2008 Job Category: WELL INTERVENTION _ 24 Hr Summary RU hard line. to top of tree, bull head gas from. BC 14 down V string. U nload veloctiy string to flow back tank, well went to 0 psig. Left 0 psig on top of velocity string Opa Trvubla __ Start lime End Time Dur (hrs) Ops Code Activity Cdde StaWs Code Comment 09:00 10:00 1.00 BLOWDN TBG_ AF Pressured up on hard line with Well head gas from BC14. WHP= 1700 psig. 10:00 11:00 i.00 BLOWDN TBG_ ~ AF ~ ~ At star) of test, Well flowing at i.8 MCFPD, 48 BWPD, 360 psig up the annulus. Pressured up on top of the Velocity string with well pressure. Pressure stabilized at 900 psig. Shut BC 14. Monitored annulus flow which dropped to 1.0 MMCFPD, same waier rate. www.peloton.com Report Printed: 8/812008 I ' Operations Summary Report Well Name: BEAVER CREEK 1A Start Time End Tlme Dur (hrs) Opa Code:. ,-AcOWty Code Opa Statue Trouble Code Comment 11:00 12:00 1.00 BLOWDN TBG_ AF Blew down the velocity string to flow back tank in 4 minutes. Velocity string went to 0 psig. No fluid. left open to flow back tank for 50 minutes with no _ change. 12:00 12:30 0.50 BLOWDN TBG_ AF ~ ~ _m Shut in operation. Velocity strijng at 0 psig. Well flowing up the annulus at 1.7 MMCFPD, 48 bbls WPD, 360 psig. Daily Operations ---------.--__..__. _ Re ort taue: 3/12/2008 Job Category: WELL INTERVENTION - _ 24 Hr Summary - -- _ RU hard line to top of tree, bull head N2 down V string 2 times. Unbad veloctiy string to flow back tank, well went to 0 psig. left 0 psig on top of velocity string. Returned well to production at 2.4 MM. Unable to get v-string to flow. Start Time End Ttme Dur (hrs) Ops Code Fu~ivtty Code. Opa Status Trouble , . Coda Comment 08:30 09:30 1.00 SAFETY MTG_ AF . Prejob safety meeting. Issue permit. Discuss JSA. 09:30 1.1:00 1.50 RURD OTHR AF Well flowing at 1.8MM. Spot and RU N2 unit to pump down v-string. 11 a)0 11:15 0.25 TEST_ EOIP P test N2 iron to 2500 psi. Good #est. 11:15 12:00 0.75 PUMP_ N2_ AF Bullheaded 40 MSCF N2 down v-string a# 500 -1000 SCF/min while unloading welt to gas buster. Unloaded 5 bbls water. 12:00 13:15 1.25 BLOWDN COIL Open CT to gas buster with well closed. Well blew to 0 psi in 15 min. Observe well for 1 hour. no flow. Tubing pressured up to 960 psi. 13:15 14:45 1.50 PUMP_ N2_ Gooled down and pumped 80 MSCF N2 down v-string at 1000 SCF/min. _ Unloaded 5 bbls water. 14:45 15:30 0.75 BLOW DN COIL Open CT to gas buster with well closed. Well blew to 0 psi in 10 min. Observe well for 45 minutes. No flow. Tubing pressured up to .960 psi. 15:30 1.6:00 0.50 RURD_ OTHR AF Shut in operation. Velocity sirijng at 0 psig. Well flowing up the annulus at 2.4 MMCFPD, 382 psig. Re ort Oate: 4/11/2008 Job Cate o R8M 24 H S MAINTENANCE r ummary - MIRU Pollard to tag TD and run PT Survey. Must disconnect piping and electrical in order to remove well house and proceed with slick line job. Stert-Tlrne End:rime , ;. Dur(hrs ^ -- OpaCode _ , . Aoi{yftyCode ,,,- Stews.,. . Code: ,.s 3 ~.u=~.- ~,:"~ ~~ ~..-- .::Commont~~;-- . .~ •;,. ~ ~ ~:,,. 07:55 08100 0.08 PREP_ LOC_ AF . _ , . , „ Artive on location. Check out well house. See that well house hatch is not aligned with tree. Will have'to RD 2"" chicksan to tree cap and 2"" blow down line to gas buster. Need an electrician to diconnect power to instrumentation and well house. 08:00 08:15 0.25 PREP_ LOC_ AF Sign in at office. Discuss situation with number 1 operator. Call Roustabouts and electrician from KGF-none in BG. 08:15 09:15 1.00 PREP_ LOC_ AF Run out to BC-1A with operations to scope out situation and develops a plan of action. Wait on electrician and Roustabouts. 09:15 10:15 1.00 SAFETY MTG_ AF Electrician and Roustabouts arrive. Discuss action plan. Discuss both crafts' JSA's. Obtain Hot work permit. obtain Safe Work permit far Slick line. 10:15 11.:45 1.50 PREP_ LOC_ AF Rig down chicksan lines and bull plug terminated openning to BC-14. Cut well house, below pipe peniiration so we do not have to disconnect heat trace and break 2"" bbw down line. Disconnect instrumentation electrical to control panel routed thru 4""pipe with V2"" wall penitration). Knock pipe out of penitration and cut Penitration io ground level. Will no longerhave to disconnect this line to remove well house. Will not need an electrcian tomorrow. 11:45 11:50 0.08 SECURE WELL ~~ AF Decide it is to late. to proceed with well house removal ,conduct slickline job, and replace well house today. Postpone jab until tomorrow. Release Pollard. Secure location. Sign out and leave loc.. Re ort Date: 4111!2008 Job Cate ~_WELL INTERVENTION 24 H S ---- r ummary ------- --- -_---- MIRU Pollard to tag TD and run PT Survey. Must disconnect piping and electrical in o>•der to remove well house and proceed with slick line job. Start Time: End Time Dur(hrs) Gps Gode Actldty Gode. Ops Status 'Trouble Code Comment 07:55 08:00 0..08 PREP_ LOC_ AF Arrive on location. Check out well house. See that well house hatch. is not aligned with tree. Will have to RD 2"" chicksan to tree cap and 2"" blow down line to gas buster. Need an electrician #o diconnect power to instrumentation and well house. _ 08:00 08:15 ~ 0.25 PREP_ LOC_ AF Sign in at office. Discuss situation with number 1 operator. Cali - -- Roustabouts and electrician from KGF-none in BC. - __._ www.peloton.com Report Printed: 8/8/2008 r~ r Operations Summary Report Well Name: BEAVER CREEK 7A Stara Tlma End T1me Dur rs Ope Cade Aotlvily Code... Ops` ..Stable Trouble Code Comment 08:15 09:15 1.00 PREP_ LOG AF <.. , .. .. .: . Run out to 8C-1A with operations to scope out situation and develope a plan of action. Wail on electrician and Roustabouts. 09:15 10:15 1.00 SAFETY MTG_ AF Electrician and Roustabouts amve. Discuss action plan. Discuss both crafts' JSA's. Obtain Hot work permit, obtain Safe Work permit for Slick _ r. _. _ line. 1 :15 11:45 _ 1.50 PREP_ ~~ LOC_ AF Rig down chicksan lines and bull plug terminated openning to BC-14. Cut well house, bebw pipe penitration so we do not have to disconnect heat trace and break 2"" blow down line. Disconnect instrumentation electrical to control panel(routed thru 4""pipe with 112"" wall penitration). Knock pipe out of penitration and cut penkration to ground level. Will no longer have to disconnect this line to remove well house. Will not need an electrician tomorrow. 11:45 11:50 0.08 SECURE WELL AF Decide it is to late io proceed with well house removal, conduct slick line job, and replace well house today. Postpone job until tomorrow. Release Pollard. Secure location. Sign out and leave loc. DailyOperations Re art Date: 4/12!2008 Job Cate o R8M MAINTENANCE 24 Hr Summary -- Pick welt house. MIRU Pollard to tag TD and run PT to determine fluid level and possibly gas entry point behind V-string. WHP 825 psi. Well flowing up V-string annulus @.384 psi 1792 mscf/d. RIH w/ PT thru V-string. Tag end of V-string @ 8556' KB. Start Tlme i Fsd Tlme Dur (hns) Ope Code ActlN Code. - Ope Statue Trouble Code r; : Comment: ., " ' 08:00 08:50 0.83 SAFETY MTG_ AF . _ Arrive loc. Hold PJSM. Discuss lift plan to remove well house. Discuss Pollard JSA and job scope. 08:50 09:15 0.42 PREP_ LOC_ AF Spot Masi truck and attach rigging. Pick well house. 09:15 09:45 0.50 RURD_ SLIK AF Spot equipment. PU lubrigtor. Rehead line. MU 1"" tool string. 09:45 _ 09:55 0.17 RURD_ SLIK. AF Carry lubricator to tree. WHP 825 psi. 09:55 10:10 0.25 TEST_ EOIP AF Low pressure PT w/WHP. PTest lubricator #01500 psi. Test good. 10:10 . 10:25 0.25 RUNPUL SLIK Af Open swab valve. RIH. Set down at 1T wlm. Cann't get past. POOH. 10:25 10:35 0.17 RUNPUL SLIK AF Shut well in. Bleed lubicator. PU more 8' of stem 10:35 10:55 0.33 RUNPUL SLIK AF . RIH wl 1.25"" GR. Tag TD @ 8556' KB. 10:55 11:10 025 RUNPUL SLIK AF POOH. 11:10 11:20 0.17 RURD_ SLIK AF OON. Bleed. lubricator. PU Dual tandem pressure temperature gauges. 91::20 11:25 0.08 RUNPUL SLIK AF Start 5 minute bench. @ surface 91:25 13:37 _ 2.20 .RUNPUL SLIK AF . RIH @ 60 fpm to 8500' 13:37 13:42 0.08 RUNPUL SLIK AF Start 10 minute bench @ 8500' KB. 13:42 15:45 2.05 RUNPUL SLIK AF End bench. POOH @ 60 fpm. 15:45 15:50 0.08 RUNPUL _ SLIK AF @ 21' Start 5 min bench. 15:50 16:36 0.77 RURD_ SLIK AF RD lubricator and tool string. Install tree cap and Ptest; Test good. 16:36 16:45 0.15 SECURE WELL AF Secure well. Replace Well house. - Re ort Date: 411212008 Job Cate o WELL INTERVENTION 24 Hr Summary - Pick well house. MIRU Pollard to tag TD and run PT to determine fluid level and possibly gas entry point behind V-string. WHP 825 psi. Well flooring up V-string annulus @ 384 psi 1792 mscf/d. RIH w/ PT thru V-string. Tag end of V-string @ 8556' KB. Start Time. EndTima. .Dur hia) OpaCode Act! Code . ~ Ops, .Status Tnwble Code .~ 'Comrr~6nt '~ 08:00 08:50 0.83 SAFETY MTG_ AF , Arrive loc. Hold PJSM. Discuss lift plan to remove well house. Discuss _ Pollard JSA and job scope. 08:50 -- 09:15 _ _ 0.42 PREP - - LOC_ AF Spot mast truck and attach rigging. Pick well house. 09:15 09:45 0.50 ~ RURD _ __ SLIK AF _ __ __ Spot equipment PlJ lubricator. Rehead line. MU 1"" tool string. 09:45 09:55 _ 0.17 RURD_ _ SLIK AF _ Carry lubricator to tree. WHP 825 psi. 09:55 _ 10:10 ~ _ _ 0.25 ~ TEST _ _ _ EQ1P ~~ AF __ _ _ ~ ~ Low pressure PT w! WHP. PTest lubricator to 1500 psi. Test good.~~ 10:10 10:25 0.25 RUNPUL _ SLIK ~~ qF _ Open swab valve. RIH. ~-~ -- _ _ _ Set down at 1T wlm. Cann't get past. POOH. 10:25 10:35 0.17 RUNPUL - SLIK AF Shut well in.~ Bleed lubicator. PU more 8' of stem. ~ ~ - 100:35 10:55 ~ 0.33. - RUNPUL SLIK AF RIH w/ 1.25"" GR. Tag TD @ 8556' KB. __._ _ 10:55 11 10 ~ 11:10__ 11 0.25 RUNPUL SLIK- AF ~ Y POOH-- ---- - ---_.. ____ _ _~_._. _ _ .. : 11 20 ~ :20 11 2 0.17 KURD SLIK AF ~ OOH. Bleed lubricator. PU Dual tandem pressure temperature gauges. : ~ : 5 . 0.08 RUNPUL SLIK AF Start 5 minute bench @ surface. - --~- - - 11:25 _ 13:37 2.20 RUNPUL SLIK AF RIH @ 60 fpm to 8500-- ---_ _____ _.. _. __ __ _ _.__ - - 13:37 13:42 0.08 RUNPUL - SLIK AF ~ Start 10 minute bench @ 8500' KB. __.___ ___._ _ ___ _ _ www,peloton.com Report Printed; 818/201)$ r' Operations Summary Report Well Name: BEAVER CREEK 1A SiartTime End Time Durhrs 0 sCOde. AcIM Code Opa statue Trouble Code Comment 13:42 15:45 2.05 RUNPUL SLIK AF .- End bench. POOH @ 60 fpm. 15:45 - 15:50 0.08 _ RUNPUL ___ SLIK AF @ 21' Start 5 min bench. 15:50 _ 16:36 _ _ -- 0.77 _ RURD_ _ - SLIK AF'y _ _ _._ _ RD lubricator and tool string, Install tree cap and Ptest. Test good w~~^ 16:36 16:45 0.15 -_ SECURE ~ ~ _ WELL AF _ _ . Secure well Replace Well house. - _ ..- _ -,-- ._..... ___,_.-_~_____.____v~ _____._._ __ Daily Operations Re ort Date: 5/4/2008 Job Category: WELL INTERVENTION 24 Hr Summary _-__._~_ _ -_----. __ _ __ _ _ MIRU pump unit. PT lines to 2500 psig. Open v-string and pump down V string while flowing up annulus to open top tank. Made 4 attempts to unload fluid . Total N2 used 210 K, 25 bbls to flow back tank. Well flowing at 850 MCFPD when tuned inotto sales Start llma Erin Time Dur tus) Opa Code AdhA Cale Ops Steam Trouble" Code Comment 08:00 08:45 0,75 SAFETY MTG_ AF BJ pumping crew on location with pump and N2 unit. Obtain work permit, held PJSM prior to moveing on well head. Discussed procedure and safety concerns. 08:45 10:00. 1.25 JET_ N2_ AF Run hard lines to N2 pump, flow lines, to tree. PT all surface equipment to 2500 psig. Good test. 10:00 10:20 0.33 JET_ N2_ AF Cool down N2 unit. Open well and start puping .down V string with N2 opened up the annulus to flow back #ank. WHP= 1500 psig on both the V-string and the annulus 10:20 10:45 0.42 JET_ N2_ AF Start pumping N2 at 500 SCFM. Returns to flow back tank after 5 minutes of pumping. 10:45 10:50 0.08 JET_ N2_ AF Increased N2 rate up to 750 SCFM, still good returns to flow back tank.. Retums are gray and black. 10:50 11:30 0.67 JET_ N2_ AF ~ Shut down N2 injection. flowing annulus pressure at 350 psig; injection pressure down the V string @ 1130 psig. 1 i:30 11:50 0..33 FLOW_ BACK AF Monitor well, well head pressure down to 250 psig, annulus dropped to 100 psig, 4 bbls fluid to tank. 11:50 12:40 0.83 JET,_ N2_ AF Start N2 rate at 1000 SCFM down V string. Pump pressure at 1000 psig. Annulus pressure back up to 350 psig. Returns to tank, approx 5 gals minutes. Gray water. 12:40 13:10 0,50 FLOW_ BACK AF Shut down N2 injection, Flowing annulus pressure bleeding down from 350 psig. H2O returns dropped to trickle. 13:10 14:00 0.83 JET_ N2_ AF Start N2 rate back at 1000 SCFM down V string. Pump pressure down V string 850 psig. Annulus pressure back up to 320 psig.. Total returns to flow back tank = 16 bbis. 14:00 14:40 0.67 FLOW_ BACK AF Shut down N2 injection. Flowing annulus pressure at 300 psig, injection- pressure down the V string @..1100 psig, fUbnitor well. H2O returns. dropped to trickle. Well not responding well. 14:40 15:40 1.00 JET_ N2_ AF Start N2 rate back at 1200 SCFM down Vsfring. Pump pressure down V string 1250 psig. Annulus pressure back up to 320 psig. Running abort of N2. Retums around 3 gal minute. 15:40 15:50 0.17 FLOW_ BACK AF Lost prime to N2 pump. Total N2 pumped 210, OQO SCF. V string pressure down to 350 psig. Left well flowing #o open top tank. Flowing pressure at 250 psig. Small amount of returns. Total in flow back tank = 25 bbls. 15:50 16:00 0.17 CLEAN_ LOC_ AF ~ BJ rig down equipment, cleaned up around area. Left lease. 16:00 17;30 1.50 RURD_ OTHR AF Monitored well. Gas to flow back tank. Rolled the well to production _ pressure up to 350 psig. Well flowing at 850 MCFPD. Re ort Date: 5/6/2008 Job Cate o WELL INTERVENTION 24 Hr Summary - - RU N2 pump and lift well pumping down v-string. Well made 24 Bbls water. Well flowing at 630 MCF/day at 360 psi. StartTlme Entl Time Durthrs) Ops Code Activity Code . Ops Sfstus Tmubia Code Comment 09:00 10:00 1.00 SAFETY MTG_ AF BJ pumping crew on location with. pump and N2 unit. Obtain work permit, held PJSM prior to moveing on well head. Discussed procedure and safety concerns. 10:00 11:20 1.33 RURD OTHRm _ AF Run hard lines to N2 pump, flow lines, to tree. Open. well to tank. SIWHP = 1400 psi. 11:20 11;40 _ 0.33 RURD_ OTHR AF Cooi down N2 unit. 11:40 -- 11;50 0.17 TEST_ EOIP AF Tesi lines and valves to 2500 psi.i 11:50 13:00 1.17 JET_ N2 AF ~ Start N2 down v-string at 1200 scf/mini. Weil made 3.5 bbis before pumping . N2. www.peloton.com Report Printed: 818!2008 T Operations Summary Report Well Name; BEAVER CREEK 1A StartTima End Time Uur(hrs), ,, OpeCode AcBvl Code Ops Status Tmuble Code Cominant 13:00 14:10 1.17 JET_ N2,^ AF Shut down N2 injection. flowing annulus pressure at 400 psig, injection pressure down the V string @ 1340 psig. recovery total = 17 Bbls. Monitor well. 14:10 14:40 0.50 JET_ N2_ _ ~ AF ~~ Well made 1.5 Bbis in 1 hour. FTP = 100 psi. Resume pumping N2 at 1200 ._ scf/min. 14:40 15:00 0.33 FLOW_ BACK AF ~ Shut down N2 injection. Well flowing at 100 psi. Total water returns = 24 Bbls. 15:00 :15:30 __ 0.50 CLEAN_ LOC_ -~ AF ~ ~ BJ ri down -- - g equipment, cleaned up around area . Left lease 15:30 17:30 2.00 _ RURD_ _ OTHR ~ AF _ s . . Monitored well. Gas to flow back tank. Rolled the well to production ~~ ___ __ pressure up to 360 psig. Well flowing at 630 MCFJday. ' Daily Operations ----- _- _ _ --.---___-- Re ort Date: 51712008. Job Categor rte: WELL INTERVENTION 24 Hr Summary --v -- - ._ Set x-plug in nipple a# 8566 CTMD. Set prong in plug. Informed AOGCC of CT BOP test tomorrow.. Start 77me End Time .Dur hra Opa Code Acdvlty Coda Opa SteWa Tiouble Code Comment . 14:00 15:00 1.00 SAFETY MTG_ AF BJ pumping crew on k>cation with pump and N2 unit. Obtain work permit, held PJSM prior to moveing on well head. Discussed procedure and safety concerns. 15:00 17:00 2.00 RURD_ SLIK AF ~ Spot and RU slickline unit. PU 1.25"" PXN plug. Pull well house with. Udelhoven crane. 17:00 17:20 0.33 TEST_ EQIP . Test lubricator with McOH to 2500 psi. Good Test. 17:20 22:00 4.67 RUNPUL SLIK AF Run 1.25"" PXN plug body and set at 8576' SLM after 3 attempts. 22:00 22:10 0.17 TEST_ EQIP AF Test quick test sub to 2500 psi. 22:10 22:45 0.58 RUNPUL SLIK AF Run and sefi prong in PXN plug baly. POH. 22:45 23:30 0.75 RURD_ _ SLIK AF RD and release stlckline unit. Sign out and leave location. Re ort Date: 5/8/2008 Job Cate o WELL INTERVENTION 24 Hr Summary Spot and RU CTU. Test lines /valves / BOP to 250/4500 psi. AOGCC waived BOP witness. Tested x-plug to 2000 psi with N2. ' ~ opa Trouble `^ ~~,r ~. ., ,. : . StartTime.• E[id Tlme Dur • ~ ' Opa Code Actlvi Code Status: Code ~ "" t 07:00 07:01 0.02 WORK COIL AF Notlfled Jim Re AOGCG, about he CT 99, 6©P test on Tuesday around 1:00 PM on BC-1A. He waved the witness on Wednesday morning at 9 AM. 07:01 08;00 0.98 SAFETY MTG_ AF Move in equipment. Obtain. work permit and held PJSM. 08:00 14:00 6.00 RURD_ COIL AF Spot and RU CTU. 14:00 15:30 1.50 TEST_ ROPE AF Test lines, valves, and SOP 250 psi bw and 4500 psi high. Good test. 15:30 17:00 1.50 RURD_ COIL AF MU CT BHA. 17:00 17:20 0.33 TEST_ EQIP Pressure up Ct to 2000 psi with N2 to test x-plug. Plug holds. 17:20 18:00 0.67 SECURE WELL AF _ Secure location. Close permit, sign out, and leave location. Re ort Date: 5/9/2008 Job Cate o WELL INTERVENTION 24 Hr Summary Attempt to land hanger. Unable to get a test in several attempts with 2 different. hangers. Will make locator sub in AM and rerun hanger. Hanger is )n tree. Start Time End Time Dur (hrs) Ops Code Activity Code OPs Stahia Tmub e Coda . ; _ ` , Gommant`' 07:00 08:00 1:00 SAFETY .MTG_ AF Obtain work permit and held PJSM. Discuss BJ JSA, safety checklist, .and assign jobs. 08:00 11:00 3.00 __ RURD_ COIL AF Stab pipe. MlJ BHA. Stab on to well. 11:00 _ 1 t:15 _ 0.25 TEST_ EQIP AF _ ~ Shell test lubricator to 1000 psi. __ _ 11:15 12:00 _ _ 0.75 RUNPUL _ COIL AF ~ Open well and attempt to latch v-string hanger. POH. ~ '- _ _ _ __ _ _ _ 12:00 14:30 250 WAITON EQIP GS pulling tool )s worng. Cali forcorrect pulling _ tool. . 14:30 23:30 9.00 RUNPUL COIL Attempt to land hanger: Unable. to gel seal. SD for night. - _ 23:30 00:00 0.50 SECURE WELL ~ AF _ Secure location. Close permit, sign out, and leave location. Report Date: 5h 012008 Job Category: WELL INTERVENTION -- 24 Hr Summary ~ --- - --- ---- Pull and rerun hanger. Got a good test. RD CT and RU slickline. Unable to get past 1' below hanger wish 1.25"" tools. Can pass with 1"". SD job for night. Will pull hanger and cut CT in AM. Start Time End Time Dur (hrs) - Ops Code. Acflviiy Code Ops Status Tmuble Code Comment ' 09:00 10:00 L00 SAFETY MTG_ AF Obtain work permit and held PJSM. Discuss BJ JSA, safety checklist, and assign jobs. 10:00 71:00 1.00 RURD_ COIL AF RU Ct and stab on to well with 3"" GS pulling tool. I 11:00 11:15 0.25 TEST_ EQIP AF Shell test lubricator to 1000 psi. www.peloton.com Report Printed: 8/8/2008 - ~ Operations Summary Report ~ - Well Name: BEAVER CREEK 'IA Start=Time End`TUne Dur(hrs) OpeCode aenrityCotia Ops stews Trouble Code Comment 11:15. 12:45 _ ~ 1.50 RUNPUL COIL AF Latch Hanger. PU and set in slips. Pump off GS spear 12:45 13:30 0.75 _ RUNPUL COIL - ~~ __ ~ _ __ ~ . Replace damaged hangerwith new hanger Stab on well ~ v 13:30 ~ 14:00 0.50 RUNPUL ~ COIL . . __ _ Land hanger with marks on Ct and lock wdh lockdown screws 14:00 14:15 _-. _ __ 0.25 ~ TEST ~ _ EQIP ' ~ ~ _ _ - _ ~ . PT hanger seals to 5000 psi. Good test. -~ ~T _A- 14:15 - 14:30 0.25 __ _ RUNPUL ~ _ COIL __.._.._ _.__a ~. _.---~~._~~_______._. Pump off GS and POH. Close swab. 14:30 15:00 0.50 w _ RURD _ ~ COIL ~ v _" __ Rig back injector and start rigging down CTU, ~ -- - 75:00 -- 16:00 1.00 RURD SLIK __ RU slickline to pull x-plug. ----^ ~~"" " "" 16:00 _ 16:45 0.75 _ __ RUNPUL _ SLIK _ RIH 1.25"" SD pulling tool. Tagged 1' below hanger. worked tools. Can pass with. 1"" but 1.25"" gets stuck below :hanger. Shut down for night 16:45 18:00 1.25 SECURE WELL - AF _. -- - Secure location. Close permit, sign out, and leave location. Dally Operations Re ort Da#e: 5/1112008 Job Cate o WELL INTERVENTION 24 Hr Summary --- Pu11 and rerun hanger. Got a good test. RD CT and RU slickline: Unable to get past 1' below hanger with 1.25"" tools. Can pass with 1""_ SD job fornight. Will pull hanger and exit CT in AM. Startllme End Time Dur ra - Ops Code Actl Code Ops Slaws Trouble Code ._, Carrenent 07:00 08:00 1.00 SAFETY MTG. AF Obtain work permit and held PJSM, Discuss BJ JSA, safety checklist, and assign jobs. 08:00. 10:30. 10:30 10:45 2.50 0.25 RURD_ TEST. COIL EQIP AF AF RU Ct and stab on to well with 3"" GS pulling tool Shell test lubricator to 1000 psi. 10:45 11:30 13:00 13:30 11.:30 13:00 93:30 13:45 0.75 1.50 0.50 0.25 RUNPUL RUNPUL RUNPUL TEST_ COIL COIL COIL EQIP AF _ ~ Latch Hanger.: PU and sei in slips. Pump off GS spear. Replace damaged hangerwith new hanger. Stab on well Land hanger with marks on Ct and lock with lockdown screws. PT hanger seals: to 5000 psi. Good test. ' - 13:45 14:00 0.25 RUNPUL COIL Pump off GS and POH. Close swab. URD_ _ _ _ COIL ~ Rig back injector and start rigging down CTU. 15:00 15:30 0.50 R URD_ SLIK RU slickline to pull x-plug. 15:30 15:40 0.17 TEST_ _ EQIP _ Test lubricator. 15:40 17:00 1.33 RUNPUL SLIK RIH 1.25"" SD ulli tool to 8264' WLMD 2 times. Unable to latch. 17.:00 19:00 2,00 RUNPUL SLIK RIH 1 "" pump bailer 3 trips. Some clay recovered. Will continue in AM with 1.25"" DD bailer. 19:00 20:00 1.00 SECURE WELL AF SecureJocation. Close permit, sign out, and leave location. Re rt Date: 5!12/2008 Job Cate o WELL INTERVENTION 24 Hr Summary Rigged up slickline and made 11 bailer runs from 8.2ti9' to 8,287. Recovered about 1 gal solids. Made 3 runs with SB pulling tool and were unable to latch x-plug. Start Time End Time Dur hra 0~ s Coda ActlNty Code Opa Status Trouble Code ,, ,_ - Comn~nt 07:00 07:30 07:30 07:50 0.50 0.33 SAFETY RURD_ AATG_ COiL AF AF Obtain work permit and held PJSM. Discuss Pollard JSA and assign jobs. PU Pollard lubricator and stab on. 07:50 08:00 0.17 TEST_ EQIP AF Shell test lubricator to 1000 psi. 08:00 18:20 10.33 RUNPUL. COIL AF RIH 14 runs with 1.25"" bailer and SB pulling tool with no success. 18;20 19:00 0.67 SECURE WELL AF Secure location. Cbse permit, sign out, and leave location. _ _ Report Date: 5/13/2008 Job Category: WELL INTERVENTION _. ---- 2 4 Hr5ummery - -- RU Pollard to pull X Plug and prong. Continue bailing -tag fill @.8280' and bail down to 8296'. . Start Time,.: . End 7lme Our hrs) Ope Code Actl .Code.:.. Ops Stews T~ubia Coda _.. Comment 09:00 09:45 _ 0.75 _ _ SAFETY MTG_ AF Obtain work permit and held PJSM. Discuss BJ JSA, safety checklist, and assign jobs. 09:45 -_ _ 10:00 0.25 _ _ _ _ RURD ~ SLIK -- AF ~ -- - PU lubricator. MU tool string. rope socket, 5' wt. bar,. knuckle jt„ 10' wt. bar, knuckle jt., hydraulic jars, spang jars, 8' DD bailerw/ flapper. 10:00 10:10 10:50 ~ 10:55 11.45 11:50 ~ 10:10 10:50 10:55- _ 11:45 11:50 12:35 _ 0.17 0.67 0.08 0.83 0.08 0,75 TEST _ ~ RUNPUL " RURD_ RUNPUL _ RURD_ RUNPUL ~ EQIP SLIK SLIK SLIK SLIK SLIK AF AF AF AF AF AF __ _- --- ____.-__._sm_ ____.. __._ _.... PTest lubricator, Test good. RIH (1) w/ 1-114"" DD bailer. Tag @ 8280' wim. Work tools. POOH. OOH. Recover 1.14 cup sand and fines. RIH 2 w/same. Ta --_-__ __ - _ () g @ 8284' wlm. Work tools. POOH. OOH. Recover 1/4 cup sand and fines. ~ RIH (3) w11-114"" DD bailer w/ ball check. Tag @ 8285' wlm. Work tools. POOH. www.peloton.com Report Printed: 8/8/2008 Operations Summary Report Well Name: BEAVER CREEK 1A Start Time End Time Dur hra) Opa Code , Activl .Code OPa Statue.. Trouble Code Comment 12:35 ~ 12:45 --- 0.17 RURD_ SLIK AF OOH. Recover 1!4 cup sand and fines 12:45 13:30 -- -- --- -- . 0.75 RUNPUL SLIK AF RIH (4) wl 1-1/4"" DD bailer w/ ball check. Tag @ 8288' wlm. Work tools. __ _ __ POOH. 13:30 13:40 - 0.17 RURD_.._ -- SLIK._-__--- AF - -- OOH Recover 1/4 cu sand d fi s - ~- - "~ ~" -~- 13:40 14:20 -- _ ~ 0 67 _ _ _ ~ _ --~~ . p an ne . . RUNPUL SLIK AF RIH 5 wJ 1-1/4"" DD bager w/ fla er. Ta - () PP 9 @ 8289 wlm: Work tools. _ POOH. 14t20 _ 14:30 _ 0.17 RURD_ __.._ - SLIK ---__ AF -- --- _. OOH. Recover 1 cu ___ ___ _ __. _ ___- _.___ _ p pastey c a nes 14:30 15:05 0.58 RUNPUL _ SLIK ~ AF y . RIH (6) w/ 1-1/4"" DD bailer w/flapper. Tag @ 8290 wim. Work tools. ~ ___ POOH.. ""Sticky"" 15:05 _ 15:11 0.10 RURD_ SLIK_ ~~ ~ _ RF OOH. Recover 1 eu "---" -- p pastey clay fines. 15:11 15:55 0.73 RUNPUL _ SLIK __ AF RIH {7) w/ 1-1/4"" DD bailer w! flapper. Tag @ 8290' wlm, Work tools. POOH. 15:55 16:D5 0.17 _ RURD_ SLIK AF OOH. Recover 1 qt clean water - 16:05 16:45 . 0.67 RUNPUL SLIK AF RIH (8) w/ 1-114"" DD bailer w/ flapper. Tag @ 8294' wim. Work tools. POOH. 16:45 _ 16:50 0.08 RURD_ SLIK AF OOH. Recover 1/2 cup pastey clay fines. Metal marks on bailer bottom. _ Possible friction bite coming off bottom. 16x50 17 10 17:10 1 0.33 RUNPUL SLIK AF RIH (9) w/ 1-1/4"" RS Overshot. Tag @ 8296' wim. Work tools. POOH. : 7:25 0.25 RURD_ SLIK AF No bite on latch. POOH. 17:25 17:45 0.33 RURD_ SLIK AF OOH. LD tools for the night. 17:45 17:55 0.17 SECURE WELL AF Securewell head and location for the night.. Sign permit and tum in. Sign out and leave loa Daily Operations Re ort Date: 5/14!2008 Job Cate o WELL INTERVENTION 24 Hr Summery _ RU Pollard to pull X Plug and prong. Continue bailing -tag fill @ 8292' and bail~down to 8305'. WHP 50 psi. V-string annulus pressure 1250 psi. _ ' StartTlme 07:30 Erid Time 07:50 Dur(hia 0 33 ~. A Code SAFETY Adt Coda MTG Dps Status Trouble Cade-. :. .... _" - .,,~ ,. -- Comment ... ,, ~ ~ `~ ~ ' . _ AF Obtain work permit and held PJSM. Discuss BJ JSA, safety checklist, and assign jobs. 07:50 08:15 0.42 Cut 5D' of wire and rehead stuffing box. 08:15 08:30 0.25 RURD_ SLIK AF PU lubricator. MU tool string. rope socket, 5' wt. bar, knuckle jt., 10`wt, bar, knuckle jt., hydraulic jars, spang jars, 8' DD bailerw/flappar. 08:30: 08:40 0.17 TEST_ EQIP AF PTest lubricator. Test good. 08:40 D9:15 0.58 .RUNPUL SLIK AF RIH (1) w/ 1-114"" DD bailer. Tag @ 8292' wlm. Work tools to 8295' wim. POOH. 09:15 09:25 0.17 RURD_ SLIK AF OOH. Recover 1/4 cup clay fines. 09:25 1D:10 10:10 10:20 0.75 RUNPUL SLIK __ AF RIH (2) w/ same. Tag @ 8294' wlm. Work tools to 8298' wlm. POOH. 0.17 RURD_ SLIK AF OOH. Recover 1!4 cup. sand and fines 10:20 10:55 0.58 RUNPUL SLIK AF . RIH (3) w/ 1-114"" DD bailer w/ ball check. Tag @ 8295' wim: Work tools to 8300' wim. POOH. 10:55 11:00 0.08 RURD SUK AF OOH Recove 1/4 d ~- 11 00 _ . r cup san and fines. : 1 i:45 0.75 RUNPUL SLIK AF RIH (4) w/ 1-114"" DD bailer vr/ ball check. Tag @ 8298' wlm. Work tools to 8303' wlm. POOH. 11:45 11:5D 0.08 RURD SLIK AF OOH. Recover 1/4 cup sand and fines. 11:50 12:35 0:75 RUNPUL ___ SLIK _ AF __ RIH (5) w/ 1-1/4"" DD bailer w! flapper. Tag @ 8298' wlm. Work tools to _ 8303' wlm. POOH. 12:35 12:45 D.17 _ RURD_ SLIK AF OOH. Recover i/4 cu ~--- ---~~- p pastey clay fines. 12:45 13:30 0.75 RUNPUL ___ SLIK - AF ~ RIH (6) w/ 1-1/4"" DD baiter w/flapper. Tag @ 8296' wlm. Work tools to __ ~ 8302' wim. POOH. 13:30 13:40 _ - 0.17 ~~ _ _ RURD_ SLIK ~ AF ~~ OOH. Recover 1/4 cup aste cl fines 13:40 14;10 0 50 L ----" _ _- __ p ay y . . . RUNPU SUK AF _ RIH (7) w! 1-1/4"" RS Overshot. Tag @ 8294' wim. Work tools to 8304' - wim. Could not latch into prong POOH 14x0_ ~ 14:20 _ - - 0.17 - RURD _. _- - SLIK_ - ~ AF _- _ _.._ _- ., . OOH. PU 1-114"" DD bailer. - -__.~_. _ _.._. 14;20 15:00 0.67 RUNPUL -~- - SLIK ~ _ AF_ ...m . _ ._.. ___ __ RIH 8 w! 1-1/4"" DD bailer w/ fla ~-~ ~~`- O pper. Fluid level @ 3360'. Tag. @ 8296' - - wlm. Work cools to 8303' wlm: POOH. 15:00 1 5:05 0.08 RURD_ - SLIK AF _ OOH. Recover 1/4 cup pastey clay fines 15:05 1 5:50 0.75 RUNPUL SLIK AF , RIH 9 w/ 1-1/4"" DD bailer w/ fla -- - - - --- -- ~--- () pper. Removed 3' exiension. Tag @ 8304' wlm: Work tools. POOH. 15:50 1 6:00 _ 0.17 RURD_ S LIK- AF OOH. Recover 114 cup pastey clay fines 16:00 1 6:30 0.50 RUNPUL S LIK A F 1 ~ . RIH (10) w! 1-1/4"" RS Overshot: Tag @ 8301'. _ --- _. www.peloton.com Rennrl Printnrl• A/R/9(1(IR Operations Summary Report Well Name: BEAVER CREEK 1A Start Time End Tiirus Dur his) Ops Code AcNNty-Code Ops Statue Trouble Code Comment . 16:30 16:35 _ _0.08 RURD_ SLIK AF OOH. PU 1-1/4""DD bailerw/flapper. ~ _ _ _ 16;35 17:20 0.75 RUNPUL SLIK AF RIH (11) w/ 1-114"" DD bailer w/ flapper. Tag @ 8304' wlm. Work loots to 8305' wlm. POOH, 17:20 17;45 - ~ 0.42 RURD_- - SLIK - -- AF -- OOH. LD tools for the night. ~-.___ _._ - - "-- - -_. __. _ ._.__ ___ - - - _ ___ _ 17:45 18:00 0.25 SECURE WELL _ _._ AF Secure well head and location for the night. Sign permit and turn in. Sign out and leave loc. Daily Operations Re ort Date: 5/1912008 Job Category: R8M MAINTENANCE - 24 Hr Summary - MIRU wire line unit; RIH wirh bailers, 1.25" SB to try and latch top of prong, Could not latch. RIH with LIB, no impression of top of fish. Lay down for night. Ops Trouble .Start Tlme End T(ma Dud hrs Ops Code ActiNry Code Sia_tus Code Comment 08:00 09:00 1.00 SAFETY MTG AF Obtained work permit, discussed JSA and held safety meeting. 09:00 10:00 _ 1,OU RURD SLIK AF __ Spot equimpent. MU lubricator and 1.25" tool string with DD bailer. 10:00 11:00 1.00 RURD SLIK AF MU high pressure pump to lubricator. PT lubricator to 1500 pstg. Good test, open well. WHP= 0 pstg. Annulus = 1300 pstg.. 19:00 12:00 1.OD WORK SLIK AF RIH tag @ 8323' KBD. Work bailer, POOH. Very little fluid w/dark water. 12:00 13:00 1.00 WORK SLIK _ AF __ MU 1.25" LIB, RIH to 8323' KBD to 8324'.. POOH with LIB. OOH no marks on LIB. 13:00 14:00 1.00 WORK SLIK AF MU 1.25" Pump bailer. RIH to 8323' KBD. Work bailer.. POOH with bailer. _ Some fluid no solids. 14:00 15:00 1.00 WORK SLIK AF MU 1.25" hydrostaflc bailer, RIH to 8323' KBD. Sat down to shear disc, work tool. POOH. OOH dse did not shear no - no solids or fluid. 15:00 16:00 1.00 _ BAIL FILL AF MU 1.0" pump bailer. ,RIH to 8337 KBD. 94' deeper. Work bailer.. POOH, no solids in bailer. 16x00 17:00 1.00 WORK SLIK AF MU 1.25" SB. RIH to $33T KBD. Work SB to and latch roe .POOH, No ron . MU 1.0" LIB. RIH with~same. Tag @ 833 wt LIB. The face of the LIB has a couple. of nicks on face. 17:00 18:00 1.00 WORK SLIK AF MU 1..25" 3 prong grab, RIH to 8337 KBD. Work grab. 200 Ib over pull. POOH. No fish. MU 1.25" SB -RIH to 833T KBD. POOH no Drong, 18:00 19:00 1.00 WORK SLIK AF Lay down wire line lubricator and. secured well. Wire line crew left lease. Re ort beta: 5/20/2008 Job Cate o ' : R&M MAINTENANCE 24 Hr Summary RU Pollard. Pull 1.24" Prong Ops: : Trouble '- _ _ _,.,, s,. ,. -,-,'' : `r3'_ Start Time ~ End Time Dur (hra '. , . Ops~~Code AetlN Gods' - Stelae . Code - ~ ~ -. ; ~.. . ~" ' ~ ~ ~ Comment 1 ~ 07:30 08:30 1,00 SAFETY MTG AF , - Hold PJSM. Discuss Pollard JSA. Obtain Safe Work Permit. 08:30 09:18 0.80 RURD SLIK _ AF PU Lubricator. MU toot string.. PTEst lubricator to 1000 psi. 09:18 10:06 0.80 RUNPUL SLIK AF RIH(1) 1" Pump bailer. Fluid leve~3250'; Tag @ 8321' KB. 10:06 10:54 0.80 RUNPUL SLIK AF _ RIH(2) 1-1l4" RS . FL 3050'. Tag. (ri)8332'. No latch POOH. 10:54 11:42 0.80 RUNPUL SLIK AF RIH(3)1" pump bailer. Tag 8333' Kt3. POOh. Bailer MT. 11:42 12:30. 0.80 RUNPUL SLIK AF RIH(4)1" LIB. POOH. Clear impression of Fishing neck.. 12:30 13:18 0.80 RUNPUL SLIK AF RIH(5)1-1/4" RS. Latch prong. Jar. POOH. Pin sheared on RS. 13:18 14:06 0.80 RUNPUL SLIK AF . RIH 6 1-1/4" RS. Latch ron .Jar Pron free. POOH,. 14:06 14:54 - _ 0.80 RURD SLIK AF RIH(7) 1-3/4 LIB.. POOH. No metal marks. 14:54 15:48 0.90 RURD SLIK AF _ RIH(8) /w 1" Pump bailer. POOH. Recover 1/4 C mud 15:48 16:42 0.90 RUNPUL SLIK AF RIH(9) w/ 1" Pump bailer. Tag $336' K6. POOH. Recover 114 C mud. 16:42 17:30 0.80 RUNPUL __ SUK ~ AF . RIH(10) w/ 1" Pump bailer. Tag @ 8338KB. POOH. Recover 1/4 C mud. 17:30 18:18 0.80 RUNPUL SLIK ^ AF _ RIH(19) w/Short 1-1/4" bailer._FL 3050'. POOH. Bailer MT. 18:18 19:06 0.80 RURD _ SLIK __ . ~ AF Rig down. -~~~~- 19:06 19:18 0.20 __ SECURE WELL AF __ _ Secure well. Tum in pemit. Leave loc. -- - ._ - Re ort bate: 5/20/2008 Job Cate o WELL INTERVENTION 24 Hr Summary ---- --.- __ -.---..-.-___v__..._ RU Pollard. PuII prong. Continue bailing to pull X plug. Bait down to 8336' KB.. WHP 0 psi. V-string annulus pressure 1250 psi. StartTlme Fed Tlme Dur hrs Ops,Code ActlNty Code t7ps Status Trouble Cods Comment 07:30 08:00 0.50 SAFETY MTG_ AF Obtain work permit and held PJSM. Discuss BJ JSA, safety checklist, and _ _ _ _ _ ~ __ assign jobs. 08:00 08:15 0.25 RURD,_ SLIK AF PU lubricator. MU tool string. Rope socket, 5' stem, knuckle jt., 15' stem, p _ knuckle jt., hydraulic jars, spang jars, Pump bailer w/ flapper. 08:15 08:30 _ 0.25. ~ ~ TEST_ EQIP AF _ _. PTest lubricator to 1000 psi.. Test good. ~;.~, . - _ _. 08:30 09:25 0.92 RUNPUL SLIK ~ AF RIH {1) w! 1""Pump bailer. Fluid level 3050' Tag @ 8321' KB. Work tools. POOH. www.peloton.com Report Printed: 8/8/2008 Operations Summary Report Well Name: BEAVER CREEK 1A StertTtme End Time Dui (hrs , „ ,Ops Code Actlvity Code Ops Status Trouble Code. ,, Comment 09:25 _ 09:50 _ ~ 0,42 _ RURD_ SLIK AF OOH. Recover 1/2 gallon fluid. 09:50 _ 10:28 ~ __ 0.63 __ _ RUNPUL ~ SLIK _ AF _ __ ~ __ RIH (2) w/ 1-1/4"" R5. Fluid level 3050'. PU weight 415#. No bites. POOH. 10:28 10:37 _ 0.15 ~ ~ _ RURD_ SLIK AF OOH. 10:37 11:20 0.72 RUNPUL SLIK AF ~ RIH (3) w/ 1"" pump bailer w/flapper. Tag @ 8833' KB. POOH. 11:20 - 11:40 0.33 _ RURD_ ~ SLIK _ AF _ _ OOH. Bailer empty. 11:40 12:05 _ 0.42 RUNPUL. SLIK -' " AF__.~ - - -- - RIH (4)w/1"" LIB. Tag @ 8333' KB. POOH. ~~_~ - -__ ___ ,_.___ 12:05 12:15 _ 12:15 12:30 v __ ~_ 0.17 _ ~ 0..25 RURD_ RUNPUL SLIK _ SLIK ~ ~ AF _ ~ AF _ _ ~ OOH. LIB shows good impression of fishing neck of prong. RIH (5) w! 1-1/4"" RS. ~- 12:30 12:45 _ 0..25 RUNPUL ~ _ SLIK ~ ~ AF v -- -- Latch prong. Jar prong with spangs. Won't come loose. 12:45 13:00 0..25 RUNPUL SLIK AF _ Pulled off.. POOH. ------ 13:00 13:15 0.25 _ RURD_ SLIK ------- OOH. Sheared pin in RS. 93:15 14:15 1 A0 RUNPUL SLIK AF __ RIH (6) w/ 1-1/4"" RS. Tag @ 8332' KB. Latch prong. Jar on prong w/ spangs. Pull free. 14:15 14:20 0.08 RURD_ SLIK AF OOH. Recover ron . 14:20 14;48 0.47 RUNPUL SLIK AF RIH (7) w! 1-1/4"" LIB. Tag @ 8333' KB. POOH. 14:48 _ 15:00 _ 0.20 RURD_ _ SLIK AF OOH. No dearimpression on LIB. 15:00 15:40 0.67 RUNPUL SLIK AF RIH (8) w/ 1"" pump bailer w/ flapper. Fluid level @ 3050'. Tag @ 8333' KB. Work tools. POOH. 15:40 15:50 _ 0.17 RURD_ SUK AF OOH. Recover 1i4 cup dense clay fines. 15:50 16:25 0.58 RUNPUL SLIK AF _ RIH (9) w/ 1"" pump bailer w/ flapper. Tag @ 8336'KB. Work tools. POOH. 16e25 16:35 0.17 RURD_ SLIK AF OOH. Recover 114 cup dense clay fines and 1 pint of fluid. 16:35 17:10 0.58 RUNPUL SLIK AF RIH (10) w/ 1 "" pump bailer. Tag @ 8336' KB. Work tools. POOH. 17:10 17:20 0.17 _ RURD_ SLIK Af OOH. Recover 114 cup clay fines. 17:20 18:10 0.83 RUNPUL SLIK AF RIH (11) w/ 1-114"" DD bailer w! flapper. Fluid level 3070'.. Tag @ 8336' KB. Work tools. POOH. 18:10 18:35 0.42 RURD_ SLIK AF OOH. Bailer empty. LD tools for the night. 18:35 18:45 0.17 SECURE WELL AF Secure well head and location for the night Sign permit and tum'in. Sign out and leave loc. Daily Operations Re ort Date: 5/21/2008 Job Cate o R8M MAINTENANCE 24 Hr Summary RU Pollard. Pull 124" X Plug ~ , .. Startllrne EndTlme Dur(hrs _ .. Opa,Code Adlvl Coda Ops Status Trouble Code Comment< 07:30- 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA. Obtain Safe Work Permit. 08:30 09:18 09:18. 10:06 0.80 0.80 RURD RUNPUL SLIK SLIK AF AF PU Lubricator. MU tool string. PTest lubricator to 1000 psi. RIH(1)1" Pump bailer. Tag @ 8336' KB. Worktoois. OOH recover/ C mud. 10:06 10:54 0.80 RUNPUL. SLIK AF RIH(2)1" pump bailer w/ snorkle. FL 3050'. PU wt 440#. Tag @8336'. POOH. Bailer MT, no metal marks. 10:54 14:42 12;30 11:42 12:30 13:18 0.80 0.80 0.80 RUNPUL RUNPUL RUNPUL SLIK SLIK SLIK AF AF AF RIH(3)1-1/4" GS / 3' add/ stem. Tag 833E KB, Get 300# overpull. POOH. RIH(4)1-1/4" GS / 3' add/ stem. Tag 8336' KB. Get 400# overpulL POOH. RIH(5)1" hydrostatic bailer.. Tap down. Tools stuck. Spang out. OOH.. Disc did not shear. 13:18 14:06 0.80 RUNPUL SLIK AF RIH(6) w/ same. Tap down. POOH. Bailer full of mud. 14:06 15:06 1.00 RURD _ SLIK AF RIH(7) w! same. Tap down. FL 3100'. POOH. FL 3200'. Bailer full of mud. 15:06 16:06 1.00 RURD SLIK AF RIH 8 /w 1-1 /4" GS. FL 3350' and failin .Latch lu POOH. R over u 16:06. 17:06 1.00 RURD ~ SLIK AF - - - Rig down. _ __ 17:06 17:30 0.40 SECURE WELL AF ~ Secure well. Tum in pemit. Leave loc. - - - - -- ----~- ---,e ~-_ Re ort Date: 5/21/2008 Job Category_ WELL INTERVENTION 24 Hr Summary RU Pollard. Continue bailing to pull X plug. Bail down to 8336' KB.. W HP 0 psi. V-string annulus pressure 1250 psi. Pull X Plug. Turn well over to production to flow. StartTima End Time Dur rs) Ops Code Actlvi Code Ops StaWs Trouble Code Comment 07:30 08:00 0.50 SAFETY MTG_ AF Obtain work permit and held PJSM. Discuss BJ JSR, safety checklist, and assign jobs. 08:00 08:30 0.50 RURD SLIK ^ ~ Cut 50' of wire and rehead. www.peloton.com- _ - i Report Printed__ 8/8/2008 r~ Operations Summary Report Well Name: BEAVER CREEK 1A Sfart Time End Tlme r Dur hrs) Opa Code AcHvl Coda.. Ops Stag Tmuble Code Comment 08:30 08:50 0.33 RURD_ SLIK AF PU lubricator. MU tool string. Rope socket, 5' stem, knuckle jt., 15' stem, 08 50 09 00 knuckle jt., hydraulic jars, spang Jars, Pump bailer w/ flapper. : : _ 0.1.7 _ _, TEST_ EOIP AF PTest lubricator to 1000 psi. Test good. ~---~- Y"- " 09:00 09:50 0.83 _ RUNPUL _ ___ __ SLIK _ AF RIH {1) w/'I""Pump bailer. Fluid Ievei. 3050' Tag @ 8336' KB. Work tools. _ POOH. 09:50 10:05 0.25 RURD_ SLIK AF ~ ~ _ --- OOH. Recover 1/4 cup of clay paste and fluid 10:05 10:50 0.75 RUNPUL SLIK AF . R)H (2) w/ 1"" pump bailer w/ snorkle bottom. Fluid Ievei 30 '. PU wt. __ 440#. Tag @ 8336' KB. POOH. 10:50 _ _ 11:00 _ _ 0,17 RURD_ SLIK AF OOH. Bailer empty. No metal marks. ^~« ~i --~-~4- - " 11:00 11:35 0.58 _ RUNPUL SLIK AF _ RIH (3) w/ 1-1/4"" GS and 3' of additional stem. Tag @8836' KB. Work tools. Get 300# overpuil. POOH. 11:35 11:40 0.08 RURD_ _ _ SLIK AF _ __ OOH. No Plug. ------~~ _"" 11:40 12:25 0.75 RUNPUL SLIK ____ ^ AF ~ ~ RIH {4) vr/ 1-1/4"" GS. Work tools. 400# overpull. POOH. 12:25 13:10 0.75 RURD_. SLIK AF _ ~ OOH. No plug. 13:10 13:45 0.58 RUNPUL SLIK AF RIH (5) w/ 1 "" hydrostatic bailer. Tag @ 8336' KB. Tap down on tools. Tool stuck. Jar free. POOH. 13:45 13:55 0.17 RURD_ SLIK AF OOH. Bailer did not fire. Rerun.. -~~ 13:55 14:40 0.T5 RUNPUL SLIK. AF RIH (6) w/ 1"" hydrostatic bailer. Tap dovrn of tools. POOH. 14:40 14:50 0.17 RURD_ __ SLIK AF OOH. Bailer full of ""gased up"" siuny. 14:50 15:30 0.67 RUNPUL SLIK AF RIH (7) wi 1"" hydrostatic bailer. Fluid level @ 3100'. Tag @.8336` KB. Tap down on tools. POOH. Fluid Ievei 3200' and dropping.. 15:30 15:40 0.17 RURD_ SLIK AF OOH. Bailer full of "" Based up"" slurry. 15:40 16:30 0.83 RUNPUL SLIK AF RIH (8) w/ 1=1/4"" GS. Fluid level @ 3350'. Tag @8336' KB. Set down. PU and latch plug. Work tools. Spang plug free. POOH. 16:30 17:20 0.83 RURD_ 5UK AF OOH with X Pi RD. 17:20 17:30 0.17 SECURE WELL AF Secure well head and location for the night. Sign permit and turn in. Tutu well over to production operators. Sign out and leave loc. Daily Operations - Re ort Date: 6/13/2008 Job Cate o R8M MAINTENANCE 24 Hr Summary RU BJ N2 pumping unit, Pump N2 down velocity string to unload well. Opa Trduble ... ~ ~.,. SfartTithe FsdTima. Dtu tux) O Codey Ac1INtyCUtle. Statue Code ~ ,.~.,,,~„ Commant~~ _ J Y . ,,, 12:00 13:00 1.00 SAFETY MTG AF Held PJSM and discussed tnpping Hazardous around well head. 13:00 15:00 2.00 RURD OTHR AF Obtained work permit. Pressure test flow lines to 4000 psig. good test. 15:00 18x00 3.00 PUMP N2 AF Start pumping N2 down ve)ocitystnng. Open well to flow back tank. WHP on annulus= 1500 psig. Start N2 rate at 700 SCFM. PIP= 100 psig 98;00 21:00 3.00 PUMP N2 AF PIP increased to 850 psig. WHP= 0 psig. Returns to flow back tank after 30 minutes pumping. PIP @ 1100 psig. WHP on annulus = 200 psig. 21:00 22:00 1.00 PUMP N2 AF Returns slowed down. 22 bbl returns in flow back tank. PIP = 1000 psig, N2 at 700 scfm, 22:00 23:00 1.00 PUMP N2 AF Switched from pumping down velocity string to pumping down back side and taking returns #hrough the velocity string. no returns from V- string to open top tank. N2 rate at 700 psig .and climbing. 23:00 00:30 1.50 PUMP N2 AF Continued pumping down annulus and returns up velocity string. Pumped 100 K nitrogen down back side. PIP= 1500 psig with no flow to surface. no build in PIP, increased PIR to 1:500 SCFM for 10 minutes no change in _ returns to surface. S/D N2 pumping. 00:30 01:30 1.00 RURD OTHR ~ AF ! Total N2 pumped 160 K, no flow from Velocity string. RD N2 unit, lei well set over night and open annulus to flow back tank to unload. Cleaned up around well head. BJ left lease. Re ort Date: 6/20/2008 Job Catego~ R&M MAINTENANCE ~ ~ ~ _ ~~~~ --- -- 24HrSummary -~`______~_~___ ____ _ _ -- --_-_~ ®__. RU BJ N2 pumping unit, Pump N2 down velocity string to unload well. Start Time End77me Du~(hrs) OpsCode Actlvi Gode° Ops StsWs Tmuble Code CommenY- 08:00 _ __ 10:00 2,00 SAFETY MTG AF Arrive on location Hold safety meeting discuss JSA and issue ermit 10;00 10:30 t).Si) RURD OTHR ~ ~ AF _ . , p . Open well to tank. SIWHP = 1.350 psi. SICTP = 800 psi. RU N2 unit. ~~ 10:30 10:45 0.2b - TEST EQ1P AF P test N2 lines io 3500 psi 10:45 11:15 0,50 PUMP N2 AF _ . _ Pump N2 down V-string at 1000 5CF/min~with well open to tank. Pump _. ___... ._ __ __ Pressure 1500 psi. www.peloton.com Report Printed: 8!8/2008 Operations Summary Report Well Name: BEAVER CREEK 1A Ops Trouble „ Start Time End 71me Du[, hrs] Opa Code AcHNry Code Statue Code Comment 11:15 12100 0.75 PUMP N2 AF Water to surface in 30 min. Unload 17 Bbls water and. SD N2 to observe _ well. FWHP = 300 psi. N2 pressure = 1300 12:00 13:15 1.25 PUMP N2 AF Observe well. Well died and sat static. No gas, no water. Total recovery 18 bls. is own to 350 psi. 13:15 __ 14:15 - 1.00 PUMP N2 AF ___ Resume N2 at 1000 SCFlMin. Water to surface in 15 mina ~~~ 14:15 __ 15:00 _ 0.75 PUMP N2 __ ~ AF ~ SD N2. Total recovery 26 BBLS. CTP = 950 PSI, WHP = 250 psi. Well died _ .` quickly. 15:00 15:30 0.50 RURD OTHR AF i RD N2 unit and release crew. Well is dead. Daily Operations Re ort Date: 6/21/?008 Job Cate o RB~M MAINTENANCE 24 Hr Summary _ -- --- --- Opened well to tank while pumping soap and water. Well made about 500 MCF but no water, SIW. ~ T~uble Start lime End Time pur hra Opa Code ActlW Code S e Code Comrnant 11:00 11:45 0.75 SAFETY MTG AF Discuss job and JSA. Issue permit 11:45 14:45 3.00 FLOW _ TEST AF SIWHP = 1400 psi. CTP = 2300 psi (with soap and water injection) Open well to tank. Well blew down. Continued making gas but no water. 1-0:45 15:00 0.25 SECURE WELL AF SIW. WHP = 0, CTP = 1700. SD soap injection. Secure well and SD. Well built 100 psi in 10 min. Approximate rate = 500 MCF/day. Re ort Date: 7/5/2008 Job Cate o R8M MAINTENANCE 24 Hr Summery Install "new" tree cap. Ptest to 2500 psi. RIH w! 3/8" Dyna Coil to 8265' KB. (Bottom of V-string @ 8296'). Had foam to the flowbade tank @ 17:00. Increased water production signiflcan8y. - Start Time End Time Dur (hre) ~~ Opa Code Activi Code ps Stetua., rou e' Code; .....,~ _µ5L ,... ~. ~ },, .,,, . Comment , 08:00 09:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific. job hazards. 09:00 10:00 1.00 RURD OTHR AF RD 2" chicksan line to top of tree. Inorder to replace tree cap. 10:00 11:30 1.50 RURD COIL AF Spot equipment. Lay liner. RD old. tree cap. Install "new" tree. cap. 11:30 11:45 0.25 TEST EOIP _ AF Ptesttree cap to 2500 psi. Test good.. 11:45 12:00 0.25 RURD COIL AF Set Fluid Control. Valve to 3800 psi.(7455' tvd x 8.7 ppg x .052 = 3373 psi) plus 450 psi. Install tubing in pack off. Install and pull test BHA to 700 lbs. Cany injector to W H. MU pack off in tree cap. 12:00 12:30 0.50 RUNPUL COIL AF RIH (1j wl "stiff" BHA. Cann get into coil hanger of V-string. POOH. Install wobble! knuckle joint. 12:30 14.:00 1.50 RUNPUL COIL AF RIH (2) wt 3/8" Dyna Coil and knuckle joint to 8265' KB. (30' short of making it out he bottom of the V-string @ 8296` KB. Begin filling coil w/ foamer. Fill to tubing capacity plus 2 gallons. 14:00 15:30 1.50 RURD COIL AF ~ Land 318" D nacoii 8265' K .Set slips. Check Radagon packirxJ. Check hydraulic pack off (2000 psi.) Disassemble injector assembly jn order to remove coil. Set. coil spool. Temporarily run braided hose from Dyna Goil to Foamer skid. Connect power to skid and begin foamer injection @ 1 gallday. 45:30 16:00 0.50 SECURE WELL AF Secure well and location. Well heading and bringing back more water than observed earlier. Earlier the well was flowing more gas but not earring out much water. Foamer floating on top of flowback tank. Tum in permit. Sign out and leave loc. Re ort Date: 7!10/2008 Job Cate a R&M MAINTENANCE 24 Hr Summary Pull short cap string and. replace. with a longer one. RIH to 8330' KB. - Ops Trtwble - - Start Tinre End Tlme Dur hrs Opa Coda ActlNty.Gode Stable Code - - Comrrrent 08:00 09:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SWP. 09:00 _ 11:30 ~ 2.50 RURD COIL AF ~ ~~ ~ Spot equipment. Lay down liner. RU coil unit: PU coil. Stab coil in injector. Carry injector to WH. Release Radigart packoff. 11:30 12:42 1.20 RUNPUL COIL ~ AF Pull coil OOH from 8265' KB.( 1700 lbs.) 12:42 14:42 2.00 RURD COIL AF OOH. Shit swab valve. Cap coil. Set spool down. PU replacement spool. Redress packoff. Check Fluid control valve. Set for 4000 psi. (7500' tvd X 8.7 ppg X .052 = 3393 psi) plus 500. Install and pull test BHA to 700 lbs. Carry injector to WH. 14:42 15:42 1.00 RUNPUL COIL AF ---- RIH (1) Can't get thru V-string hanger. POOH. InstaN wobble joint. www.peloton.com Report Printed: ti/8/2008 Operations Summary Report Well Name.: BEAVER CREEK 1A OPs Trouble StsrtTime End Time Dur(hrs) D sCOde AdMtyCode Status Code Comment 15:42 17.:57 2.25 RUNPUL COIL AF RIH (2). Work coil and shake injector. Finally able to get into V-string hanger. Rlti to 8330' KB. 1]:57 18:57 1.00 RURD COIL AF Land capillary string af8330' KB, Set spool Connect to Foamer skid and _ _ _ ~^ start injecting foamer. RD unit and equipment. 18:57 19:27 0.50 SECURE WELL AF Secure well head. Post signage. Ask operator to LOTO swab and master valves. Clean up location. Turn in permit.. Sign out. www.pel oton.com Report Printed; 8/8/2008 #: 167-009 50-133-20006-00 :y Des: A - 028083 ration: 153' (16.8' AGL) ate: 3/13/1967 ched: 6/13/1967 Camco Injection Mandrel @ 898' 1-314" QT-700 0.125" wall 1.40" ID Toe Bottom MD 0' 8,296' ND 0' 7,455' 2.50" BHA wl: Grapple 10' Straight bar 1.25" PXN nipple 1.75" Re-entry shoe BC-1 A Pad 1 A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. Caoillarv String 3l8" 2205 Stainless Steel ~ T~ Bottom ~ MD 0' 8,265' ND 0' 7,426' ', B-18U 8,087 - 8,107 B-18L 8,118' - 8,148' B-19 8,183' - 8,223' ', B-20 8,284' - 8,312' B-21 8,374' - 8,404' B-22 8,439' - 8,459' B-23 8,500' - 8,520' 8,527' - 8,567' rforations: --~ $,79T-8,817 2.313" Otis X Nipple @ 8,894' Cast Iron Bridge Plugs @ 8,994' MD -~ @ 9,001' MD ~ @ 9,003' MD _~ TD MD: 10,296' TVD: 9,390' Conductor 20" H-40 94 ppf Top Bottom MD 0' 526' ND 0' 526' 26" hole cmt wl 1,000 sks of Class G Tubing String Baker 80-40 Anchor 3-1/2" L-80 9.3 ppf on Baker 84 SAB 2984" ID Tom Bottom 40x30 Permanent MD 0' 7,890' Packer w/ 3.25" ID ND 0' 7,101' 2.813" Camco X Nipple 7,815' Surface Casing 13-3/8" J-55 61 ppf 2.813" Camco X Nipple 7,853' Tom Bottom MD 0' 2,220' Wireline Re-entry Guide ND 0' 2,220' C @ 7890' c 18-518" hole cmt wl 3,500 sks of Class G C 3.25 OD x 2.984 ID C Intermediate Casino C 9-5/8" N-80 40 143.5 ppf Tom Bottom MD 0' 5,130' ND 0' 4,819' Baker SC-1 Packer f- 4' ID @ 8607' 12.1/4" hole cmt w/ 1,800 sks of Class G Production Casino 7" N-80 / P-110 26 129 ppf tiC T~ Bottom C MD 0' 9,697' ND 0' 8,807' " Well Screen 4.5" OD x 2.438" ID 8.1/2" hole cmt w/ 730 sks of Class G C f~ Liner 4-1/2" L-80 17 ppf Tom Bottom Model D Packer MD 8,607' 8,984' ~ 3.25" ID @ 8984' ND 7,747' 8,110' ~ Gravel packed PBTD MD: 8,994' ND: 8,122' Well Name & Number: Beaver Creek - 1A Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 1.8° / 100 ft @ 2,300' Angle/Perfs: 29°-~19° Maximum Deviation: 39° @ 4,450' Date Completed: Ground Level (above MSL): 153' RKB (above GL): 16.8' Prepared By: Kevin Skiba Last Revision Date: 818/2008 RE: Beaver Creek #lA PTD #167-009: De minimis gas venting discussion Page 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 16, 2008 11:30 AM To: 'Walsh, Ken' Cc: Ibele, Lyndon; Sulley, Michael; Skiba, Kevin J.; Mullin, Mickey; Donovan Jr, Dennis M.; Dammeyer, Michael D. Subject: RE: Beaver Creek #1A PTD #167-009: De minimis gas venting discussion Ken, As we have discussed regarding prior wells, the vented volume must be reported on the gas disposition form. Also, as discussed, the need to vent is not uncommon while doing "gas well work". I have no doubt that Marathon is doing all it can to minimize the venting, however that venting is ultimately dependant on the well performance. Nothing further is needed at this time. I will place a copy of this message in the well file. ~, 200$ Call or message with any questions. ~~ ~~~ Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoil.eom] Sent: Wednesday, July 16, 2008 10:47 AM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Sulley, Michael; Skiba, Kevin J.; Mullin, Mickey; Donovan Jr, Dennis M.; Dammeyer, Michael D. Subject: RE: Beaver Creek #1A PTD #167-009: De minimis gas venting discussion Tom, This email is a follow-up to our discussion this morning, July 16, 2008, pertaining to de minimis gas venting to reestablish flow from the Beaver Creek #1A well. Marathon requested and received approval to vent up to 1600 Mcf of gas from this well on July 3rd. Marathon ran a capillary string into this well on July 4 to provide foamer injection and improve the fluid unloading capabilities of this well. Due to an error, the capillary string was changed out on July 9th since it was too short to reach the intended treatment depth. I informed you this morning over the phone that we continue to vent this well with a total estimated volume vented of around 3 MMscf to date. The well is unloading about 28-30 BWPD and flowing at about 300 Mcfd at 100 psi FTP. This well is recovering from its relatively long shut in but still is not strong enough to enter the sales line at 350 psi. We do not know exactly how much longer that this well will require venting to atmosphere before we can restore it to sales. However, we believe that, if after about 2 weeks time from today, the well still cannot be turned from vent to sales, we will discuss the conditions again with you before we decide to shut the well in and consider other options. Do you still agree that the gas venting volumes that 1 described over the phone and above qualify as de minimis and do not require a Form 10-403 submission for gas venting as described? I look forward to hearing from you. 7/16/2008 Beaver Creek # 1 A PTD # 167-009: De minimis gas venting discussion Page 1 of 1 • , Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 03, 2008 8:38 AM To: 'Walsh, Ken' Cc: Ibele, Lyndon; Sulley, Michael; Skiba, Kevin J.; Mullin, Mickey Subject: RE: Beaver Creek #1A PTD #167-009: De minimis gas venting discussion Ken, You captured our conversation correctly regarding the venting. The vented volume should be reported on the gas disposition report. I am reviewing the sundry and would hope to have favorable information for you later today. Regards, Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Thursday, July 03, 2008 8:32 AM To: Maunder, Thomas E (DOA) ~~.~~~~~ ~~]- ~ ~ 20~$ Cc: Ibele, Lyndon; Sulley, Michael; Skiba, Kevin J.; Mullin, Mickey Subject: Beaver Creek #1A PTD #167-009: De minimis gas venting discussion Tom, This email is a follow-up to our discussion this morning pertaining to de minimis gas venting to reestablish flow from the Beaver Creek #1A well. As a brief recent history, Marathon permitted and ran a coiled tubing velocity string to unload the produced fluid from this well. Marathon has also attempted to blow the produced fluid out of the well several times using nitrogen without success. However, since Saturday, June 28 starting at 1800 hrs, we have vented the well to atmosphere at relatively low rates through a gas buster and tank. We estimate a total vent estimate of 600 Mcf for this project to date with another 1000 Mcf possible. The venting efforts have reestablished gas flow but it is still too weak to enter the 350 psi LP. As you are aware, we have filed a Form 10-403 for permission to install a capillary foamer string in this well. The additional 1000 Mcf vent volume would cover the amount vented from today until we install the capillary string and establish foamer injection. We are hopeful that we will receive permission from the AOGCC today and can run the cap string tomorrow, Friday, July 4. You agreed that the gas venting volumes that I described over the phone and above qualified as de minimis and did not require a Form 10-403 submission for gas venting as described. look forward to hearing from you. .7fe~ Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) 7/7/2008 • T § ~,,. \ ~+~~"4,4. 3 _~ A~ t ~ _`.~ t~~~S. b pt ~A ~ s t A....6 rv~`{~ f ~~,., .Fr ~` ~..°:~.,..~ ~l.a ~ €. ~ ~ ?~ _ ~ , ..~ ~ ~ ' 1 , '°;~ 1 ~` r°~e SARAH PALIN, CaOVERNOR OIIJ ~ ~ IIl, 333 W. 7th AVENUE, SUITE 100 CO1~T51'.R'QA'1`IOl'1T COMIrII55I0I'1T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Mullin Senior Production Engineer Marathon Oil Company ~~~~~~ JUL. ~ 2fl08 PO Box 1949 Kenai AK 996 1 1-1 949 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek # lA Sundry Number: 308-235 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. Sincerely, . ,~ ,~~C DATED this -day of July, 2008 Encl. Daniel T. Seamount, Jr. Chair /(e~ -ate ~Utarathon MARATHON Oi[ Company July 1, 2o0s Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Beaver Creek Field Well: Beaver Creek #1A Dear Mr. Maunder: • Marathon Clil Company Alaska Asset Team R.O. Box 19!49 Kenai, AK 99611 Telephone 907/283-1371 Fax Sd7/283-1350 `!U~° p X008 A1as~a t}r~ C~ i. ~-~~:~^~, ~:ar;~~;:~~icn fit,; ; '~; ~,~,~~ Marathon has mobilized a crew from Calgary Canada to install capillary strings for our foamer injection program. This concept has proven beneficial. KTU 24-6H has experienced an incremental increase of approximately 475 mcfd with the aid of soap injection. The installation crew is available for eight capillary string installations during their mobilization. KBU 11-8Y was one of the initial candidates but has since been removed from the program. This frees up a capillary string for use in another well. In an effort to best utilize the resource available to us, we propose to run this 3/8" capillary string in BC-1A. • The expected installation date is July 4"', 2008. I recognize that this timeframe requires a short turn-around for sundry approval.. Your assistance will allow us to maximize this opportunity to stabilize production. Please call me at (907) 283-1371 if you have any questions or need additional information Sincerely, - Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File KJS MAM ~ ~ ,B~ ~3 ~~~ o STATE OF ALASKA • f~J'~ , O~ ALASKA OIL AND G;4S CONSERVATION COMMISSION !~ ~U~ ~ ~ E 1~/ APPLICATION FQR SUNQRY APPROVAi~p~~ ~,~ ~ Bey ~t:~n~~ ~~c7,~~ri,~~; , 20 AAC 2s.2so 1. Type of Request: Ab d ^ j° ;..... an on Suspend ^ Operatwnal shutdown[] Perforate ^ Waiver °~ Other Q Alter casing^ Repair well ^ Piug Perforations ^ Stimulate ^ Time Extension ~ install Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well. ^ Capillary String 2. Operator Name:. Mal'atCilOll OII C0111 1t1 4. Current Well Class: 5. Permit to Drill Number p y Development O Exploratory 167-009 ` 3 Address: ^ . PO BoX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20006-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest $. Well Name and Numbers property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Beaver Creek #1A . 9. Property Designation: 10. KB Elevation (ft}: 11. Field/Pool(s): A- fl28fl83 . 153' (16.8' AGL} Beaver Creek Field /Beluga Pool 12` PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 10 296' Total Depth T~VDp(tt1:Q Effective Depth MD (tt): ~ ' - ' .Effective Depth TVD (ft): Plugs (measured): Junk (measured: , 33$ ! ~•v 8,994 $,122' 8,994', 9,001', 9,033' 8,648' Casing Length Size MD TVD Burst. Collapse Structural Conductor 50g+ 20'• 526' 526' 1,530 psi 520 psi Surface 2,203 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,113' 9-5/8" 5,13D' 4,819' 5,750 psi' 3,090 psi Production 9,680' 7" 9,697 8,8QT 9,960 psi 6,210 psi Liner 377 4.112" 8,984' 8,11fl' Gravel Pack Gravel Pack Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grader Tubing MD (ft}: 8,087-8,976' gross 7,265'-8,102` gross 3-112" 9.3# L-80 7,890' Packers and SSSV Type: Baker 84 SAB 40x30,. Baker SC-1, Packers and SSSV MD (ft): Baker Model D 7,764`, 8S0T, 8,984' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed worka Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ 5ervice ~] 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 4, 2fl08 ^ Oil ^ Gas Q Plugged ^ Abandoned 17. Verbal Approval; Date: WAG. ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact . Kevin Skiba (907).?83-1371. printed Name .Michael A. Mullin Title Senior Production Engineer :Signature . Phone Date (907) 283-7337 July 7, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that`s representative may witness. Suntlry Number: © - 5 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other.. Subsequent Form Required; ~~~ APPROVED BY f Approved by: COMMISSIONER THE COMMISSION.. Date:` ~ ~~ v Form 10-403 Revised 06/2006 ®t-( I 1 ~ I' " H L ~F~,, ~UI_ ~ '~ 1008 .. Submit in Duplica e ?,Z,~ 2Q08 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, SC, KGF and NGF WBS#s SD#3 - W0.08.18049.CAP:.001 33-6X, 41-7 - W0.08.18053,GAP.001 Bc 13-wo,o8.18os4.caP.~©r CLU 6 - W0.08.18056.CAP.OQ1 SU 32-9 - W0.08.18117.CAP.001 GO 6 - W0.08.1819~.CAP.001 • ~ BC-lA - W0.08.18CAP.001 Objective - Install a 3/$" Capillary String into these wells to alleviate liquid loading.: We intend to treat the producing fluid level in each of these $ wellbores with foamer. Install and Complete CICM (injection skids} to utilize on wellheads. We have'seen. an incremental increase on KTU 24-6H capillary stt-ing installation of approximately 475MCFD. Procedure.. Companies Evoived:UOSS, BJDC, BJCS BigG Installation Order 1 Well. Maximum Setting De th ' Maximum String Len th ' Minimum String Needed at Surface trin Size andT a lan a Connection Est'd Producing Fluid Leval a De th Gauge Ring ID .run Recommended Setting Depth From PT+Ta GLU 6 8042 8200 45` 2205 3/8" X 0.049." VVT' 4-1/16 5M RX39 7880' 8058' 2:300" 8020` 2 3 4 SU 32-9 BC 13 6200' 8590' ' 6250' 8750' 45' 45' 2205 3/8" X 0.049" 1!VT 22053/8" X 0.049" WT 3-1/8" 5M RX35 3.1/16" 10M BXi54 TBD 7900' TBD 10055' TBD 2..300" TBD 8580' Gd 6 10120 10300' 45' 22053/8" X 0,049" WT 4-1f16 SM RX39 TBD TBD TBD TBD 5 SD 3 :9290' 9450' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBII 6 KBU 41-7 6910' 7050' 45' 2205 318" X 0.049" WT 3-1/8" 5M RX35 TBD' TBD TBD TBD 7 ' K8U 33-6x. 8200' ' 8300' 45' .2205 3/8" X 0.049" WT 3-1/1$" 10M BX154 TBD TBp TBD' TBD 8 BC-1A 8305 8350' 45' 2205 3/8"X 0.049" WT 3-1/16" 10M`BX154 TBD TBD `~ TBD TBD 2008 Capillary String Installation.. Page 2 Installation Procedure:: 1.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41 7, all other'well s have units placed. They will complete Installation of items that aze pertinent to operation. of CICM. b) Move NS#3 CICM to GO#6 well 2".) DOSS: (Hold PJSM and JSA) .a) Removal of all well houses to setup for BJ DynacoilUnit b) Replacement of CICM roof on (3) new skids, after tanks are.. set inside containment. 3.) Big G: (Hold PJSM and JSA) a) Complete explosion proof electrical. end fittings-for CICM b) Complete tubing. for hookup of Dynacoil - if needed. - Placement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tub ing disconnects when well work is needed, thus reducing exposure. to trapped pressure. 4.) BJDC; 1. Hold PJSM and Complete JSA/JHA 2. Mane in rig up BJ Dynacoil unit. 3: Replace tree-cap flange with specified internally threaded flange listed above in the. matrix.. 4. MU BHA and secure to 3/8" string. 5. MCJ WHA to :internally threaded flange 6. MU Trailer Haskell Pump to VUHA with 1"male NPT tie: back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" - This. will prevent BHA from traveling down flowline. BHA is small and capable of flowing :into flow-Tee: 9. R1H with capillary below "Est'd Producing Fluid Level". All. strings must be set into the producing. fluid level to prove the most effective. 10. Set Rattguns and Leave 1.5 times STTP or greater as requested by BJDC on hydraulic pack off; 11. "OPEN WELL TO PRODUCTION" l2. Leave remaining spool of tubing outside of well for soap injection skid hookup. 13-. Cap the tubing with a Swagelok cap,.. Swagelok valve, and pressure gauge. 14. ..Lockout/Tagout Swab, Upper Master and. Lower Master. (Install BJ Dynacoil signs on all valves. stating "Do Not ©perate BJ :Dynacoil in wellhead". Proceed to Lockout aloes with production lock and cable.) 15. Hookup injection line to CICM, andaet specified rate for each well.. L6. RDMO, Cleanup site,. Sign.-out 167-009~~ 0-133-2ooos-00 Pad 1A r Des: A - 028083 117' FSL, 1,338' FEL anon: 153' (16.8'AGL) Sec. 33, T7N, R1OW, S.M. ite: 3/13!1967 hed: 6/13/1967 rra ; ^ ; e ,-. ,,, ~, ^. ^. ^. Camco Injection Mandrel @ 898' Tubing 3-112` L-80 9.3 ppf 2.984" ID Toe Bottom MD 0' 7,890' TVD 0' 7,101' 1-314" t]T-700 0.125' wall 1.40" ID Toe Bottom MD 0' g,2g6' TVD 0' 7,455' 2.50" BHA wl: Grapple 10' Straight har 1.25" PXN nipple Forations: ~~$U 8,08T - 8,107' ,~'8L 8,118' - 6,148' 'B-19 8,183'-8,223' B-20 8,284' - 8,312' B-21 8,374' - 8,404' B-22 8,439' - 8,459' 6-23 8,500' - 8,520' °'~~_. 8,527' - 8,567' Conductor 20" H-40 94 ppf ToP Bottom MD 0' 526' TVD 0' 526' 26" hole cmt w/ 1,000 sks of Class G Baker 80-40 Anchor Surtace Carina 13-318" J-55 61 ppf on Baker 84 SAB lop Bottom ~ 40x30 Permanent MD 0' 2,220' Packer w/ 3.25" ID ND 0' 2,220' 2.813" Camco X Nipple 7,815 18-518" hole cmt w/ 3,500 sks of Class G 2.813" Camco X Nipple 7,853' Intermediate Casino 9-5(8" N-80 40 / 43.5 ppf ~ Wirelirte Reentry Guide T~ Bottom @ 7890 MD 0' 5,130' 3.25 OD x 2.984 ID T~ 0' 4,819' 12-114" hole cmt w/ 1,800 sks of Class G _ Model D Packer 3.25"fD @ 8984' Production Casino 7" N-80 / P-110 26 129 ppf Top Bottom MD 0' 9,697' TVD 0' 8,807' 6-112" hole cmt w/ 730 sks of Class G Liner 4-1/2" L-80 17 ppf Tom Bo om MD 8,607' 8,984' ND 7,747' 8,110' Gravel acked Well Name $ Number: Beaver Creek -1A Lease: A - 028083 County or Parish: Angle @KOP and Depth: Kenat Peninsula Borough 1.8° f 100 ft @ 2,300' Angle/Perfs: 29°~79° State/Prov: Alaska Maximum Deviation: Country: USA 39° @ 4,450' Date Completed: Ground Level (above MSL : 153' RKB (above GL): 16.8' Prepared By: Kevin Skiba Lasl Revision Date: 3/4/2008 Mtckey Mullin Last Revision Date: 5/12/2008 TD PBTD MD: 10,296' MD: 8,994' TVD:9,388' TVD:8,122' Beaver Creek #lA: PTD #167-009 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 06, 2008 2:18 PM To: 'Walsh, Ken' Cc: Cissell, Wayne E.; Donovan Jr, Dennis M.; Ibele, Lyndon; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject: RE: Beaver Creek #1A: PTD #167-009 Ken, confirm our conversation of this morning. A sundry is not needed to perform the work planned. However, the 404 with the daily summary and revised wellbore drawing should be submitted. Call or message with any questions. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Tuesday, May 06, 2008 2:14 PM To: Maunder, Thomas E (DOA) Cc: Cissell, Wayne E.; .Donovan Jr, Dennis M.; Ibele, Lyndon; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject: Beaver Creek #lA: PTD #167-009 ~L~,~l~~ MAY (I '~ 200 Tom, Following up on our telephone conversation today, Marathon is requesting your guidance on how to handle the sundry notification to pick the coiled tubing velocity string tail uphole. Marathon ran and hung an 1-314" OD coiled tubing string in this well under Form 10-403 #307- 217. Marathon filed a 10-404 after the work was completed and the coiled tubing was set to a total measured depth of 8570'. After multiple unsuccessful attempts to establish continuous flow up the velocity string, Marathon wishes to pull the coiled tubing string uphole to place the end at or about 8300' MD. Marathon anticipates that this new placement depth will allow gas to enter the velocity string more easily and help re-establish and maintain fluid unloading. I have attached a wellbore diagram for your review. ~~ Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) «BC-01A WBD With V-String 030408.x1s» 5/6/2008 • M Marathon MARATHON Oil Company • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 March 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Beaver Creek Field Well: Beaver Creek 1A RECEIVED MAR 0 5 2008 Alaska 01~ ~ Gas Cons. Commission Anchorage Ifs?~0°~' V Dear Mr. Maunder: Attached for your records is the 10-404 Sundry Report for BC-1A well. This report covers the velocity string installation work that Marathon completed under sundry #307- 217. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, c\~ ~J~~ Kevin J. Skiba Production Technician ~ APR 4 2 2008 Enclosures: 10-404 Sundry Report Operations Summary Well Schematic cc: Houston Well File Kenai Well File KJS DMD ALA OIL AND G STCONSE VAT ON COM~SIO~~CEtVED ~ /~ REPORT OF SUNDRY WELL OPERATION~AR 0 5 2008 AIa~La X1:1 Q. /~~. /'+ww~ I~....,....:..wiww 1. Operations Abandon Repair Well P rf d Plug Perforations Stimulate ter ns a -String orme e : Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development^ Exploratory^ 167-009 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20006-00 7. KB Elevation (ft): 9. Well Name and Number: 16.8' KB AGL ~ Beaver Creek #1A ' 8. Property Designation: 10. Field/Pool(s): (aqs A - 028083 Beaver Creek Field / Belu Poo 11. Present Well Condition Summary: ~,OS ~. Total Depth measured .10,296'' feet Plugs (measured) 8,994', 9,001', 9,033' true vertical feet . ~ Junk (measured) ~ 8,648' 9390 ~ 3~ Effective Depth measured 8,994' feet true vertical 8,122' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 509' 20" 526' 526' 1,530 psi 520 psi Surface 2,203' 13-3/8" 2,220' 2,220' 3,090 psi 1,540 psi Intermediate 5,113' 9-5/8" 5,130' 4,819' 5,750 psi 3,090 psi Production 9,680' 7" 9,697' 8,807' 9,960 psi 6,210 psi Liner 287' 4-1/2" 8,607' - 8,984' 7,747' - 8,110' Gravel Pack Gravel Pack Perforation depth: Measured depth: 8,087' - 8,976' (Gross) True Vertical depth: 7,265' - 8,102' (Gross) 1-3/4" Hang Off Grade 8,570' Tubing: (size, grade, and measured depth) 3-1/2" 9.3 # I-80 7,890' Baker 84 SAB 40x30 7,764' Packers and SSSV (type and measured depth) Baker SC-1 8,607' Baker Model D 8,984' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA 1,900 23 0 344 Subsequent to operation: NA 2,200 45 0 345 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-217 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature Phone (907) 283-1333 Date March 4, 2008 Form 10-404 Revised 04/2006 ~\' ;.~~~ ~ ~ ~ ~. (I'~~! f.~ '~' J~,~~~o\~~ Submit Original Only 50-133-20006-00 tv Des: A - 028083 vation: 153' (16.8' AGL) late: 3/13/1967 Iched: 6/13/1967 Camco Injection Mandrel @ 898' Tubino 3-112" L-80 9.3 ppf 2.984" ID Tom Bottom MD 0' 7,890' ND 0' 7,101' 1-3/4" HO-70 0.125" wall 1.40" ID Tom Bottom MD 0' 8,570' ND 0' 7,712' 2.50" BHA wl: Grapple 10' Straight bar 1.25" PXN nipple B-18U 8,087' - 8,107' B-18L 8,118' - 8,148' B-19 8,183' - 8,223' ', B-20 8,284' - 8,312' ~ B-21 8,374' - 8,404' I B-22 8,439' - 8,459' B-23 8,500' - 8,520' 8,527' - 8,567' BC-1 A Pad 1 A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. II~ARATNOM ti - ~, Conductor 20" H~0 94 ppf T~ Bottom MD 0' 526' ND 0' 526' r 26" hole cmt wl 1,000 sks of Class G - - Surface Casino Baker 80-40 Anchor 13-318" J-55 61 ppf on Baker 84 SAB Tom Bottom ',° r ~ 40x30 Permanent MD 0' 2,220' Packer w/ 3.25" ID ND o' 2,220' tr i n ~i 2.813" Camco X Nipple 7,815' 18-5/8" hole cmt wl 3,500 sks of Class G ~~ ~ 2.813" CamCO X Nipple 7,853' Intermediate Casino 9-518" N-80 40 143.5 ppf ! WirelineRe-entry Guide Tom Bottom C @ 7890' MD 0' 5,130' ~ C ND 0' 4,819' 3.25 OD x 2.984 ID ~ C 12-114" hole cmt wl 1,800 sks of Class G 2.313" Otis X Nipple @ 8,894' ' Model D Packer ~- 3.25" ID @ 8984' Production Casing 7" N-80 I P-110 26 / 29 ppf Tom Bottom MD 0' 9,697' ND 0' 8,807' 8-112" hole cmt w/ 730 sks of Class G Liner 4-112" L-80 17 ppf Tom Bottom MD 8,607' 8,984' ND 7,747' 8,110' Gravel packed Well Name & Number: Beaver Creek - 1A Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 1.8° / 100 ft @ 2,300' Angle/Perfs: 29°~19° Maximum Deviation: 39° @ 4,450' Date Completed: Ground Level (above MSL): 153' RKB (above GL): 16.8' Prepared By: Kevin Skiba Last Revision Date: 3/4/2008 TD PBTD MD: 10,296' MD: 8,994' TVD:9,388' TVD:8,122' • • Marathon Oil Company Operations Summary Report Legal Well Name: BEAVER CREEK 1A Common Well Name: BEAVER CREEK 1A Event Name: RECOMPLETION Contractor Name: Rig Name: Date From - To Hours Code Sub Code 2/2/2008 106:00 - 07:00 I 1.001 WORK I COIL 07:00 - 17:00 10.00 12/3/2008 107:00 - 07:30 I 0.50 07:30 - 09:30 i 2.00 09:30 - 10:20 I 0.83 10:20 - 11:30 1.17 RURD COIL 11:30 - 12:15 0.75 RURD COIL 12:15 - 14:25 I 2.171 WORK I COIL Page 1 of 2 ~ Spud Date: 3/13/1967 Start: 2/1/2008 End: 2/3/2008 Rig Release: Group: Rig Number: Phase ~ Description of Operations CMPRUN Notified Jim Reaa, AOGCC, about the CT BOP testing that we planned to do on Thursday around 2:00 PM on BC-1A. He called back and waved the witness and ask that I send him a completed copy via e-mail 4500 si Tested blinds & slips -good test. MIRU PU injector. MU tools to coil. Pull tested the X-grapple coil connector to 25, 000 lbs. good test. MIRU MU BHA to 1.75" coil with .175" wall. BHA consist of grapple, stainght bar, X profile, with re entry shoe which has pump out plug in bottom. MIRU Go to well with injector. Shell test to 850 PSIG. Open well. WHP= 370 psig, 2100 MCFPD. RIH with velocity string. MIRU Coil at 8570' hang off depth. Mark coil. PU 13' 6" above BOP where 3" coil hanger mandrel will be installed. Set pipe slips & clamps on well. Blew down gas above pipe rams. COIL CMPRUN Move in equipment. Obtain work permit and held PJSM. Spotted all flow back equipment on liners, rig up blow down equipment, move well house and setup to install the velocity string. BJ left lease. MTG_ MIRU Obtain work permit. Held PJSM and discussed procedure with crew. Started equipment. Problem starting the fluid pump engine. MTG MIRU Function tested BOP blinds. Tested BOP's low @ 255 psig/ high at COI L 14:25 - 15:00 0.58 CUT_ TBG_ MIRU Break Bowen above slips, PU lubricator, cut pipe. Inspected the roll on coil connector on reel. Decided it should be replaced because of potential fluid or N2 leak at the connection. 15:00 - 17:00 2.00 CUT TBG_ MIRU Secured Pipe above the BOP on trees. Vetco installed grapple and coil tubing mandrel assemble. 17:00 - 18:15 1.25 CUT_ TBG_ MIRU Unstab pipe in the injector. Spool off 500' with truck. Pull cracked roll on at the reel past the counter box. Cut pipe off and roll coil out to ground, installed roll on coil connector and stabbed though injector. 18:15 - 19:45 1.50 CUT TBG_ MIRU PU additional lubricator and do pull test on GS to 26,000 Ibs, prior to picking up velocity string an landing in hanger. PU and go to well with 3" GS latch 4" mandrel assemble. Lower lubricator over mandrel and PT shell. 19:45 - 20:15 0.50 WORK COIL MIRU Unlock BOP's, slips and rams. Open well. RIH to setting depth. Vetco run in hanger bolts on hanger. 20:15 - 20:20 0.08 WORK COIL MIRU Mandrel assemble landed in tubing hanger. Operator came by said BC-1 A flow went to 0.0 flow. Found the Annulus flow line at tree was frozen. When velocity hung shut off flow to flow line. 20:20 - 20:30 0.17 WORK COIL MIRU PT hanger, made several attempts to pressure up on hanger. Could not PT the han er. PU 2000 Ibs, Vetco unlanded bolts. PU coil to hanging wait of aournd 17,000 Ibs. 20:30 - 21:20 0.83 WORK COIL MIRU Coil picked up 13' above hanger, set BOP tubing slips and manually pinned slips for over night. Pumped off GS with N2. Blew down pressure above BOP's. 21:20 - 22:30 1.17 RURD_ COIL MIRU PU injector and pull lubricator under injector. Rack up to craddle. Secured well. Secured area and well. 22:30 - 23:00 0.50 RURD_ COIL MIRU BJ left lease. Well currently flowing at 1.8 MCFPD 2/7/2008 09:30 - 10:30 1.00 SAFETY MTG_ CMPRUN Hold safety meeting and issue permit. Discuss BJ JSA and complete safety check list. Discuss working at cold temperatures. 10:30 - 14:45 4.25 RURD_ COIL CMPRUN Start equipment and RU CT. V-string is hanging in BOP and well is flowing through lower flow arm (tubing) at 1.8 MM. 14:45 - 15:35 0.83 RURD_ COIL CMPRUN Uncap well and LD lubricator. Ready to change hanger. 15:35 - 16:30 0.92 RUNPU COIL CMPRUN Change old style O-ring hanger to new style compression packing hanger. Prin[etl: LS/ZOOS J:Z1:41 PM • • Marathon Oil Company Page 2 of 2 Operations Summary Report Legal Well Name: BEAVER CREEK 1A Common Well Name: BEAVER CREEK 1A Spud Date: 3/13/1967 Event Name: RECOMPLETION Start: 2/1/2008 End: 2/3/2008 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 2/7/2008 16:30 - 17:00 0.50 RUNPU COIL CMPRUN Hang off v-string and lock down. Lock down screws energise seals. Pull test han er to 25K Lbs. 17:00 - 17:30 0.50 TEST_ EOIP CMPRUN Tesat han er to 5000 si. Good 10 min test. 17:30 - 18:00 0.50 RURD_ COIL CMPRUN Rig down injector and lubricator. Cap BOP and close blinds. 18:00 -18:30 0.50 RURD_ COIL CMPRUN Pressure up v-string with n2 and blow off plugs from BHA. Plugs sheared off at 1500 psi. Open v-string to production. Indications of water unloading after about 30 min. 18:30 - 19:00 0.50 RURD_ COIL CMPRUN Secuer location. Close permit and leave. 2/8/2008 10:00 - 10:30 0.50 SAFETY MTG_ CMPRUN Hold safety meeting and issue permit. Discuss BJ JSA and complete safety check list. Discuss working at cold temperatures. 10:30 - 15:00 4.50 RURD_ COIL CMPRUN Start equipment and RU CT. Release equipment. Close permit and leave location. Printed: 2/8/2008 3:21:41 PM . ~"[~"[Œ LID~ ~~~~æ~ . AIIA~1iA. OIL AlQ) GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7IhAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Wayne Cissell Well Work Over Supervisor Marathon Oil Company PO Box 1949 Kenai Alaska 99611-1949 5~ JUL 0 6 2007 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 1A Sund1yNumber: 307-226 fo1-ooq Dear Mr. Cissell: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. A sundry application for similar work was received June 25. DATED this 6day of July, 2007 Enc!. it ~ \ ',-1 _ (. M..) Marathon MARATHON Oil Company RECEIVED- Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Alaska Oil & Gas Cons, Commission Fax 907/564·6489 Anchorage JUN 2 9 Z007 June 14, 2007 Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Sundry Notice 10-403 Field: Beaver Creek Field Well: Beaver Creek Unit BC-1A Dear Mr. Maunder, Enclosed please find for your approval form 10-403, the Sundry Notice for running a 1 %" velocity string in the well BC 1 A. A PL T was able to determine that there is water held up in the well bore. The plan is to maintain better unload rate from produced fluid and make well less problematic after maintenance shut downs. Attachments include a well bore diagram and coil velocity installation procedure.. Should you require further information, I can be reached at 907-283-1308 or bye-mail at wecissell@MarathonOil.com. Sincerely, Wayne issell Well Work Over Supervisor Enclosures: 10-403 Sundry Notice Operations procedure Well bore diagram Proposed well bore diagram Cc: AOGCC Kenai Well files Houston Well files WEC KJS /Ø' RECt::IVI:::L) . STATE OF ALASKA ã/..Pl ALA OIL AND GAS CONSERVATION COM~ON JUN 2 9 2007 APPLICATION FOR SUNDRY APPROVÞdm~a Oil & Ga 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Company 3. Address: Suspend Repair well 0 Pull Tubing 0 Development Stratigraphic P.O. Box 19168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 12' 8. Property Designation: Beaver Creek Unit ~~A Oe::ll r (7 3'$ 11. Other ./ o o Hang Velocity dWell 0 String it to Drill Number: o? /6r~Ø l"rJI# Exploratory Service . API Number: () 50-133-20006-0/ 00 .f':;/'~ 9. Well Name and Number: BC 1A / 10. Field/Pools(s): Total Depth MD (ft): 10296 Total Depth TVD (ft): 9338 Length Effective Depth MD (ft): 8994 Casing Structural Conductor Surface Intermediate Production Liner Size 526' 2220' 5130' 9691' 281' 20" 13 3/8" 9-5/8" 7" 4-1/2" Perforation Depth TVD (ft): 7365 -8102' Perforation Depth MD (ft): 8087 - 8976' Packers and Plugs (measured): 8994,9001,9033' Junk (measured): 8648' Collapse Packers and SSSV MD (ft): 7764',.8601' & 8984' SSSV N/A Baker 84 SAB 40X30 packer, I Baker SC-1 packer model D Baker Model D 12. Attachments: Description Summary of Propos Detailed Operations Program 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory 0 Development 0 Service D 15. Well Status after proposed work: 7/7/2007 Oil 0 Gas 0 Plugged 0 Abandoned D WAG 0 GINJ 0 WINJ 0 WDSPL 0 Printed Name Signature Contact Work Over Supervisor Date 907-283-1308 COMMISSION USE ONLY ommission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Other: Subsequent Form Required: Approved by: Form 10-403 Revised 07/2005 6/19/2007 Sundry Number: ~ 7 - Q. dJ..o Location Clearance 0 RBDMS 8FL JUL 0 6 iOD1 APPROVED BY THE COMMISSION Date: 1--5 ,-()r S~P7/"~? J, ~ - - Marathon Oil Company Alaska Region BCIA Beaver Creek Velocity String Procedure History: Well BC lA is a Beluga producer with 3 ~"tubing and packer inside 7" production casing. The well is currently producing at 2.3 MMCFPD, 340 psig, 40 BBLS H20 per day. The well experiences shut in problems after being shut in for any length of time. Objective: A 1.75" coiled tubing velocity string will be run to keep the well unloaded. A production log data indicated that most of the water was held up in the section of the well below the second set of perforations. Outline Procedure: 1. Install coiled tubing spool and piping. 2. RU BJ coiled tubing 3. Run 1-3/4" coiled tubing velocity string and hang off at 8150' MD. 4. RD BJ 5. Unload and test well. Detailed program: Install Coiled Tubing head and flow line / tree modifications: 1. RU Vetco. 2. Set BPY. 3. Close upper master 4. Remove tree and flow spools 5. Install CT hanger spool (Tubing Head) 6. RU Tree 7. PT Tree to 4,200 psi. BC-lA Velocity String Program Rev. 1 6/1612007 " . . -, 8. Pull BPV Run Velocity String: (After surface modifications) 9. NOTE: Well remains flowing during coiled tubing work. 10. RU BJ CT services. a. MU BOP and injector to tree. b. MU V String BHA (WEG, KEP nipple, Straight Bar, Weld on connector). c. RIH with CT velocity string to 8150' hang off depth.. d. Set slip/pipe combination rams, perform pull/push test, lock rams closed. Bleed off any pressure and break lubricator. e. Cut off dimple on connector and cut 450' off velocity string. f. Install ABB Vetco CT hanger with seal ring. g. Install GS pulling tool to CT with double flappers to 1.75 work string. h. Latch hanger and walk injector head down to MU lubricator. . 1. Land mandrel hanger in CT hanger with 2000 lbs set down weight. J. Confirm placement by pressure testing void in hanger, install lock screws to confirm integrity. Perform pull test and pump through GS pulling tool at 2 bpm to release. k. POOH with GS pulling tool. 1. RDMO BJ CT. 11. RU Pollard wire line service with .125 wire and I" tool string. a. Hold Pre-job safety and environmental awareness meeting. b. MU lubricator with BOPE to tree and test to 200/3500. c. MU line from CT / Tbg annulus to V string and equalize surface pressures. d. Rlli with 1" tool string and retrieve 1.188 KEP prong in CT nipple. e. RIH with 1" tool string and retrieve 1.188 KEP plug in CT nipple. f. POOH. g. RDMO pollard wire line. 12. Close well and build 700 psi on velocity string. 13. Close velocity string and flow well through tubing (annulus) to tank and blowout plug in CT. Shut in well. 14. Flow well through velocity string. Minimum flowing pressure is 350 psi (line pressure) on V-string. Test well. Record CT / Tbg annulus pressures during test. BC-IA Velocity String Program Rev. 1 6/16/2007 '. ..., . . 15. Please call Mickey Mullin at 398-9954 or 283-1337 with any questions. Contacts: Mickey Mullin Wayne Cissell BC-IA Velocity String Program Work Phone Cel 283-1337 283-1308 398-9954 394-1324 Rev. 1 6/16/2007 · , .' ... Well Name & Number: County or Parish: Perforations: (MD) Angle/Perfs BHP: FWHP: Date Completed: Prepared By: BC1a J j 3,5" Tubing 2,984" 10 Perforations 8087-8107 B-18U 8118-8148 B-18L 8183-8223 B-19 8284-8312 B-20 8374-8404 B-21 8439-8459 B-22 8500-8520 B-23 8527-8567 BC1a Kenai Borough Angle @KOP and Depth o BHT: FBHP: o o o D 20 o o o o 526 Cameo Injection Mandrel @ 898' 13,375 o o o o 2220 - 9625 o o 5130 o o -- Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent, Packer With 3.25" ID 2,813 Cameo X Nipple 7815' 2,813 Cameo X Nipple 7853' Wireline Reentry Guide @ 7890' 3.25 DD x 2,984 10 Perforations Perforations Baker SC-1 Packer 4' 10 @ 8607' Perforations 8797-8817' 2,313 Otis X Nipple @J 8894' Perforations 8956-8976' Model 0 Packer at 8984' with 3.25" ID Cast Iron Bridge PiU9 @ 8994, 9001, 9033 7 00 o 9697 o USA o Don Eynon Last Revision Date: o o BC1a l o o o o 20 o o o o 526 Cameo Injection Mandrei @ 898' 13.375 o o o o 2220 9.625 o o o o 5130 3.5" Tubing 2.984" 10 Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent Packer With 3.25" iO 2.813 Cameo X Nipple 7815' 2.813 Camco X Nipple 7853' Wireiine Reentry Guide @ 7890' 3.25 00 x 2,984 10 Perforations 8087-8107 B-18U 8118-8148 8183-8223 B-19 8284-8312 8374-8404 8439-8459 8-22 8500-8520 8527 -8567 1 3/4" Velocity string @ 8150' Perforations Perforations Baker SC-1 Packer 4' 10 @ 8607' Perforations 8797-8817' 2.313 Otis X Nipple @¡ 8894' Perforations 8956-8976' Model 0 Packer at 8984' with 3.25" 10 Cast Iron Bridge Plug @ 8994, 9001, 9033 7 00 o 9697 o USA o FBHT: Last Revision Oate: o o · . ~"[~"[Œ LID~ ~~~~æ~ / AI4AfI¡IiA. OIL AlQ) GAS / CONSERVATION COMMISSION Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 1A '\ '1 / D oG\ Sundry Number: 307-217 \0 S~ JUL 0 6 Z007 Dear Mr. Donovan: 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. Thank you for including the information regarding the production logging operations. Such information is more properly submitted using form 10- 404, Report of Sundry Well Operations. 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 this ~ day of July, 2007 Enc!. . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 (. M.') Marathon MARATHON Oil Company June 13, 2007 RECEIVED JUN 2 5 ZOOl !\Iaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Beaver Creek Gas Field Well: Beaver Creek Unit 1a Dear Mr. Maunder: We propose to run a 1.75" velocity string in BC #1 a. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, well bore diagram, and proposed well bore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, Denni~~· Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic Operation Summary cc: AOGCC Houston Well File Kenai Well File DMD KJS /()1 ~ KI::L;I::IVI::U ctr1/~" STATE OF ALASKA ~-;;::J?.()~ ALA~ OIL AND GAS CONSERVATION COM~ION ~~UN 2 5 2007 APPLICATION FOR SUNDRY APPROVAhI&ka Oil & Gas Cons. Cnmmission 20 MC 25.280 . . 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver 0 u Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 V-String Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Companv Development 0 Exploratory 0 167-009 /' 3. Address: Stratigraphic D Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20006-00-00 /' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes D .A...../ No 0 Beaver Creek Unit 1 a /' 9. Property Designation~¿2)Að..,,:7xnK:öt" ~?410. KB Elevation (ft): 11. Field/Pool(s): 117S 1338E Sec. 33 7N R10W S.M. 16.8' Beaver Creek Gas Field /' 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): 10296' \ 9390' \ 8994' 8122' 8994' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 526' 20" 526' 526' 1530 psi 5020 psi Surface 2220' 13-3/8" 2220' 2220' 3090 psi 1540 psi Intermediate 5130' 9-5/8" 5130' 4819' 6330 psi 3810 psi Production 9697' 7" 9697' 8807' 8120 psi 7020 psi Liner ;J. 6~\ \"\\b" <ì><cO"'\-<iAC('"\ ''') ')'-\"'\ - ~~ """" ,t"c...~ \ ÇIta(. \:. ~ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft)': '\"') 8087'-8976' 7265'-8102' 3-1/2" L-80 7890' Packers and SSSV Type: Baker SAB 40x30 permanent Packer Packers and SSSV MD (ft): 7764', 8607', 8984' Baker SC-1 Packer, Model D Packer 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 12-Aug-07 Oil D Gas 0 Plugged 0 Abandoned D 17. Verbal Approval: Date: WAG D GINJ 0 WINJ D WDSPL 0 Com mission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name 1 Dennis Donovan Title Production Engineer Signature ,~ '~Ìl, Phone (907) 283-1333 Date 13-Jun-07 """ ....." ~ ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ '7 ... ótl 7 Plug Integrity 0 BOP Test ~ Mechanical Integrity Test D Location Clearance 0 Other: ~SOO c'\ w:> Ç> -\-<ë >-\- Subsequent Form Required: \.;0 RBDMS BFl JUL 0 6 2007 APPROVED BY 1-~-t)r- Approved by: -- l C~SSIONER THE COMMISSION Date: 7 / Form 10-403 Revised 06/2006Lü fl'ß1 N , Submit in Duplicate A . . MARATHON OIL COMPANY ALASKA REGION Beaver Creek Gas Field Beaver Creek Unit 1a 2007 CT Velocity String Hangoff Procedure Notes: . This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. . Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real-time Flowina Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil TubinQ Head. 3. Make flowline modifications for coil tubina velocitv strina. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back eauipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubina unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHAt Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 Ibs. Nipple up injector to WHA. 7. Pressure test surface lines and CT eauipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold. (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in well bore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. . . Pàge 2 of2 10. Nipple UP injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubina velocitv strina and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubina. PUH to span WHA for final landing depth. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 Ibs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanaer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purae N2 from CT remainina in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. BC 1a J j l ml 0 0 0 0 0 0 0 0 0 0 526 Camco Injection Mandrel @ 898' Well Name & Number: County or Parish: Perforations: (MD) BHP: FWHP: Date Completed: Prepared By: 3.5" Tubing 2.984" ID Perforations 8087-8107 B-18U 8118-8148 B-18L 8183-8223 B-19 8284-8312 B-20 8374-8404 B-21 8439-8459 B- 22 8500-8520 B-23 8527 -8567 Kenai Borough Angle @KOP and Depth o BHT: FBHP: Don Eynon 13.375 o o 2220 o o 9.625 o o o o 5130 Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent Packer With 3.25" ID 2.813 Camco X Nipple 7815' 2.813 Camco X Nipple 7853' Wireline Reentry Guide @ 7890' 3.25 OD x 2.984 ID Perforations Perforations Baker SC-1 Packer 4' ID @ 8607' Perforations 8797-8817' Well Screen 4.5" OD x 2.438" ID 2.313 Otis X Nipple @) 8894' Perforations 8956-8976' Model D Packer at 8984' with 3.25" ID Cast Iron Bridge Plug .-- @ 8994, 9001, 9033 7 00 o 9697 o USA o Last Revision Date: J j l wl 0 0 0 0 0 0 0 0 0 0 526 Camco Injection Mandrel @ 898' PROPOSED BC 1a Well Name & Number: County or Parish: Perf MD) Angle/Perfs BHP: FWHP: Date Completed: Prepared By: 3.5" Tubing 2.984" ID Perforations 8087-8107 B-18U 8118-8148 B-18L 8183-8223 B-19 8284-8312 B-20 8374-8404 B-21 8439-8459 B-22 8500-8520 B-23 8527-8567 Kenai Borough Angle @KOP and Depth o BHT: FBHP: -- Don Eynon 13.375 o o 2220 o o - 9.625 o o 5130 o o Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent Packer With 3.25" ID 2.813 Camco X Nipple 7815' 2.813 Camco X Nipple 7853' WIreline Reentry Guide @ 7890' 3.25 OD x 2.984 ID Perforations Perforations Baker SC-1 Packer 4' ID @ 8601' Perforations 8797-8811' Well Screen 4.5" OD x 2.438" ID 2.313 Otis X Nipple @? 8894' Perforations 8956-8976' Model D Packer at 8984' with 3.25" ID Cast Iron Bridge Plug ~ @ 8994, 9001, 9033 7 00 o 9697 o USA o FBHT: Last Revision Date: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15:30 - 16:30 16:30 - 17:00 12/16/2006 08:00 - 09:30 09:30 - 10:00 10:00 - 11 :15 11:15 -11:30 11 :30 - 11 :45 11 :45 - 12:31 12:31 - 13:03 13:03 - 13:33 13:33 - 13:50 13:50 - 14:05 14:05 - 14:18 14:18 - 14:28 14:28 - 14:35 14:35 - 15:00 15:00 - 15:25 15:25 - 16:00 16:00 - 16:30 16:30 - 16:45 16:45 - 17:15 17:15 - 17:38 17:38 - 18:00 18:00 - 19:00 19:00 - 19:30 6/15/2007 08:00 - 09:00 09:30 - 10:00 10:00 - 10:30 10:30 - 11 :35 11 :35 - 12:10 . . o Marathon Oil Company 0 Operations Summary Report 0 BEAVER CREEK 01A BEAVER CREEK 01A MAINTENANCE/REPAIR 1.00 RURD_ SLlK SLICK 0.50 RURD_ SLlK SLICK 1.50 SAFETY MTG - WRLN 0.50 RURD_ ELEC WRLN 1.25 RURD_ ELEC WRLN 0.25 TEST_ PBU - WRLN 0.25 RUNPUL ELEC WRLN 0.77 RUNPUL ELEC WRLN 0.53 RUNPUL ELEC WRLN 0.50 RUNPUL ELEC WRLN 0.28 RUNPUL ELEC WRLN 0.25 RUNPUL ELEC WRLN 0.22 RUNPUL ELEC WRLN 0.17 RUNPUL ELEC WRLN 0.12 RUNPUL ELEC WRLN 0.42 RUNPUL ELEC WRLN 0.42 RUNPUL ELEC WRLN 0.58 RUNPUL ELEC WRLN 0.50 RUNPUL ELEC WRLN 0.25 RUNPUL ELEC WRLN 0.50 RUNPUL ELEC WRLN 0.38 RUNPUL ELEC WRLN 0.37 RUNPUL ELEC WRLN 1.00 RURD_ ELEC WRLN 0.50 RURD_ ELEC WRLN 1.00 SAFETY MTG - WRLN 0.50 RURD_ ELEC WRLN 0.50 TEST_ PBU - WRLN 1.08 RUNPUL ELEC WRLN 0.58 RUNPUL ELEC WRLN Page 1 of 2 ,"0 Start: 12/14/2006 Rig Release: Rig Number: Spud Date: 3/13/1967 End: Group: Date From - To Hours Code $\lb Phase Côde 12/15/2006 09:00 - 10:00 1.00 SAFETY MTG - SLICK 10:00 - 10:45 0.75 SAFETY MTG - SLICK 10:45 - 11 :30 0.75 RURD_ SLlK SLICK 11 :30 - 12:00 0.50 TEST_ PBU - SLICK 12:00 - 12:20 0.33 RUNPUL SLlK SLICK 12:20 - 12:40 0.33 RUNPUL SLlK SLICK 12:40 - 12:50 0.17 RUNPUL SLlK SLICK 12:50 - 13:00 0.17 TEST_ PBU - SLICK 13:00 - 13:20 0.33 RUNPUL SLlK SLICK 13:20 - 13:30 0.17 RUNPUL SLlK SLICK 13:30 - 14:10 0.67 RUNPUL SLlK SLICK 14:10 -14:20 0.17 RUNPUL SLlK SLICK 14:20 - 14:30 0.17 TEST_ PBU - SLICK 14:30 - 14:45 0.25 RUNPUL SLlK SLICK 14:45 - 15:00 0.25 RUNPUL SLlK SLICK 15:00 - 15:30 0.50 RUNPUL SLlK SLICK Description of OperatiQ)1I's Arrive @ Beaver Creek field office, sign in and obtain work permit. Mobilize equipment to BC 1A and hold PJSM with JSA Begin rigging up equipment Stab Lubricator and Pressure test to 1000 psig Open well and RIH w/2.70" GR (Well @ 400 psig) Tagged packer x-over@ 8607' SLM, POOH OOH, change out tools to 2" DD Bailer w/ mule shoe bottom. (5' long) Stab Lubricator and Pressure test to 1000 psig Start in hole w/ Bailer Tagged @ 8607' SLM, spudded several times and POOH OOH, check bailer for fill, had fill in bailer and marks on bottom from hitting packer @ 8607' SLM Rig up 2.75" LIB to check for fluid level and tag packer Stab Lubricator and pressure to 1000 psig Start in hole with LIB Tag @ 8597' SLM Maybe saw fluid level @ 1456', well is flowing and cannot see definite fluid level. sharp marks on LIB showing metal jagged edges on bottom, possible that packer is beat up from wirelining in hole Rig down complete Leave well location, turn in work permit and leave lease. Arrive @ Beaver Creek field office, sign in and obtain work permit, hold PJSM with JSA Mobilize to BC 1A location with E-line Truck Warm up and rig up equipment Pickup Lubricator, stab on well and pressure test Start in hole (360 psig surface and .65MMCFD) Fluid Level @ 1678' KB Start 30'/min flowing down pass @ 7700' KB End down pass and start 30'/min up pass @ 8590' KB End up pass and start 60'/min down pass @ 7700' KB End down pass and start 60'/min up pass @ 8590' KB End up pass and start 90'/min down pass @ 7700' KB End down Pass and start 90'/min up pass @ 8590' KB End up pass Shut in well Start @ 7700' KB down pass (shut in 30'/min) End down pass. PU to 7700' KB Start run #2 down pass End down pass. PU to 7700' KB Start run #3 down pass End static run #3 down pass POOH and find fluid level @ 4660' KB @ 738 SITP OOH and rig down unit Turn in work permit and leave location Arrive @ Beaver Creek field office, sign in and obtain work permit, hold PJSM with JSA Mobilize to BC 1A location with E-line Truck. Begin rig up. Pickup PL T string, stab Lubricatorl and pressure test to 1000 psi. Test good. Open well. RIH. (387 psig surface and 2.359 MMCFD) Correlated to depth. Run 30'/min. flowing down pass @7900'. Spinner Printed: 6/19/2007 1 :28:42 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ",..,-~~ TI'\ . ....". v ~_ 6/15/2007 11 :35 - 12:10 12:10 - 12:33 12:33 - 12:47 12:47 - 13:00 13:00 - 13:10 13:10 - 13:22 13:22 - 13:25 13:25 - 14:30 14:30 - 15:30 15:30 - 16:00 Marathon Oil Comp~:my Operations $ummary Rép~ "" . BEAVER CREEK 01A BEAVER CREEK 01A MAINTENANCE/REPAIR Sub Code Code Phase 0.58 RUNPUL ELEC WRLN 0.38 RUNPUL ELEC WRLN 0.23 RUNPUL ELEC WRLN 0.22 RUNPUL ELEC WRLN 0.17 RUNPUL ELEC WRLN 0.20 RUNPUL ELEC WRLN 0.05 RUNPUL ELEC WRLN 1.08 RUNPUL ELEC WRLN 1.00 RURD_ ELEC WRLN 0.50 RURD_ ELEC WRLN . . Page 2 of2 . . Start: 12/14/2006 Rig Release: Rig Number: Spud Date: 3/13/1967 End: Group: Descriptton.of Operatioo$ working. @ 8590' KB. 780 psi. 117 F. Run 30'/min. up pass. Run 60'/min. down pass from 7882' KB. @ 8590' KB Run 60'/min up pass. @ 7880' KB. Run 90'/min down pass. Run 90'/min up pass from 8590' KB End up pass @7878' KB.. POOH. OOH. Shut swab valve. WHP 390 psi. 57 degree F. Rig down. Turn in work permit and leave location Printed: 6/19/2007 1 :28:42 PM I '\L..VL..I v t:u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 6 2007 REPORT OF SUNDRY WELL OPERATI0tiiska Oil & Gas 3. Address: P.O. Box 19168, Anchorage, AK 99519-6168 Plug Perforations Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate g V string WaiverD Time Extensi Re-enter Suspended ell D 5. Permit t ~~~u~~~ ~'r'1 AR Number: ...., -0"") 50 33-20006-~ C)C) to 1. 'Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator Marathon Oil Company Name: 7. KB Elevation (ft): 12' 8. Property Designation: Beaver Creek Unit 11. Present Well Condition Summary: Total Depth measured 10296 feet true vertical 9338 feet Effective Depth measured 8994 feet true vertical 8122 feet Casing Length Size Structural Conductor 526' 20" Surface 2220' 13-3/8" Intermediate 5130' 9-5/8" Production 9697' 7" Liner 287' 41/2" TVD Burst Collapse 526' 1530 520 2220' 3090 1540 4819' 5750 3090 8807' 9960 6210 7747'-8110' .. (Gravel pack) Perforation depth: Measured depth: 8087-8107',8118-81 8797-8817', 8956-8 True Vertical depth: 7265-7284', 7293 7928-7948', 80 Tubing: (size, grade, and measured depth) d J Packers and SSSV (type and measured depth) ~ 83-8223', 8284-8312', 8374-8404', 8439-8459', 8500-8520', 8527-8567', ',7350-7388',7443-7470',7527-7556', 7588-7607', 7646-7665', 7672-7710', 3 1/2", 9.3# 1-80 TO 7890' . -"', .... ,..,-,.--.,.....' . 12. Stimulation or cement squeeze summary: Intervals treated (measured): ceme~l' u zed perfs at 5655-5675' w/60 sacks (\J SCANNED JUL 0 9 2007 Treatment descriptions including volumes ~s and final pressure: Baker 84 SAB 40x30 packer @ 7764', Baker SC-1 packer @ 8607', Baker Model D packer @ 8984', SSV N/A 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that th oregoing is true and correct to the best of my knowledge. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 13. Prior to well op Subsequent to 14. Attachments: Copies of Logs and Surveys Ru Daily Report of Well Operatio 2200 45 o ..,," Tubing Pressure 344 Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: Title Well Work Over Supervisor Signature Phone 283-1308 Form 10-404 Revised 04/2004 ORIGINAL RBDMS BFl JUL 1, ø 2007 Submit Original Only ~ Marathon Oil Company Alaska Region BCIA Beaver Creek Velocity String Procedure History: Well BC lA is a Beluga producer with 3 'l'í"tubing and packer inside 7" production casing. The well is currently producing at 2.3 MMCFPD, 340 psig, 40 BBLS H20 per day. The well experiences shut in problems after being shut in for any length of time. Objective: A 1.75" coiled tubing velocity string will be run to keep the well unloaded. A production log data indicated that most of the water was held up in the section of the well below the second set of perforations. Outline Procedure: 1. Install coiled tubing spool and piping. 2. RU BJ coiled tubing 3. Run 1-314" coiled tubing velocity string and hang off at 8150' MD. 4. RD BJ 5. Unload and test well. Detailed program: Install Coiled Tubing head and flow line / tree modifications: 1. RU Vetco. 2. Set BPV. 3. Close upper master 4. Remove tree and flow spools 5. Install CT hanger spool (Tubing Head) 6. RU Tree 7. PT Tree to 4,200 psi. BC-IA Velocity String Program Rev. 1 6/16/2007 8. Pull BPV Run Velocity String: (After surface modifications) 9. NOTE: Well remains flowing during coiled tubing work. 10. RU BJ CT services. a. MU BOP and injector to tree. b. MU V String BHA (WEG, KEP nipple, Straight Bar, Weld on connector). c. RIH with CT velocity string to 8150' hang off depth.. d. Set slip/pipe combination rams, perform pull/push test, lock rams closed. Bleed off any pressure and break lubricator. e. Cut off dimple on connector and cut 450' off velocity string. f. Install ABB Vetco CT hanger with seal ring. g. Install GS pulling tool to CT with double flappers to 1.75 work string. h. Latch hanger and walk injector head down to MU lubricator. . 1. Land mandrel hanger in CT hanger with 2000 Ibs set down weight. J. Confirm placement by pressure testing void in hanger, install lock screws to confirm integrity. Perform pull test and pump through GS pulling tool at 2 bpm to release. k. POOH with GS pulling tool. I. RDMO BJ CT. 11. RU Pollard wire line service with .125 wire and 1" tool string. a. Hold Pre-job safety and environmental awareness meeting. b. MU lubricator with BOPE to tree and test to 200/3500. c. MU line from CT 1 Tbg annulus to V string and equalize surface pressures. d. RIH with 1" tool string and retrieve 1.188 KEP prong in CT nipple. e. RIH with 1" tool string and retrieve 1.188 KEP plug in CT nipple. f. POOH. g. RDMO pollard wire line. 12. Close well and build 700 psi on velocity string. 13. Close velocity string and flow well through tubing (annulus) to tank and blowout plug in CT. Shut in well. 14. Flow well through velocity string. Minimum flowing pressure is 350 psi (line pressure) on V-string. Test well. Record CT 1 Tbg annulus pressures during test. BC-IA Velocity String Program Rev. 1 6/16/2007 15. Please call Mickey Mullin at 398-9954 or 283-1337 with any questions. Contacts: Work Phone Cel Mickey Mullin Wayne Cissell 283-1337 283-1308 398-9954 394-1324 BC-IA Velocity String Program Rev. 1 6/16/2007 BC 1a l 0 0 0 0 0 0 20 0 0 0 0 526 Cameo Injection Mandrel @ 898' 3.5" Tubing 2.984" 10 Perforations 8087-8107 B-18U 8118-8148 B-18L 8183-8223 B-19 8284-8312 B-20 8374-8404 B-21 8439-8459 B-22 8500-8520 B-23 8527-8567 Angle/Perfs BHP: FWHP: Date Completed: Prepared By: 13.375 o o o Q 2220 - 9.625 o CJ 513CJ o o Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent· Packer With 3.25" 10 2.813 Cameo X Nipple 7815' 2.813 Camco X Nipple 7853' Wireline Reentry Guide @ 7890' 3.25 00 x 2.984 10 c c Perforations Baker SC-1 Packer 4' 10 @ 8607' Perforations 8797-8817' Perforations 8956-8976' Model 0 Packer at 8984' with 3.25" 10 Cast Iron Bridge Plug @ 8994, 9001, 9033 7 00 o 9697 o BC 1a USA o o Don Eynon Last Revision Date: ~ BC1a J '" 3.5" Tubing 2.984" to Perforations 8087-8107 S~18U 8118-8148 S~18L 8183~8223 13-19 8284-8312 13-20 837 4-8404 B~21 8439-8459 13-22 8500-8520 13-23 8527-8567 l o o 20 o o o o 526 Camco Injection Mandrel @ 898' 13.375 o o o o 2220 9.625 o o o o 5130 - Baker 80-40 Anchor on Baker 84 SAB 40x30 Permanent Packer With 3.25" iO 2.813 Camco X Nipple 7815' 2.813 Camco X Nipple 7853' Wire line Reentry Guide @ 7890' 3,25 00 x 2.984 iO 1 3/4" Velocity strin9 @ 8150' ::::::II ::::::II :II:: :II:: Perforations Saker SC-1 Packer 4' 10 @ 8607' Perforations 8797-8817' 2.313 Otis X Nipple @ 8894' Perforations 8956-8976' Model 0 Packer at 8984' with 3.25" 10 Cast Iron Bridge Plug @ 8994, 9001, 9033 7 00 o 9697 o USA o o o o o , AlaSk. Dome . uction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 I i/ ,~f":.A./ ,-/.. , (. -- RE: cPq r :1; /11- Multipoint Gas Well Tests Lß// q~- Bàver Creek Unit Wells BCU-la and BCU-9 K I ~¡'J ~ f/Þf./ ~ I L-uf"':, --b? Çì.Q ~ á ~þ ---.. ) // /" ../ February 5, 1997 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 -- Dear Jack: ~-"---- ~- --- ~~-~ ~..,.. - ~,.-;...->....--- - ~~-,,---.-, Attached in duplicate are copies of AOGCC Form 10-421 with results of multipoint tests for the above referenced gas wells. These multipoint tests are the first to be conducted following the recent completion of permitted activities for these wells. (Sundry completion notices for these activities were previously submitted.) If you have any questions or require additional information, feel free to contact me at 564-6327 ?£:øß Lyndon Ibele Reservoir Engineer n r"- r ~ \ .! i" !~ ;~~t\_~=~ \j eL' r,,-. rCD b" 10ÿ7 ~ \I '"-" i Alaska Oil 2< Gas Cons. Commission Anchorage LCIIkz:H:'WP\ENGIBCU4PT. WPD Attachments A subsidiary of USX Corporation Environmentally aware for the long run. Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 5, 1997 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Multipoint Gas Well Tests Beaver Creek Unit Wells BCU-1 a and BCU-9 Dear Jack: Attached in duplicate are copies of AOGCC Form 10-421 with results of multipoint tests for the above referenced gas wells. These multipoint tests are the first to be conducted following the recent completion of permitted activities for these wells. (Sundry completion notices for these activities were previously submitted.) If you have any questions or require additional information, feel free to contact me at 564-6327 Sincerely, Lyndon Ibele Reservoir Engineer LCI/kz:H:\WP~NG',BCU4PT. WPD Attachments RECEIVED FEB 6 1997 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 GAS WELL OPEN FLOW POTENTIAL TEST REPORT , ._ la. TEST: INITIAL X lb. TYPE TEST STABLILIZED [ I NON STABILIZED ., ANNUAL MULTIPOINT ~ CONSTANT TIME SPECIAL OTHER ISOCHRONAL ~. Name of Operator ......... 7. Permit No. " Marathon Oil Company ""-9~-.22Ct 3. Addres~ ' 8. APl Number'---- -- - f '" 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20(X)6-~t. ~,. Location of W~II 19. Unit or Lease Name ..... At surface Beaver Creek Unit ,,, , , . , 117'FSL, 1338' FEL 10. Well Number ,Section 33, T7N, R10W, S.M. BCU-la ~ il Field a~nd Pool ' Beaver Creek Field, Beluga " 5. lEievation in feet (~J~. DF et=.) 16. Lease Designation and Sedai No. 15' KBI A-028083 , ,. , ,... 2/96 10296 8621 (Fill) Single tl:g. string/cased hole... , ,.,. ., ..... 16. Csg. Size .... Weight per foot, lb. I.D. in inches Set at f. Perforations: From To 7" 26,29 - 9697 8087-8107 8284-8312 85(X).8520 17. Tbs.'Size Weight per foot, lb. I.D. in inches Set at It. 8118-8148 8374-8404 8527-8567 8183-8223 8439-8459 3.5" 9.3 2.992 7890 .... ~18. Packer,~et at lt. '"' J19. GoR cf/bbl. "12~. APl'Liquid Hydrocarbons' ' 21. Specific Gravity Fiowing fluid (G) ...... 7762! -,I - 0.56 22. Producing thru: .... Reservoir Temp. °'F. Mean Annual Temp. °F. Barometric Pres~re (Pa), I:~sia Tbg. r~ Csg. ~'"~ 121 33 14.73 '23'. Length of flow channel (L) 7S90 J Vertical Depth <H) J Ga., 7088 , a ~Co= J %N= 0 0 %~=&lPr°ver''''a a Mete'run J X map~ 24. Flow Data Tubing Data Casing Data ..... Cl~oke ................... Prover Orir~.e Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow .... No.I (in.) (in.) ,,psis hw °F. , psis °F. psis °F. Hr. 1.~ 3.826 X" 2.5 734 6.1 70 1835 53 ....- - 1.833 2.: 3.826 X ~15 '" 726 4.7 "' 74' 2015 ,~3 '- ............ -" 1,917 3.; ' 3.826 X , 2 702 5 77 2210 ......... 53 - - , 1.917 4.~ 3.~26 X 2 681 2.5 83 2315 53 - - 1.917' ,,,,, , , ,,,,, , 5.! X ,,, , ,,,, ,,, B"'~,ic C°efr,:ient ~/ ........... (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super. Comp. Factor Rate of Flow No.: , Fb or Fp Pm Ft .... ,F',~I Fpv , ,, Q, Mcfd 1. 119.2 66.9 748.7 019905 1.336 1.1375 7,975 "2. ' .... 104.3 58.4 ....... ~40.7 0'.~8 1.336 ' ' 'i.1431 "'6,091 " 31 64.7 59.2 716.7 " 0.98~0 '1'.~36 ' 1.1460 '3,831 41 45.7 " 4'~.3 ' 695.7 0.9786 ' 1.336 1.1464 1,887 5. Pg. 125 GPSA Temperature . ' fo~' Separator Gas for Flowing FlUid" No. Pr T Tr Z Gc, I G 1. 1.0f~ ...... 5,30 ,, i,.545 ,,, 0.7728 0.56 .... 2. 1.0645 534 1.557 0.7653 "' 3, 1.0293 537 1.566 0.7~14 Critical preSSUre "' 682 " .... 4. ' 0.9985 543 1.583 0.7609 Critical TemPeratur~ .... 343 "' Fo~m 10-421 Rev. 7-1-80 ,,,,',.,:, kz~A~AS.XLS "" ,' CONTINUED ON REVERSE[SIDE Pc 2,479 Pc~ 6,145,441 Pf 2,940 PF 8,643,600 No.- Pt Ptz ' 'Pcz- Pe Pw Pwz Pc·- Pw~ Ps i~s'~ Pff- P~=' " 1. ' '1,835 3,367',225 2,778,216 -~ - - 2,285 5,221,;'~5 '3,422,~5' 2. 2,015 I 4,060,225 2,085,216 - - - 2,467 6,086,089 2,557,511 3. 2,210 4,884,100 1,261,341 " - - -' - 2,666 7,107,~56 1,536,044 4. 2,315 ~',359',225 786,216 ' - - - 2,801 '718z~,60i '" 797,9~" 5. 0 0 ., , 25. AOF (Mcfd) 20,402 n 0.9873 Remarks: Temperatures under Flow Data and Tubing Data are estimates. Actual values were not recorded, 4-point test conducted on 9/20/96 using downhole electronic gauge recorders. I hereby certify that the foregoing is true and correct to the best of my knowledge. DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic odf~,e factor Mcfd/ -~/ hwiPm Bas~ critical flow prover or positive choi(e factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=l.00), dimensionless Gas-oil ratio, cu. ff. of gas (14.65 psia and 60' F.) per barrel oil (60' F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back. pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Fk3wing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60'F.) Reduced temperature, dimensionless Absoiute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Intemtate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev. 7-1.80 ~O~CCG^S.XLS CONTINUED ON REVERSE SIDE Alaska Reg,un Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 21, 1996 Blair Wondzell Alaska Oil & Gas Conse~ation Co~ission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Blair: Enclosed is the AOGCC Report of Sundry Well Operations Fo~ 10- 404 for BC-iA (Approval Nu~er 95-220). If you have any ~estions, please contact me at 907-564-6315. Sincerely, Michael R. Olson Production Engineer Attachments cc: CEF RECEIVED OCT 2 ~ 1996 Naska 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 REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation Shutdown Stimulate Plugging Perforate X Pull Tubing X 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 117' FSL, 1338' FEL, Sec. 33, T7N, R10W, S.M. At top of Productive Interval 914' FSL, 1383' FVVL, Sec. 34, T7N, R10W, S.M. ~ 7265' tvd At Effective Depth 984' FSL, 1674' FWL, Sec. 34, T7N, R10W, S.M. ~} 8122' tvd At Total Depth 1021' FSL, 1965' FWL, Sec. 34, T7N, RIOW, S.M. I~ 9388' tvd 12. Present Well Condition Summary Total Depth: measured true vertical 5. Type of Well: Stratigraphic Service Effective Depth: measured 8994 feet true vertical 8122 feet 6. Datum Elevation (DF or KB) 16.8 feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-1A 9. Permit Number/Approval Number -22o -- 10. APl Number ~ 11. Field/Pool Beaver Creek Field/Beluga 10296 feet Plugs (measured) 8994', 9001', 9033' md -'- ORIGINAL Junk (measured) Fill ~} 8648' md Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 526' 20" I(XX) SX 526' 526' Surface 2220' 13-3/8" 3500 SX 2220. 2220' Intermediate 5130' 9.5/8" 1800 SX 5130' 4819. Production 9697' 7'' 730 SX 9697' 8807' Liner (Grovel Pack) 287' 4-1/2" - 8607-8984' 7747-8110. Perforation Depth: measured 8087-8107', 8118-8148', 8183-8223', 8284-8312., 8374-8404', 8439,8459., 85(X)-8520', 8527-8567', 8797-8817', 8956-8976' true vertical 7265-7284', 7293-7319' 7350-7388', 7443-7470', 7527-7556', 7588-7607', 7646-7665', 7672-7710', 7928-7948', 8083-8102' Tubing (size, grade, and measured depth) 3-1/2", 9.3~ L-80 to 7890' Packers and SSSV (type and measured depth) Baker 84 SAB 40x30 packer (~ 7764', Baker SC-1 packer ~} 8607', Baker Model D packer ~ 8984', SSSV - N/A 13. Stimulation or Cement Squeeze Summary RECEIVED Cement Squeezed perfs at 5655-5675' w/60 sacks Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A OCT 2 5 .1996 Alaska 011 & Gas Cons /tnnhnr~n~ 14. OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 1600 168 850 15. 17. Subsequent to Operation 8100 6 290 1850 Attachments [ 16; StatUs of Well Classification as: I Copies of Logs and Surveys run Daily Report of Well Operations X Oil__ Gas X I hereby certify that the fo~regoing is true and oorr~_~t to the best of my knowledge. Suspended Production Engineer Service Date 10/21/96 Form 10-404 Rev. 06/15/88 Submit in Duplicate · · r OPEP. ATION SUMMARY REPORT NELL: BC-1A g/O . 01/31/96 1 0 9.000 ACCEPTED RIG FROH MOBILIZATION AT 1700 HRS 1'30'96. R/U SLICK LINE AND RETRIEVED TUBING PLUG, PULLED 'XX' PLUG AT 5/,21', AND OPENED SLIDING SLEEVE AT 5599'. R/S SLICKLINE. R/U LINES TO TREE. PUMPED SATURATED SALT PILL. MONITER WELL. TOOK 25 BBLS TO FILL. MIX SATURATED SALT PILL. 02/01/96 2 0 9.120 KILLED WELL. SET WIRELINE PLUG AT 142'. SET BPV. N/D TREE. N/U AND TESTED BOPE. 02/02/96 3 5455 9.120 FINISHED TESTING BOPE. R/U V DOOR RAMP, CATWALK AND MOUSE HOLE. R/U SLICKLINE AND RETRIEVED PLUG AT 1/.2'. FILLED TUBING AND ANNULUS. R/U WIRELINE AND CUT TUBING AT 8/,71' AND 5/,72'. PULLED HANGER TO RIG FLOOR. CBU. 02/03/96 4 5484 9.260 CBU. POOH L/D 172 JTS OF 3 1/2" TUBING. P/U PACKER RETRIEVING TOOL AND BHA. RIH P/U DRILL PIPE. TAGGED PACKER AT 5471'. CBU. LATCHED PACKER AND PULLED FREE. CBU. POOH. 02/04/96 5 5484 9.270 L/D PACKER. JET CUT FLARED. WAITED ON MILL. M/U BHA. RIH. MILLED OVER TUBING AT 5484'. CBU. POOH. M/U OVERSHOT ASSEMBLY. RIH TO 5484' LATCHED FISH. CBU. POOH. NO RECOVERY. REDRESSED OVERSHOT. RIH. 02/05/96 6 5/*84 9.340 RIH WITH OVERSHOT. P/U KELLY AND WORKED OVER FISH. PULLED FREE. CBU. POOH. L/D FISH. M/U BIT AND SCRAPER. R IH. TAGGED PACKER AT 5645'. CBU. POOH. RIH WITH PACKER RETRIEVING TOOL. PULLED PACKER FREE. CBU. RAISED BRINE WT TO CONTROL GAS. 02/06/96 7 8619 9.550 FINISHED RAISING BRINE WEIGHT TO 9.5 PPG. POOH. L/D PACKER. POOH L/D 94 JTS OF 3 1/2" TUBING. RIH WITH BIT AND SCRAPER TO 8619'. CIRCULATED AND SWEPT HOLE. POOH. 02/07/96 8 8619 9.600 POOH. BNA. M/U RETRIEVABLE BRIDGE PLUG AND RTTS. RIH. SLIP AND CUT DRILL LINE. RIH. SET RBP AT 5775'. TESTED TO 3000 PSI WITH RTTS. POOH TO 5219' AND SET RTTS. ESTABLISHED INJECTION RATE OF 2 BPM AT 1500 PSI. CBU. REPAIRED RIG. POOH. DID NOT LEAVE RBP AT 5775'. L/D RTTS. RIH WITH RBP AND SET AT 5775'. POOH. 02/08/96 9 8619 9.600 FINISHED POOH. RIH W/ RTTS AND SET AT 5725'. TESTED BRIDGE PLUG TO 3000 PSI. POOH. RIH W/DP. CBU. DUMPED 12 SX OF SAND ON TOP OF BRIDGE PLUG. TAGGED SAND AT 5758'. MIXED AND SPOTTED 150 SX CEMENT PLUG AT 5700'. POOH TO 4455'. REVERSED OUT. SQUEEZED 12 BBLS (60 SX) OF INTO PERFORATIONS. WOC HOLDING PRESSURE. 02/09/96 10 8619 9.600 WOC, HOLDING PRESSURE. POOH. ATTEMPTED TO SET RETRIEVABLE BRIDGE PLUG AT 500', LOST BRIDGE PLUG. RIH TO 5280' AND LATCHED BRIDGEPLUG. POOH. RIH WITH 20 STANDS DP THEN SET STORM PACKER AT 80'. N/D STACK AND INSPECTED TUBING SPOOL. PULLED STORM PACKER. R/U TO TEST BOP' S. OPERATION SUMMARY REPORT NELL: BC-1A W/O . 02/10/96 11 8619 9.600 TESTED BOP'S. R]H TO 4700'. REAMED 4700' TO 5270'. TESTED CASING. DRILLED CEMENT FROH 5270 TO 5371. CBU. TESTED CASING. DRILLED CEMENT FROH 5371 TO 5470. CBU. TESTED CASING. DRILLED CEMENT FROH 54?0' TO 5600~o CBU. TESTED CASING. DRILLED CEMENT FROH 5600~ TO 5690". 02/11/96 12 8619 9.600 DRILLED CEMENT FROM 5690~ TO 5700'. CBU. TESTED CASING. DRILLED CEMENT FROM 5700~ TO 5720'. WASHED SAND FROM 5720~ TO 5758j. PUMPED HI VIS SWEEP. POOH. M/U BRIDGE PLUG RETRIEVING TOOL AND RIH. WASHED SANO FROM 5757~ TO 5767~ CBU. LATCHED BRIOGE PLUG. CBU. POOH. M/U BIT AND SCRAPER. RIH TO 8619~. CBU~ PUMP OOWN ACTIVE PITS. 02/12/96 13 8619 8.500 PUMPED DC)~N ACTIVE PITS. CLEANEO PITS. DISPLACEO WITH 3~ KCL. POOH, L/D DRILL PIPE. R/U ANO STARTED RUNNING 3 1/2" PROOUCTION TUBING. 02/13/96 14 8619 8.500 RAN PROOUCTION PACKER ON 3 1/2" PRODUCTION TUBING. LANOED HANGER WITH TUBING TAIL AT 7890~. CIRCULATED AND INHIBITEO 3~ KCL. SPOT 5 BBLS DZESEL IN ANNULUS. DROPPED BALL AND SET PACKER. TESTEO PACKER. TESTED ANNULUS. SET BPV. STARTED N/D BOP~S. 02/14/96 15 8619 N/O BOP'S. N/U TREE AND TESTED SAME. RELEASED RIG TO OEMOB AT 1500 HRS, 2'13-96. OPERATION SUI~IARY REPORT: POST RIG WELL: BC-1A 2/26/96 8621' RU HWS. RIH w/ 2.0" GR. Tag fill at 8621' RIH w/ swab cups and swab well down to 3200'. Well started to flow. SI well. WHP inc to 400 psig in 5 min. Unable to bleed down well. SI well and RD. 3/13/96 8621' Flowed well @ 580 mscfpd @ 710 psig WHP. RU SWS and RIH w/ PL tool string. Made stationary stops above and below B-23 squeezed perfs. Made 30 and 60 fpm up and down passes. Interpret logs: most of gas flowing from leaking B-23 perfs, w small amount of gas coming from B-26 and 28 (sanded back). 3/14/96 8621' RU SWS and perf 8527 - 8567' (B-23L) w/ 2-1/2" HC, 6 SPF, 60 degree phasing. Test well @ 1900 mscfpd, 2200 psig WHP. RIH w/ 2-1/2" HC and sat down at 85' Unable to get past hydrates. Flow well over night while injecting methanol. 3/15/96 8621' RU SWS and RIH w/ dummy gun. Worked through hydrates @ 221', 331'. RIH to 550' - OK. RIH and perf 8500 - 8520' (B-23M) w/ 2-1/2 HC, 6 SPF, 60 degree phasing. Test B-23 M/L at 2100 mscfpd, 2100 psig WHP. 4/4/96 8636' RU HWS and RIH making flowing gradient stops. Tag fill at 8636'. Record FBHP for 6 hours. SI well for 100 hour PBU. POOH making gradient stops. DD = 31.8% at 4030 mscfpd, 1835 psig WHP. 5/8/96 8636' RU SWS and perf 8439 - 8459' (B-22) w/ 2-1/2" HC, 6 SPF, 60 degree phasing, 900 psig underbalance. Test B-22-23 at 4192 mscfpd, 1820 psig WHP. 5/10/96 8636' RU SWS and perf 8374 - 8404' (B-21) w/ 2-1/2" HC, 6 SPF, 60 degree phasing, 1000 psig underbalance. Test B-21-23 at 4200 mscfpd, 1825 psig WHP. 8/22/96 8630' RU HWS and RIH making flowing gradient survey. Tag fill at 8630' Make flowing temperature pass across perfs. 9/4/96 8630' RU SWS and perf 8284 - 8312' (B-20) w/ 2-1/2" HC, 6 SPF, 60 degree phasing, 900 psig underbalance. Test B-20-23 at 4200 mscfpd, 1570 psig WHP (note same BHP, WHP lower due to water loading in casing while rate was cut back). 9/6/96 8630' RU SWS and perf 8183 - 8223' (B-19L) w/ 2-1/2" HC, 6 SPF, 60 degree phasing, 750-950 psig underbalance. Test B-19L-23 at 4900 mscfpd, 1600 psig WHP. 9/10/96 8630' RU SWS and perf 8118 - 8148' (B-18L) w/ 2-1/2" HC, 6 SPF, 60 degree phasing, 850 psig underbalance. Test B-18L-23 at 5500 mscfpd, 1600 psig WHP. OCT OPERATION SUI~IARY REPORT: POST RIG WELL: BC-iA 9/12/96 8630' RU SWS and perf 8087 - 8107' (B-18U) w/ 2-1/2" HC, 6. SPF, 60 degree phasing, 750 psig underbalance. Test B-18U-23 at 8100 mscfpd, 1850 psig WHP. 9/20/96 8648' RU HES and perform 4 point. PRODUCITON CASING: 0 0 - 51300 (OD:9 5/8 I'LJB~NG: 0 0 7890 2 (OD:3 1/2 ID 2 63/64) CAMCO iNJECTION MANDREL: 897 9 9049 (OD:5 1/4 ID:2 63/64) BC-1A BAKER 80 40 ANCHOR: 7762 5 - 7763 6 (OD4 1/2 ~D3 1/4) BAKER 84 SAB 40x30 PACKER: 77636 7768 5 (OD6 3/16 lO:3 1/4) CAMCO X NIPPLE 7814 8 - i'816 2 (OD:3 61/64 ID:2 13/16) CAMCO X NIPPLE: 7853 1 7859 5 (OD;3 61/64 ID 2 13/16) W[REL/NE REENTRY GUIDE: 7869 5 - i890 2 (OD:3 1/4 ID:2 63164) B 18U BdBt B20 B 21 B25 BAKERSC 1 PACKER 86073 86109(OD:531/321D4) TUBING 86109 - 8783 6 (OD:2 7/8 ID:2 7/16) Sand Fill 8648 0 8994 0 (OD:2 7/16) GRAVEL PACK: 8783 6 8693 5 (OD 4 1/2 ~D:2 7/16) OTIS X NIPPLE: 88935 88946 (OD:3 1/4 iD2 5/16) GRAVEL PACK; 8894 6 8984 0 (OD 4 1/2 ~D:2 7/16) BAKER MODEL D PACKER 8984 0 8967 4 (OD:5 11/16 ID:3 1/4) BRIDGE PLUG: 89940 89980 (OD:6) BRIDGE PLUG: 9001 0 - 9005 0 (OD:6) BRIDGB PLUG: 9033 0 90370 (OD:6) RECEIVED 0C7 2 ~ 1996 UWl 50-I 33-20006-01 10117~96 Alaska Re Domestic I~rod~uction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 21, 1996 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 The following well logs are enclosed: Description Kenai Gas Field "7~- i~ ~ KBU 41-7 Multiple Isotope Tracer SurveY Beaver Creek Field Beaver Creek No.' 1-A ~"7 -- ~~ Completion Record, 2.5 HSD, 8-May-96 Completion Record, 2.5 HSD, 10-May-96 Print Film 1 1 1 1 1 1 This data is considered confidential until the normal release date. MARATHON OIL COMPANY kz/H:~wp~expl~aogctran.ltr Enclosures Received By: Date: Alaska Oil & Gas Cons. Corem'talon And~orage A subsidiary of USX Corporation Environmentally aware for the long run. R "CEIVED Letter of Transmittal March 26, 1996 MAR 2 6 I~I~RATHON OIL COMPANY 3201 C Street, Suite 800 Alaska 011 & Gas Cons. C0mmis~ Box 19616~., Anchora e '" "" ': ~nchorage, Alaska 9951'9~6168 Telephone: (907) 5.61-53!T, Fax: (907)':5,6.4-:6Z~89 "'? .. , ~..,~., ~'::'!!.:f' ...:.;. TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 .' FROM: Chick Underwood Exploitation Department WELL LOGS Description Print Kenai Gas Field ~?KDU-2 COMPLETION RECORD 2 1/2" HSD Beaver Creek Field COMPLETION RECORD 2 1/2" HSD 1 PRODUCTION LOG TEMP/GRADIO/SPINNER I TOTAL 3 Film 1 This data is considered confidential until the normal release date. (Marathon Oil) (Date) (ReceiVed By) (Date) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing ~ Repair Well Plugging X.,. Change Approved Program Pull Tubing X Variance Re-enter Suspended Well~ Time Extension Stimulate X Perforate X 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 117' FSL, 1338' FEL, Sec. 33, T7N, R10W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service 591' FSL, 46' FEL, Sec.' 33, T7N, R10W, S.M. At Effective Depth 688' FSL, 37' FWL, Sec. 34, T7N, R10W, S.M. At Total Depth 1003' FSL, 1966' FWL, Sec. 34, T7N, R10W, S.M. ORIGINAL 12. Present Well Condition Summary Total Depth: measured 10,296 true vertical 9,390 feet Plugs (measured) feet 6. Datum Elevation (DF or KB) 15' KB above GL 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-1A 9. Permit Number 67-9 10. APl Number 50-- 133-20006-01 11. Field/Pool Effective Depth: measured 8,994 true vertical 8,122 Casing Length Size Structural Conductor 526' 20" Surface 2,220' 13-3/8' Intermediate 5,130' 9-5/8" Production 9,697' Liner feet Junk (measured) ~.~L~ Oil & G.:~s Cons. Commi~ioa feet ~mhcrag,~ Ce~ M~sur~ De~h T~ Ve~l D~ 1~ SX 5~ 5~ ~ SX 2,~ 2,~ 1~ SX 5,1~ 4,81ff 7~ SX 9,~7 Per/oration Depth: measured Sea attached true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.3~, L-80 to 8,617, 1. Baker SC-1 {~ 5,455' 2. Baker SC-1L {~ 5,634' 3. Baker SC-1 Gravel Pack Packer {~ 8,607' 4. Sump Packer {~ 8,984' feet 13. Attachments Description Summary of Proposal Detailed Operations Program .~X BOP Sketch 14. Estimated Date for Commencing Operation 115. Status of Well Classirmation as: i Oil~ Gas X ,. Service 16. If Proposal was Verbally Approved Name of Approver Date Approved Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION US~'ONLY '~' Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test / Location Clearance Mechanical Integrity Test --"~ubsequent Form Required 10- //"'""~/,.f Original Signed By David W. JOhnston Approved by Order of the Commission Form 10-403 Rev. 06/15/68 IApprov~_l No. Approve~l Col~--- ~ Returned Commissioner Date Submit in Triplicate H:~F_XCEL~BCIAAOGA.XLS (nfs) 12/13/g5 Form 3. t 60-5 . (May 1989)' U N IT,~D STATES ~UBMIT IN TRIPLr~-'~(E* (Other Instructions DEPARTMEN ~F THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ~xse this form for proposals to drill or to deepen or plug back to a differeut reservoir. Use "APPLICATION FOR PERMIT--" for such FORM APPROVED OMB NO. 1004-0135 Expires: September 30, 1990 5. LEASE DESIGNATION AND SBIIAL #O. J~. IF INDIAN, ALLOTTEE OE TILES NAME 1. 7. UNIT AOEBEMBNT NAME o,L []] GABPZ1 Beaver Creek Unit WSLr. WELL ~ *TH ~-R 2. NAME Or OPERATOR 8. FAIM 0S LSASE NAME MARATHON OIL COMPANY ? Beaver Creek 3. ADDRESS Or OPERATOR P. O. BOX 196168, Anchorage, AK 99519-6168 4. LOCATION OF IVELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 117' FSL, 1338' FEL, Sec. 33, T7N, RIOW, S.M. 9. WeLL NO. BC-1A 10. FIELD AND POOr., 0S WILDCAT Beaver Creek Field 14. PERMIT NO. J 1,5. ELEVATIONS (Show whether Dr. RT, OR. et~) 67-9 J 15' KB above GL 10. Check Appropriate Box To Indicate Nature o[ Notice, Report, or Other Data 11. SEC., T., i., M., OI ELK. ddlD SUuVBY OS ddimA Sec. 33, T7N, RIOW, S.M. 12. eOONTY 08 P&IISHJ 18. ST&TS KenaiI AK NOTICE OF INTgNTION TO : TEST WATER SHUT-Orr [ { Pf'LI, OR ALTER C ISING ['--/~'1 FRACTUEE TRE&T M L' LTIPLE CO M PI.ETE SHOOT OR ACIDIZ~ ABANDON* nZPAIR WELL CHANGg PLA~ (Oth~r) 8UBSEQUSNT REPOuT Or: FRACTURE TIEATMgNT ALTSEING CASING 8HOOTING OR ACIDlY. lNG ABANDONMSMT° (Other) . (NOTE: Report results of multiple completion on Well Completion or Recotapletion Report and Log form. l DESCRIBE PROPOSED OR CO.~IPI.ETED OPERATIONF. (Clearly stat~ all pertinent detnil.~, and .~lve pertinent dates, Including ~tlmated dste of starting any prop.sell work. If well is direct(.nelly drilled, give subsurface Ioe~tions and meas,,red and true vertical depth~ for all marker, end ~on~ imrti- nent to this work.) * See attached addendum 18. I hereby certify that the foregoing Is true and correct (This space for Federal or StAte oflic~ u~) APPROVED BY ~ONDITIONS OF APPROVAL, IF AN~: TITLE DA~E *See Instructions on Rev~ Side Title 18 U.S.C. Section !001, makes it a crizne for any person knowingly and willfu!Iv to make to any department or agency of the Un/tea States ~ny raj.se, flctit~ous or fraudulent statements or representations as to any matter w~thin its jurisdiction. BC-1A PERFORATIONS STERLING 5300' - 5310' 5430'- 5445' 5488'- 5520' 5520'- 554O' 5655'- 5675' 10' 15' 32' 20' 20' 5,117' - 5, 143' TVD B-1 SQUEEZED B-2 SQUEEZED B-3 B-3 SQUEEZED B-4 SQUEEZED BELUGA 8522' - 8564' 8747' - 8817' 8956' - 8976' 42' 20' 20' 7,667' - 7,707' TVD 7,931' - 7,950' TVD 8,085' - 8,104' TVD B-23 SQUEEZED B-26 B-28 H:\WP\ORiU.95\BC1APERF.WPW (nm) 12/13/95 BC-1A WORKOVER PROCEDURE . . 3. . . . . . . 10. 11. 12. 13. 14. 15. R/U coiled tubing unit and sand back Lower Beluga B26/28 to 8610'. with KWM.-) Ensure annulus full. b,'[[ ~ ,,,,,,,..,..4. Set BPV. Fill tubing Move in and rig up workover rig. N/D tree, N/U BOP's and test to 250/3000 psi. Clean out wellbore to Packer @ 5634'. Squeeze Sterling B-3 perforations. Clean out wellbore to GP Packer @ 8607'. Set production packer at 8000'. Run 3-1/2" production tubing. Set BPV. N/D BOP's, N/U tree and test. Rig down and move out workover rig. Perforate Lower Beluga B-23 8525-8580. Frac as required. Flow test and evaluate. Perforate and flow test Lower Beluga B18/21 8085' - 8310'. Frac as required. Perforate Lower Beluga B-24 8640' - 8680'. Commingle B-18 through B-24. H:\WP\ DRILL95\ E)C 1AWO.WI=W (nm) 12/1;3/1~ 542t' []tis "X' Nipple <3.813' IDb. 5455' Bat<er- SC-' ;"kr' w,'SBE 5455'-5468' 2ea~ assr ~. Hu~eshoe 5476'-5536' Btost _,~cs ~ .... heavy .~oil pipe 4.5' OD 3.0' ID:, Dtls 'XD' Si,ding S(eeve (2.813'ID) '(Opens down). 5634'-5644' Baker SC-IL Pkr w/Mittout lrxt 5634'-5637' Baker- 3-33 Locator', 5678' Otis X NilDpte 8607' Baker SC-! Grvt Pk Pkr 8631' GP-12 SDSJ w/43,000# p,n. 6634'-8784' b d:s 2-7/8' Stank p,pe w/wetd-on cenl:r-atizer-s ever'v 3uat Screen Pr'e[:)acx screen O.Ol~' 9ouge, 80/40 resin coo~ed s~nd, weta-on cen~¢6tizems every 88~4' B~is 'X' Nippte (8.313 8895'-8974' 5 3ts 3uat Screen Pmepack. 8974' ~-ning Sub a975'-8983' 8-7/8' O.Oie gauge wi~e w¢apped Tett-TaLe. 8983' Snao Latch ~ Sept ossy. Stuck Ret BP's e 8994' 900~', ~nd 9033'. Tn ¢ IO P96,' MARATHON OiL CS BEAVER CREEK WELL SC-lA Comot,?l:ect i2/30/89 i i Att measurements are RKB to 1:ap .. , oF equil2. RK B=]6.85' 3-i/_:" ':33~ L-80 EUE 8RD AB Nap -o9 '29~2' ID). B-! 5300'-5310' ' ~ B-2 ~,430'-5445' L-=--=----- B--' 5488'-55~0' i . ~ ~ ., , i I ~ B-4 5655'-5675' I 3-1/8' 9.3# L-80 £UE 8RD AB MoO Tbg (8.998° UndeF ineO 8522'-8564' '-,, , i Reservoir' Datum: ~ Sterling-5000' Sub Sec, P~etuge.- .9000' 3up 3eo ' .... i UndeFined 8797'-8817' .L~ B-C 8956'-8976' UncleF,ned 9104'-9114' I I ] ~evision Dote: 2/15/95 i Revised By: VHR/evo k / , =SAVER _ CREEK, SC No. '!A ?RO?OSED WELLBORE SCHEMAYtC 94 ppf, h-40 @ 526' 1,3 5/8" , 61 ppf, J-55 (D 2,220' . 3 1/2" Tubing Existing 825 sqz perfs 8,522'-8,564' Baker $c-1 Grvl Pk Pkr @ 8,607' :qP-!2SOSJ @ 8,651' w/ 43,000¢ pin l Ir : 7/8" bt(Ink pipe 8,634' -- 8,784' Ouel prepack screen 8,784' -- 8,894-' 9 5/8", 45.5 & 40 ppf, N-80 ~ 5,150' Upper Belug<a (8-1,2.5.4.) squeeze perfs at 5,.300' - 5,675' MD P~cker set at 8,000' MD L. Betug(] 825 (8.52.5' - 8.580'): Perf. flow test. evaluate, .Stoqe 1 fr~c stimul(]tion. L. Beluga 824 (8,64.0' - 8.680': Perf and commingle witia 82.3 followin~l fr(]c stimul(]tion. Uphole recompletion ovail(]ble in the L. Belug(] B18-21 (8,085' - 8.510': Uphole recomptetion and possible fr(]c immediately following B2.3/24 work. B-26 8,797' - 8,817' 8-28 8,956' - 8,976' 7" , 26/29 ppf, N-80, Pl10 @ g,697' MD (}AM .3/04/95 EXHlSrr A PROPOSED BOP STACK CONF]GUEAT~ON 13 5_/8 RSRP, A ,if' '1 ~3 ~/~-'~o, oom:~ HUe eonou ,(, 1/16"'-5.0C10~ ~ ~ BLOW-OUT PREVENTER STACK PAA WORKOVER RIG MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907 564-6435 Letter of Transmittal October 17, 1995 TO: Howard Okland Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM: Chick Underwood Exploitation Department Description L~,o~ Print Film Beaver Creek #1-A Production Log -1' ,1- ~,Kenai Unit 21-6L TDT-P ..1--/~ .A"~.~. e~..~.,,'Kenai Unit 34-31 TDT-P ~ .,Kenai Beluga Unit 33-7L TDT-P ~" ~ ~"/Kenai Deep Unit #1 TDT-P _~ _A/ The data is considered confidential until the normal release date. (Marathon Oil) (Date) (Date) Please Return I Copy by Either FAX or Mail to Marathon RFCF!VED OCT 1 7 1 95 Ala. ?egion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 10, 1995 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Wondzell' Attached is the AOGCC "Report of Sundry Well Operations" for Beaver Creek Well BC-1A. Should you have any questions regarding this report, please contact Mike Olson at (907) 564-6315. Sincerely, Mark F. Sinclair Drilling Superintendent Encl. RECEIVED MAY 1 5 1995 Oil & Gas Cons. Commission .... ' ~/lchomge A subsidiary of USX Corporation Environmentally aware for the long run. 3/¥Ol-ldNO NI J. IINSNS ell!i peu§!s · e§PelMOU)l Au jo lseq eql ol looJJOO pue emi s! §u!o§eJol eql mql/[t!lJeO AqeJeq I ZL eo!^Jes ~ pepuedsns "% ss9 ~ I!0 :se uo!leoy!sselo Ile~ ~o snlelS '9~ -X- suo!mJedo IleM 1o ~Jodel~ Xl!eO -~ unJ S/ICA JrtSpue S60'1 ~O se!doD slueuJqOellV 008I 0 0 0017' I §6/0~/17 uo!mJedo ol 1uenbesqns OZ9 0 I~ 000'I § 6/Z I/17 UO!leJedo IleM O1 JO!Jcl (,l~b~) 'U LepoN (peJnseew) peleeJ1 sleAJelUl /~Jewwns ezeenbs luaweo Jo uo!lelnwIIS 'C L (qldep peJnseeuJ pue ad/[1) ASSS pue sJ@23ecJ qldep leo!pe^ enA qldep pe]nseev~ pelueuJa3 ems qlbUe'l 1eel , ~ ~ I ~ ~ leo!lJe^ emi , ~Z6 ' ' , [006 , ~668 d8~ ~3n~s (peJnseeuJ)~un¢ ~eej , ~66'8 pemse@uJ :qldep@^!ioa~3 ~eei ,06~' 6 (~uama3) ,96Z'0[ - ,ZI9'6 (peJnseeLu)sBnl8 1eel ,96Z'01 leO!peA enJl peJnseeLU :qidep lelOj_ /(JewuJns uoil!pu0o IleM iueseJd 'g L e6n LaG/6U.L Laa%S IOOd/Ple!-4 'L L NS-MOI-NZ '17g'oas ' NS-MOI-NZ 'I~S 'oas "lMJ,Z~"lSJ ,889 q~depe^!loagelV NS-MOI-NZ ' EE'oaS' -13J, 917' 'ISJ, I6§ le^Jelu!e^qonpoJdlodoilv NS-MO I-NZ ' SS' oaS' 93J, 8~I' 9SJ, Z I I ooepns m ,e~ lo uo!mooq '~ -- Jaqlo -- IIOM J!edebl -~ eleJoped -- 6u!66nld IS66 ~V a6e,~oqouv '89196I xo~] 'O'd ssoJpp¥ 'C £uedmo3 L.LO uoq%e.~eN JomJedo Jo at.ueN '8 -- §u!seo JellV -- Bu!qnl lind ' -- emlnuJ!lS -- UMOpinqs uo!mJado :poLuJOped suo!leJodO 't SNOI.LV =IdO TI:IM Aa(iNnS _-IO .U:lOd3U NOISSIRROO NOIIVAEi3SNOO SV9 ONV -110 V)lSVqV ' ., VNSVqV 40 ~IV/S 4/18/95 4/19/95 4/20/95 4/21/95 5/5/95 5/9/95 Future: Note: BC-1A: Attachment #1 Perforate Beluga B-23 Through Tubing Summary of Daily Well Operations PT lubricator to 3500 psig. OK. RIH and perforated 3- 1/2" tubing at 8540-8541.5' using a 1-11/16" through tubing puncher, 0 phasing, 8 shots total. The WHP increased from 1450 psig to 1750 psig. POOH. Unable to flow well due to u-tubing completion fluid from behind pipe. Brought well on line and monitored production for leaking squeezed Sterling B-4 perforations. mmscfpd bwpd Before tubing punch: 1.0 31 After tubing punch: 1.4 0 FTP, psig 670 1800 SI well, WHP increased to 1840 psig. This corresponds to the expected 2200 psig BHP for the Sterling B-4 Sand. PT against WHP. Ran a sweep of production logs from above the Sterling B-3 perforations to below the Beluga B-23 perforations with the well flowing and shut-in. POOH. Analysis indicate gas is being produced from the Sterling B-4 squeezed perforations and through the tubing punch holes. There is no production coming from the squeezed Beluga B-23 perforations or from the open Beluga B-26, 28 perforations. Water analysis of the produced water was inconclusive of confirming Sterling B-4 water production due to a mixture of NaC1 completion fluid. 1912 mmscfpd, 19 bwpd, 1450 psig (water is gradually increasing at approximately 1 bpd) There are no plans to proceed with perforating the Beluga B-23 sand. Plans are to continue producting the well from the Sterling B-4 sand until the well is worked over. A produced water sample will be obtained next month to further confirm Sterling B-4 production. Discussed work done and current plans with Blair Wondzell on 5/9/95. RECEIVI D MAY 1 5 1995 Oil & Gas Cons. Commission ~orag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abanao~ __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time ex'tens,on --._~. o~'timutate-~r Cnange approved program __ Pull tubing __ Variance __ Perforate 2. Name of Operator j 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Company t Development__ 153' KB ~ ---- Exploratory M 3. ~ ~ -- Stratigrapmc__ 7. Unit or Property name P. 0. Box 196168 Anchorage AK 9951cj-61 8 Serv,ce__ Beaver Creek Unit feet 4. Location of well al sudace 117' FSL, 1338' FEL, Sec. 33 7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33 7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34 7N-10W-SM At total depth 1003' FEL~ 1966' FWL~ Sec. 34 7N-10W-SM 12. Present well condition summary Total depth: measured true vertical 8. Well number BO-lA 9. Permit number 67-9 10. APl number 5o- 133-20006-00 11. Field/Pool Sterl inq/Bel uqa 10,296' feet Plugs(measured) 9617' - 10,296' (cement) 9,390' feet Effective depth: measured 8,994' feet Junk(measured) stuck RBP 8994', 9001 ' , 9033 ' true vertical 8,122 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 526' 20" 1000 SX 526' 526' Intermediate 2,212' 13-3/8" 3500 SX 2,212' 2,212' Production 5,130' 9-5/8" 1800 SX 5,099' 4,793' Liner 9,697' 7" 730 SX 9,697' 8,807' Perforation depth: measured 5488 - 5520' 8797 - 8817' 8956 - 8976' truevertical 5117 - 5143' 7931 - 7950' 'Fdblng(size. grade, and measured depth) 3-1/2", 9.3#, L-80, 8607' Packers and SSSV (type and measured depth) Baker SC-1 (5455', 8607'), Baker SC-IL (5034'), Baker Model D (8984') 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation April 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas X~ Suspended Service 17. I hereby certify that the fo. regoing is true and correct to the best of my knowledge. Signed/~.~,~· ~~,.:. Title /,~/~ ..,,,¢~z¢/, FOR COMMISSION USE ONLY Date LC ,"/"2. -S ~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Original Signed By David W. Johnston I Approval NO. ~ ~'"'_ ? 3 ~pproved Copy yl~{eturrled CommiSsioner Date ~'//~ ¢/1~~'~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Marathon Oil Company AFE 8101595:B-23 Perforating Procedure Well BC-1A Field/Platform: Beaver Creek Lease: A-028083 Site: Pad 1A Packer: Tbg: 5455', 5634.55', 8607.29' 3-1/2" 9.3//L-80 Sand: B-26, 28 EOT: 8607.20' KB: 12.0' Est Start Date: 4/18/95 Est Comp Date: 4/19/95 Status: 1.05 mmscfd, 31 bwpd Min ID: 2.813" (5421', 5677') (1.9" thru gravel pack) Fill depth: Tubing clear 8617' (2/9/94) Tree Connection: 3-1/2" 8rd OBJECTIVE: i Perforate the B-23 sand (8522-8572'). POTENTIAL PROBLEMS: J Hydrates have been a problem in this well, annular volume between 3-1/2" tbg and 7" csg is 78 J bbis (5644'-8607'), note pressure differential between zones: B-23 (3420 psig), B-26, 28 (2250 psig). LAST WIRELINE WORK: [2/16/94 Recovered X-lock from X-nipple @ 5678'. PROCEDURE: il) Hold safety/environmental meeting, and review e-line procedure and previous wireline world. !2) SI well at the wing valve. !3) Complete the "Perforating/Explosives Safety Checklist" proceaure prior to arming or disarming the ~: perforating gun. 14) PT equipment to 3500 psig using water. ~.5) RIH w/ 1-11/16" jet perforator, mal<e correlation run fram 8650-8500', and perforate the tubing at 8560- i8562' (2/16/90 PL), 4 spt, 0 deg. phasing. Drop down below pert hales immediately after perfarating. '6) POOH. (Recommission communication system after verifying the blasting cap has aetonatea.) 7) Test well for a min. of 24 hours, note: gas/water rates, and tubing/casing pressure every two hours. 8) SI well at the wing valve. 9) Complete the "Perforating/Explosives Safety Checklist"" procedure prior to arming or disarming the perforating gun. (The Schlumberger '~afe System" will be used to detonate the 2nd perforating guns.) 10) PT equipment to 3500 psig using water. 11) RIH and perforate B-23 using Schlumberger 2-1/2" deep penetrator hollow carrier gun, 6 SPF, 60 deg. i pt~asing (Note SI tubing and casing pressures before and after each run): ~-~'~-~cl~ Run 1' 8542-8572' (3a') - correlates to 8538-8568' CCL on the 2/16/90 PL. i Run 2: 8522-8542' (20') correlates to 8518-8538' CCL on the 2/16/90 PL. ,~12) POOH and RD. (Recommission communication system after verifying the blasting cap has detonated.) ~13) Return welt to production slowly - do not exceed a 30% drawdown. QUESTIONS/COMMENTS? Mike Olson, ext. 315 APPROVALS: (Mark F. Sinclair) (Terry J. Kovacevich) Fax to KGF Foreman p~asV, a 0il & {~as (~ons. (~omm~sion ~chora~e H :excel ~ wireline ~ bc ~ bc-1 a ~ 002.xls 525° ~2~0' '3-3/8', 6tt~, J-55 =:30' ?-5/8°, 43.5 & 40~, N-80 9597' -", 5,09' 3aker Injection N~oDte (3.0° [-~)- 5455{ ~ake~ SC-I Pkr 5455'-~468' Seal ashy & Hulesnoe 5476'-5536' Bta~ jt~ (3.5' heavy 5599' ~t;s 'XD' Sliding Sleeve (2.BlS'ID) (~;2ens clown). 5534'-5644' Baker SC-il Pkr 5634'-5637' B~ker S-28 Locator, Snalatatch & Sem~ assy. 5678' Otis "X' Nipple (2.813' ID) 8607' B&ker SC-! Orvt Pk Pkr' 9631' 5P-12 SBSJ w/43,000ft p~n. 8634'-8784' 6 jl:s 8-7/8' Btank pipe w/we[ci-on cen~:rmllzers =_very 15', ¢J784'-8894' 6 J~cs 8-7/8' x 4,-1/8' Duoi Screen PreDo. c.k screen 0,01~ gauge, 20/40 resin coal:ed sanct, weld-on cen~cr'~LIzer'5 every ].0'. 8894' Ct;s 'X' N;ppte (E. 313 ' lO). 8895'-8974' 5 J~s 8-7/9' x 4-t/8' ~al Sc~'een Pr-eDo. c:t<. '3974' ~-rtng Sub 8975'-e~B3' e-7/8' 8983' Sn~D L~ch & Seat assy, S~uck Re~ BP's e 8994', MARATHaN OIL COMPANY DEAVER CREEK FIELD "JELL BC-IA Att MeasureMents are RK]] to tcc oF eau;o. (Correct,on, Tbg Meas to RKB -4.9t'). 3-1/2' 9.3I~ L-@O EUE 8RD AB Mca Tbg (2.99B' ID). ~ B-+ 5655'-5675' 3-1/2-' 9,31~ L-80 EUE 8RD AB Mo' Tlog (2.99B' II]). B&-~-23 8522' - 8564' RECEIVED APR 1 2 1995 &laska Oil & Gas Cons. Commission Anchorage R~servolr 9a~cum, Ste.,'-tmg-50OO' Sub Sea Betug~- 9000' Sub Sea B-26 8797'- 88!7' B-28 8956'- 8976' Uncteflnect cJtO4'-gtl4' Revision Date: 3/14/95 Revised By: MRO Rea~. Correct 'X' NiDDle DeDtt Prey[otto Revisio~ Jan 1990 L.R.,' "~t,~ ez Prod,, ~)n Manager Alaska Region Domestic Production Marathon Oil Company November 15, 1994 Mr. Blair Wondzell A.O.G.C.C. 3301 Porcupine Dr Anchorage, Ak. 99508. P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Dear Mr. Wondzell, This letter is intended to correct reporting discrepancies, for the gas production and gas injection wells, in the.Beaver Creek Field. The confusion centers around BC-1A. From 1974 to 1982 BC-1A was both an gas injection well and a gas producing well. To eliminate flaring Beaver Creek oil well formation gas, the gas was injected into BC- lA. Gas was also taken from BC-1A to supply lift gas and fuel gas to the Beaver Creek oil wells. State reports reflect the gas was injected into the Beluga formation (reservoir # 500). State reports should reflect gas injection into the Sterling formation (reservoir # 525). Below is a table summarizing gas production and gas injection thru 7/94 as you requested. Production Cumulative Well Formation Phase Start Last Water(BBL) Gas(MCF) BC-1A Beluga Production 1/89 Active 63,707 3,025,587 , ~ BC-1A Sterling Production 1/73 12/89 86,523 11,453,266 BC-2 Sterling Production 5/74 1/87 308 4,718 BC-3 Sterling Production 9/82 .10/88 199,351 19,108,1 67 BC-7 Sterling Production 11/82 7/93 162,950 41,647,224. BC-6 Sterling Production 9/82 3/94 57,493 51,564,301 ~ , BC-1A Sterling Injection 1/74 9/82 0 507,592 BC-6 Beluga Injection 9/82 10/83 0 43,464 If you need additional information please g~ve me a call at 564-6410. G~ cc: Marcus Allen Engineering Manager Mark Sinclair Operations Manager Roger Good Accounting Supervisor RECEIVED NOV 1 6 1994 A subs~~l~:~~.a~]J~missi0n , ~nnhnmn= Environmentally aware for the long run. Alaska i~ n DomestiC.. ,oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 11, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Beaver Creek Well BC-1A Dear Mr. Wondzell: Attached for your approval is the AOGCC "Report of Sundry Well Operations" for BC-1A. Should you have any questions regarding this application, please contact me or Mr. Ed Oberts at (907) 564-6436. L. C. Ibele Operations Engineering Supervisor LCI/EVO/cah Enclosure Gas Cons. commission Anchorage H:\wp\Sundry A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALAS~.~ OIL AND GAS CONSERVATION COMb,..,~ION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown ~ Stimulate ~ Plugging ~ Perforate__ "~-,~ Pull Tubing ~ Alter Casing __ Repair Well ~ Other ~ "~, 6. Datum elevation (DF or KB) 1. OperationS Performed: 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168 Anchorage, AK 99519 5. Type of Well: 19' GL feet 4. Location of well at surface 117' FSL, 1338' FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1003' FSL, 1966' FWL, Sec. 34-7N-10W-SM Development Exploratory Stratigraphic Service RECEIVED 12. Present well condition summary Total Depth: measured true vertical APR -8 1994 Alaska 0il & Gas Cons. Commiss~ Anchorage 10,296' feet Plugs (measured) 9,390' feet 7. Un' Propa na e 8. Well number BC-1A 9. Permit number/approval number 67-9 0. APl number 50- 133-20006-00 ~11. Field/Pool Beaver Creek Unit Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8,994' feet Junk (measured) 8,122' feet Length Size Cemented 526' 20" 1,000 sx 2,220' 13-3/8" 3,500 sx 5,130' 9-5/8" 1,800 sx 9,697' 7" 730 sx measured Sterling 5,488'- 5,520' MD Beluga 8,797' - 8,817' MD true vertical Beluga 8,956' - 8,976' MD Measured depth True vertical depth 526' 526' 2,220' 2,220' 5,130' 4,819' 9,697' 8,807' 5,117'- 5,143' TVD 7,931'- 7,950' TVD 8,085'- 8,104' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 EUE 8RD AB Mod Packers and SSSV (type and measured depth) Baker Pkrs: SC-1 w/SBE (~ 5421'; SC-1L w/Millout Ext. (~ 5634'; SC-1 Grvl PK ~ 8607'; 'D' Sump Pkr (~ 8984' Stimulation or r. eme,~t squeeze summa .ry. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data Oil, Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 1,481 37 0 500 Subsequent to operation 1,557 7 0 1,060 15. Attachments 116. I Copies of Log and Surveys run __ Daily Report of Well Operations ~ Oil__ 17. I hereby certi g d correct to the best of my knowledge I Signed .,'/'/' --~-.-~ Title Form lO-40~_,i~ev 06/15/88 ~ ' Status of well classification as: Gas X Suspended Service Operations Engineering Supervisor BEAVER CREEK WELL 1-A WORK SUMMARY TO PLUG BELUGA AND OPEN STERLING SELECTIVE WORK STARTED: 2/9/94 COMPLETED: 2/16/94 CURRENT STATUS: Sterling would not flow. Closed sliding sleeve and restored Beluga Zone production. WORK SUMMARY 1. S/I well. SITP stabilized at 1800 psi. 2. Set XX plug in nipple at 5678'. . Bled tubing pressure to 1100 psi, no build-up, plug holding. 4. Open XD sliding sleeve at 5,599'. · Attempted to flow Sterling Zone. Well immediately logged up, no flow to surface. Rigged up echo meter. Fluid level at 2,300', confirming sleeve open. 6. Closed sliding sleeve at 5,599'. 7. Retrieved XX plug from nipple at 5,678'. 8. Put Beluga Zone back on production. h:\wp\BCIAWORK APR -8 1994 oil & Gas cons, commission Anchorage Alaska jion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 7, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Beaver Creek Well BC-1A Dear Mr. Wondzell: Attached for your approval is the AOGCC "Application for Sundry Approvals" to shift the sliding sleeve on Well BC-1A to produce from the Sterling. L. C. Ibele Operations Engineering Supervisor LCl/EVO/cah Enclosure H:\wp\Sundry A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well__ Plugging__ Time extension Stimulate Change approv'"~d program Pull Tubing Variance P-"~rforate Oth"~' X 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168 Anchorage, AK 99519 4. Location of well at surface 117' FSL, 1338' FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1003' FSL, 1966' FWL, Sec. 34-7N-10W-SM 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED FEB - 8 1994 Alaska UII & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) 15° KB above GL feet 7. Unit or Property name Beaver Creek 8. Well number BC-IA 9. Permit number/approval number 67-9 10. APl number 50- 133-20006-0 11. Field/Pool Beaver Creek Unit 12. Present well condition summary Total Depth: measured true vertical Effective depth: meaSured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 10,296' 9,390' 8,994' 8,122' Length feet feet feet feet Plugs (measured) Junk (measured) ORIGI/VAL Size Cemented Measured depth True vertical depth 526' 2,220' 20" 1,000 SX 526' 13-3/8" 3,500 SX 2,220' 526' 2,220' 5,130' 9,697' 9-5/8" 1,800 SX 5,130' 4,819' 7" 730 SX 9,697' 8,807' Sterling 5,488'- 5,520' MD 5,117'- 5,143' TVD Beluga 8,797'- 8,817' MD 7,931'- 7,950' TVD Beluga 8,956'- 8,976' MD 8,085'- 8,104' TVD 13. Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 EUE 8RD AB Mod Packers and SSSV (type and measured depth) Baker Pkrs: SC-1 w/SBE ~ 5421'; SC-IL w/Millout Ext. @ 5634'; SC-1 Grvl PK ~ 8607'; 'D' Sump Pkr @ 8984' Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation February 9, 1994 If proposal was verbally approved Name of approver Date approved 15. Staffs of well classification as: Oil Gas X Service Suspended__ 7. I hereby certify that the foregoin_.g i;,s.~nd correct to the best of my knowledge. Signed ~"~7~~ Title Operations Engineering Supervisor .~_/' "L.." ~,' ' FOR COMMISSION USE ONLY Conditions of a~'proval: Notify Commission so representative may witness Date Plug integrity__ Mechanical Integrity Test Approved by order of the Commision Form 10-403 Rev 06/15/88 BOP Test__ Location clearance__ Subsequent form required 10- JApprova~ No~ f./t ,. 0 3 Original Signed By -- ~ ' '~'~ ~ VVI II IUI~UI I ~pproved Copy. Returned commissione~ Date ~.//.~'/? SUBMIT IN TRIPLICATE BEAVER CREEK 1-A Objective: To shift sliding sleeve to initiate Sterling production. 1) 2) 3) 4) 5) 6) RU slickline unit. PT lubricator to 3500 psi. S/I production. RIH w/ 2813" XX equalizing plug and set in X-nipple @ 8605'. POOH. RIH w/check set tool to verify plug is set properly. POOH. Bleed TP through production choke to 1200 psi. Monitor TP for 1 hr. to verify plug is holding. This TP will equalize w/Sterling reservoir pressure prior to opening the sliding sleeve. RIH w/BO shifting tool to XD sleeve @ 5599'. Shift sleeve open. POOH. RD slickline and open well to production. 2/7/94 TAM H:\WP\Sundry\BC1-A FE~ '" 8 1994 Gas Cons. Commission Anchorage MARATHON OIL COMPANY BEAVER CREEK FIELD WELL BC-1A CS_Q; 526' 2220' 5130' 9697' 500' 20', 94#, H-40 13-3/8', 61#, J-55 9-5/8', 43.5 & 40#, N-80 7', 26/29~, N-80/P-110 Boker Injection Nipple (3,0' ID), 5421' Otis 'X' NippLe (2.813' II)). 5455' Baker SC-1 Pkr w/SBE 5455'-5468' Seat ossy & Muteshoe 5476'-5536' 3tast Jts (3.5' heavy wad pipe 4.5' nl) 3.0' ID) 5599' Otis 'XD' Stidin9 SLeeve (2,813'ID) (Opens down). 5634'-5644' Baker SC-IL Pkr w/Mitlout Ext 5634'-5637' Baker S-22 Locator, SnapLatch & Sea[ assy. 8605' 8607' 8631' Otls X NippLe Baker $C-1 Grv[ Pk Pkr GP-12 SOSJ w/43,000# pin. 8634'-8784' 6 Its 2-7/8' BLank plpe w/weLd-on centralizers every 15'. 8784'-8894' 6 Jts 2-7/8' x 4-1/2' Dual Screen Prepack screen 0.012 gauge, 80/40 resin co~*ed send, weLd-on centratizers every 10'. 8894' Otls 'X' NippLe (8.313 ' Il)). 8895'-8974' 5 Jts 2-7/8' x 4-1/8' Dual Screen Prepack. 8974' D-ring Sub (1.9' ID). 8975'-8983' 8-7/8' 0.018 Q~uge wire wrapped TeLL-TaLe. 8983' Sn~p L~tch & Seat assy. 8984' Baker Model 'D' SuMp Pkr. Stuck Ret BP's 8 8994', 9001', and 9033'. TD @ 10,296' Att MeasureMents are RKB 4o top oF equip. (Correction, Tbs Meas to RKB -4.91'). 3-1/2' 9.3# L-80 EUE 8RD AB Mod Tb9 (2.992' ID). B-1 5300'-5310' B-2 5430'-5445' B-3 5488'-5520' B-3 5520'-5540' B-4 RECEIVED FEB - 8 1994 5655'-5675'AiB$ka Oil & Gas Cons. Commission Anchorage 3-1/2' 9.3# L-80 EUE 8RD AB Mod Tb9 (2.992' ID>. Undefined 8522'-8564' Reservoir ])arum= Stertlng-5000' Sub Sea BeLuga- 9000' Sub Se~ Undefined 8797'-8817' B-C 8956'-8976' I~ Undefined 9104'-9114' Revised By~ VHR/noF Reason, New CoMpLetion Assy. Previous Revislom :Dec 1988 BEAVER CREEK Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) -- Lubricator Manually Operated BOP Tree Cai) RECEIVED FEB - 8 1994 Alaska Oil & Gas Cons. Commission Anchorage Swab Valve 2" Wing Valve Master Valves 3-1/2' 500.0 psi Christmas Tree Seal Flange Marathon Oil Company Alask~ ,on Domestic ~,roduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 January 31, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Well Completion or Recompletion Report and Log" for Beaver Creek Well #lA. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, District Operations Engineer Attachment ~docs~ml\6.doc A subsidiary of USX Corporation RECEIVED Anch0ra~.' ' -, ~"'"' STATE OF ALASKA ~ ~ ALASKA ~IL AND GAS CONSERVATION COMMISSIOI~ t~ ~ ~ ~ 1~ ~ ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~. StatUs of Well Classification of Service Well : OIL ~ GAS~ SUSPENDED [] ABANDONED [] SERVICE [] '2. Name of Operator 7. Permit Number Marathon Oil Company 67-9 3. Address 8. APl Number P. 0. Box 190168 Anchorage, AK 99519 so- 133-20006-01 4. Location of well at surface 9. Unit or Lease Name 117' FSL, 1338' FEL, Sec, 33 7N-lOW-SM Beaver Creek At Top Producing Interval 10. Well Number 591' FSL, 46' FEL, Sec. 33 7N-lOW-SM BC- lA At Total Depth 11. Field and Pool 1003' FSL, 1966' FWL, Sec. 34 7N-lOW-SM 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Sterl i ng/Bel uga 15' KB above GLI A-028083 Gas Pools 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions . 3/13/67 6/13/67 12/30/89 N/A ,.,MS,I 1 '17. TotaIDepth(MD+TVD) ,8. Plug Back Depth (MD+TVD) ,9. DirectionalSurvey ! 20. Depth where SSSV set [ 21. Thickness of Permafrost 10,296' & 9390' 8994' & 8122' YESr'-] N~[-], None feetMD N/A · 22. Ty~,e Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... :0:: 94# H-40 O: 526: 26" i000 sx Class G .3-3/8" bl# J-55 O' ZZZU' tt~-b/]t~" ShOO sx glass G .N./,A. 9-b/t~" q~.b/qO# N-t~O O' 5,13U' [Z-1/q" it~UU sx Class G /" 26/29#N-~;O/P11L) O' 9,69/' 8-1/Z" 730 sx Class G N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) ;terling: B-3, 5488' - 5520' MD /5 SPF 3-1/2" 8,621' 5455'/563~' 5117' - 5143' TVD 2-7/8" 8,987' 8607'/8984" lel uga: 26. X~4~(~, CEMENT SQUEEZE, E'IYO~XXXX 797' - 8817' MD; 7931' - 7950' TVD /12 SPF DEPT.~NTERVALIMDI AMOUNT & KIND OF MATERIAL USED 1956' - 8976' MD; 8085' - 8104' TVD / 6 SPF Sterling E-l, 2, 3, & 4 5300 - 5675' & Beluga unidentified 8522 - 8564' - Sqz 408 sx Class "G" cmt w/ additives 27. PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.) 1/3/90 Flowing Gas Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO ./21/90 24 TESTPeR'OD ~ N/A 1130 166 N/A IN/A ... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.1000 , 0 24-HOUR RATE I~N/A 1130 166 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~:~.~ka.0il & Gas Cons. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOE(~Gic MARKERS ' FORMATION TESTS · · . , .. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each pha.~. Top of Sterlinc. 5423' 5064' Gas Zone (B-2 Sand) Top of Beluga 6306' 5365' 31. LIST OF ATTACHMENTS At%aCh #i, '~ummary of Daily Operations: Attach #£.. CUrrent t...,'ellbare F)iagra~,~. 32. I hereby certify that the foregoing is true and correct to the best of my'knowledge !~ District Opera'lions Engineer 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 °ther spaces on this form and in any attachmentS..· Item 16 and 24: If this well is completed for separate, production from more than one interval (multiple completion), so .state in item 16, and in item 24 show the producing' intervals for only the interval reported in item 27. Submit a separate form for each-additional .interval to be separately produced, showing the data pertinent to such interval. .. Item 21"Indicate whether from ground level (GL) or other elevation (QF, KB, etc.). Item 23: Attached supplemental records for this well shciuld show the details of any multiple stage cement- ing and the location of the cementing tool~ ., ...,;J.~:~,r r-lowing;: (Sas L.~tt Rc.~d P~.rn[-,., iqvdr;.;uli(:: r,un, ~'' '-p. ~.;~.,,Smersi::;,~r::,, ,~-~. ..... ~'~- iection,~;~ ~s' i r~i~r~ior',, ShUt-in, Other-exs!ain. item '~':" . * '-° indicate Attachment #1 Daily Well Operations Beaver Creek Well #lA Workover 11/13/89 Pull BPVs in long and short string, run 1.84" GR, locate top X nipple w/ X-line running tool, attempt several times to set slip stop unsuccessfully. RDFN. 11/14/89 Set G slip stop and perforate at 5548' WLM w/ Kinley perforator. Pull G-stop, RU and pump 100 bbls 9.6+ NaC1 down LS taking returns up short string, well dead, RU slickline, shift x sleeves and set XRX plugs. Set BPVs. SDFN. 11/15/89 Lay out pad liner and matting, spot rig sub-base, working on starter for generator. SDFN. 11/16/89 Remove tree and NU BOPE, spot equip, still working on rig motors. Will continue RU in a.m. 11/17/89 Cont RU, started rig motor, raised derrick, fired boiler, generators running, raising rig floor at 0600. Will inspect rig this a.m. 11/18/89 Mix 9.6# NaCl, change pipe rams, hammer up stack, prep for BOPE test. Accepted rig 0 19:30 11/17/89. 11/19/89 Completed NU, test blinds and choke manifold valves, actuated choke would not test. Released rig until better prepared, accepted rig, tested choke and check, attempt to MU landing jt to test Hydril, need to remove seal sleeves, begin nippling down stack to remove sleeves. 11/20/89 Complete BOP test, pull plugs in SSSV nipples. Cut LS @ 5375'. Attempt to pull pkr loose and attempt to kill well. 11/21/89 LD tbg hanger and landing jts. Circ. Perf SS 5300'-5301'. Circ. POOH LD dual 2-3/8" tbg string. Summary of Dai, ~ell Operations Beaver Creek Well #lA Page 2 11/22/89 Fin POOH w/ 2-3/8" dual pkr. Replace dual 2-3/8" pipe rams w/ 3-1/2" pipe rams. Test to 4000 psi. MU 2-3/8" overshot and RIH. PU 3-1/2" d.p. 11/23/89 P/U 3 1/2" dp & RIH. Engage fish at 5375'. Run freepoint. Tbg struck at 5615'. Cut fish at 5586'. Work tbg free. POOH. 11/24/89 POOH. L/D fish. P.U washpipe and RIH. Wash over fish 5586'-5741'. Circ. 11/25/89 Circ. POOH. L/D washpipe. P/U overshot. RIH. Engage fish at 5568'. POOH L/D fish and overshot. M/U PRT and RIH. 11/26/89 Mill on packer. Circ. up gas from below packer until dead. Continue milling parker. 11/27/89 Mill on packer. CBU. Monitor well - losing 5-6 bph. POOH 5 stds. Mix and spot bridgesal pill. POOH. L/D fishing BHA and fish. RU to test BOPE. 11/28/89 RU test BOPE. RD. RIH for cleanout. CBU @ 6012'. 11/29/89 RIH, PU 3-1/2" d.p. Tag fill @ 8522'. Wash to 8784'. Drill on junk at 8784'. Circ. POOH to check bit. 11/30/89 POOH. Recovered pkr debris in boot baskets. BHA. RIH. Ream tight spot 5356'-5361'. RIH. Tag fill @ 8782'. Mill on junk 8784'-8785'. 12/01/89 Mill on junk 8785'-8791'. Wash to 8843'. Attempt to work through junk. CBU. POOH. BHA. PU new mill. ' Summary of Dai',~ Well Operations Beaver Creek Well #lA Page 3 ~2/02/8~ RIH w/ mill. Wash 8843'-8999'. CBU. Losing 12 BPH. Spot HEC pill. I_os~ng 6 BPlq. Monitor well. Monitor well. Losing 2.3 BPH. Spot bridge-sal pill. Losses reduced to less than i BPH. POOH. BHA. RU E-line. RIH w/ CET/GR. 12/04/89 Run CET/GR 9003'-8300' and 5800'-5300'. Run gauge ring and junk basket to 8600' Set retainer on E-line La 8570' WLM. PU 2-7/8" tbg stinger and 7" p~r. RIH. Tag retainer La 8566' RO 85 bbls. Set pkr La 7833'. Held safety mtg. Establish inj rate La ~/4 bpm La 4500 psi. Mixing cmt 12/05/89 Mix cmt Spot 102 sx of cmt POOH 12 stds. Set pkr La 7083'. Squeezed 2 bbl (iO sx) into perfs. P~OH. Set pkr La 5591'. Establish inj rate into Sterling B-4 perfs of I bpm La 1400 psi. POOH. Set retainer La 5724' WLM. PU stinger and pkr and RIH. 12/06/89 RIH. Mix 117 sx Class "G" w/ additives. Lay a balanced plug. POOH. RO. Set pkr La 4255'. Squeeze to 1500 psi. Squeeze 2-1/4 bbl into perfs. POOH. Test BOPE. BHA. RIH. 12/07/89 RIH. WOC. Drld soft cmt 5109' to 5237' Drill hard cmt to 5333'. Test Sterling B-1 perfs 5300'-5310' to 1~00 psi, ok. Drill hard cmt to 5458'. Test Sterling B-2 perfs 5430'-5445'. Established inj rate I bpm @ 1400 psi. POOH. PU pkr. RIH. 12/08/89 RIH w/ pkr and tailpipe. Set pkr La 5327'. Mix and spot 81 sx "G" w/ additives. Squeeze 14 bbl of slurry into B-2 perfs. Final squeeze pressure = 1400 psi. POOH. BHA. RIH. WOO. 12/09/89 WOC. RIH. Drill cmt 5400'-5460'. Test Sterling B-2 squeeze perfs to 1470 psi, ok. Drill cmt to 5550'. Test Sterling B-3 perfs. Establish inj rate of 3/4 bpm La 1200 psi. POOH. PU retrievable pkr and RIH. Summary of Dai.~ Well Operations Beaver Creek Well #lA Page 4 12/10/89 RIH. Set pkr @ 5458'. Test Sterling B-3 perfs. Inject (a i bpm (a 1300 psi. Test backside to 1500 psi. Pressure dropped to 1300 psi. Squeeze B-3 perfs w/ 81 sx to 1700 psi. POOH to 5333'. WOC. Resqueeze B-2 perfs w/ 27 sx to 1550 psi. POOH. 12/11/89 POOH. WOC. BHA. RIH. WOC. RIH. Retest Sterling B-1 perfs to 1500 psi, ok. Drill cmt 5539'-5455'. Test Sterling B-2 perfs to 1500 psi, ok. Drlg cmt. 12/12/89 Drill cmt to 5554'. CBU. Test B-3 perfs to 1500 psi, ok. Drill cmt to 5721'. CBU. Test B-4 perfs to 1500 psi, ok. Drill ret @ 5721'. Tag cmt at 7997'. Drill cmt. 12/13/89 Drill cmt to 8565'. Test Upper Beluga perfs to 1500 psi, ok. Drill retainer [a 8565'. Well flowed. SI. SIDP = 0 psi. SICP = 200 psi. Circ out gas. 12/14/89 Circ gas out. RIH. CO fill 8992'-8996'. POOH. LD BHA. Test BOPs. 12/15/89 Test BOPE. BHA. RIH w/ 6" tapered mill and csg scraper. Tag fill at 8895'. Clean mud pits. 12/16/89 Clean pits and mix brine. CO fill 8910'-8942' Hit tight spot. Work thru tight spot to 8996'. Circ. Tag fill @ 8~93'. POOH. 12/17/89 POOH. SD 13-1/2 hrs due to volcanic ash fallout. Fin POOH. RU lubricator. RIH w/ perf guns. 12/18/89 RIH w/ perf guns and perf Beluga 8956'-8976' w/ 6 SPF and 8797'-8817' w/ 12 SPF. MU surge assembly and RIH. Set pkr @ 8620'. Open MFE tester valve and surge perfs w/ 1000 psi underbalance. RO. Had 11 bbl influx w/ small amount of gas. CBU. POOH. Summary of Dai,~ Well Operations Beaver Creek Well #lA Page 5 12/19/89 POOH LD surge assembly. RIH w/ tapered mill Wash 8953'-8993'. (Fili 8958'-8993'.) Circ and filter. POOH 5 ~tands. Establish inj rate of I bpm @ 500 psi. RIH. No fill. POOH. 12/20/89POOH. BHA. MU sump pkr. RIH. Set pkr @ 8984'. POOH. 12/21/89 PU gravel pack equipment and prepacked screen. RIH. Latch into sump pkr @ 8989'. Set SC-1 pkr at 8606'. RU and pump xylene. 12/22/89 Pickle d.p. w/ xylene and HCl. Mix and pump 25 bbl slurry (7.5 lbs sand/gel). RO 9 bbl slurry (est volume : 11 bbl) 37 sx gravel packed and placed. Test pack to 2000 psi, ok. POOH. 12/23/89 POOH. LD gravel pack tools. Test BOPE. RU to run tbg. MU seal assembly and 94 jts 3-1/2" 8rd ABM tbg. MU SC-1 pkr. RIH w/ assembly. Could not get past 5294' w/ pkr. POOH to inspect pkr. 12/24/89 POOH. Replace crossover. RIH w/ SC-1 pkr and tail pipe. Sting into lower pkr. Set SC-1 pkr @ 5636'. POOH. RIH w/ pkr plug. 12/25/89 RIH and set plug in pkr @ 5636'. Drop 3 sx sand down d.p. POOH 24 stds. SI for X-mas. 12/26/89 Start up rig after X-mas SD. POOH. PU DST/TCP assembly. RIH. 12/27/89 Fin RIH w/ DST/TCP assembly. Correlate guns w/ GR/CCL. Set pkr @ 5469'. Perf Sterling B-3 5488'-5520', 5 spf. Unload well. Test Sterling perfs @ 3.2 MMCFD, 1160 psi FTP, less than 10 BWPD. RO. POOH. 12/28/89 POOH. LD TCP/DST assembly. RIH. Retrieve pkr plug. POOH. MU SC-1 pkr, sliding sleeve, and blast jts. RIH. Summary of Dai,j Well Operations Beaver Creek Well #lA Page 6 12/29/89 RIH w/ upper pkr assembly. Set pkr. POOH. LD tbg. MU seal assembly c 9. 12/30/89 Fin RIH w/ 3-1/2" tbg. Sting into. pkr. Space out. Land tbg. Set "XR" plug in nipple @ 5421'. ND BOPE. NU tree. Test to 5000 psi. RELEASED RIG @ 0330 hrs. on 12/30/89. 12/31/89 Continue demobbing rig. 01/01/90 Unloading well to production. 01/02/90 Unloading well to production. 01/03/90 Unloading well to production. 01/04/90 Unloading well to production. o /o5/9o Unloading well to production. 01/06/90 Jetted to 2000' w/ CTU and N2. Unable to get well to flow. 01/08/90 01/09/90 SI. Prepping for acid job. 01/10/90 Acid job delayed due to -27°F ambient temperature. Summary of Dai.j Well Operations Beaver Creek Well #lA Page 7 Acid job delayed. 01/12/90 Acidized w/ 200 bbl, 7-1/24 HCI - 1-1/24 HF acid. Unloaded to 4000' w/ CTU and N2. Waitin9 on additional nitrogen. 01/13/90 Unload w/ CTU and ~ Well flowing Ia 8 bph. Estimated rate : 1 MMCFD. Total 01/15/90 15/90 load recovered : 650 bbl. 01/16/90 Presently unloading @ a rate of 7-1/2 bph w/ 425 psi FTP. Total load recovered = 831 bbls. 01/17/90 Presently unloading @ a rate of 7 bph w/ 500 psi FTP. Total load recovered = 998 bbls. 01/18/90 Presently unloading @ a rate of 7 bph w/ 725 psi FTP. Total load recovered : 1150 bbls. 01/19/90 Presently unloading [a a rate of 4-8 bph w/ 700 psi FTP. Total load recovered : 1296 bbls. 01/20/90 Presently producing 1,130 M6F, 166 B~PD, 1000 psi FTP. Final Report. \docskbc\bcla.doc Attachment #2 526' 2220' 5130' 9697' 500' MARATHON OiL COMPANY BEAVER CREEK FIELD WELL BC-IA 20', 94#, H-40 13-3/8; 61#, J-55 9-5/8', 43.5 & 40~, N-80 7', 26/29#, N-80/P-1IO Baker Injection N~ppie (3.0' ID). 5421' Otis 'X' Nipple (2.813' ID). 5455: Baker SC-I Pkr w/SBE 5455'-5468' Seal assy & Muleshoe 5476'-5536' Blast Jts (3.5' heavy wail pipe 4.5' OD 3.0' ID) 5599' Otis 'XD' Sliding Sleeve (;3.813'ID) (Opens down). 5634'-5644' Baker SC-IL Pkr w/Mittout Ext 5634'-5637' Baker S-22 Locator, Snap[arch & Semi ossy. 8605' 8607' 8631' Otis X Nipple Baker SC-1 Grvt Pk Pkr GP-12 SDSJ w/43,000# p~n. 8634'-8784' 6 J~cs 2-7/8' Blank pipe w/weld-on centralizers every 15'. 8784'-8894' 6 Jts 2-7/8' x 4-1/2' Du~i Screen Prepack screen 0.01;3 gauge, PO/40 resin coated sand, weJd-on centralizers every lO'. 8894' Dt~s 'X' Nipple (;3.313 ' ID). 8895'-8974' 5 J~s 8-7/8' x 4-1/8' Dual Screen Prepack. 8974' D-ring Sub (1,9' lO). 8975'-8983' P-7/8' 0.018 gauge' wire wrapped 8983' Snap Latch & Seal Qssy. 8984' Baker Model 'D' Sump Pkr. Stuck Re~ BP's 8 8994,, 9001; and 9033'. TD 8 10,296' ]OmOleted 12/30/89 = > I [] AH Measurements ore RKB to top oF equip. (Correct;on~ Tbg Me~S to RKB -4.910. 3-1/2' 9.3# L-80 EUE 8RD AB Mod Tbg (8.992' ID). B-I 5300'-5310' B-E 5430'-5445' B-3 5488'-5520' B-3 5520'-5540' B-4 5655'-5675' 3-1/2' 9.3~ L-BO EUE BED AB Mod Tbg (2.998' ID). Undefined 8588'-8564' Reservoir Datum~ Sterling-5000' Sub Sea BeJuga- 9000' Sub Sea Unde¢lnFd 8797'-8817' B-C 8956'-8976' UndeFined 9104'-9114' Revision Date, Jan 1990 Revised By, VHR/ne? Reason, New Completion Assy. Previous Rev;slam Dec 1988 Marathon Oil Company Alaska ~on Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 November 10, 1989 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton' Enclosed is the AOGCC "Report of Sundry Well Operations" for Beaver Creek Well #lA. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, ~orl ett District Operations Engineer Attachment \docs~ml\6 doc A subsidiary of USX Corporation ~ STATE OF ALASKA AL/-~KA OIL AND GAS CONSERVATION COMMISSION ~'~ R I G J J~J A [ REPOI OF'SUNDRY WELL OPEF TION$ 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing __ Alter casIng __ Repair well Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 995 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-IOW-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-lOW-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-lOW-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-TN-10W-SM Perforatem Recover Fish & Others Olean Out Fill ,, 6. Datum elevation (DF or KB) 15' KB Above GL feet 7. Unit or Property name Beaver Creek Unit 8. Well number BC lA 9. Permit number/approval number 9-810 lO. APl number 5o-133-20006-01 11. Field/Pool Beluila/Sterl inl] Gas Pool 12, Present well condition summary Total depth : measured 10,296' feet Plugs(measured) Stuck RET BP @ 8,994' true vertical 9,390' feet " @ 9,001 ' " @ 9,033' Effective depth: measured 8,994 ' feet Junk (measured) true vertical 8, 122 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 526' 20" 1,000 sx 526' 526' Surface 2,220' 13 3/8" 3,500 sx 2,220' 2,220' Intermediate 5,130' 9 5/8" 1,800 sx 5,130' 4,819' Production Liner 9,697' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling- B-3 5,488' - 5,520' MD 5,117' - 5,143' TVD trueverticBa~eluga- 8,522' -8,564' MD 7,667' - 7,707' TVD 8,797' -8,817' MD 7,931' - 7,950' TVD 8,956' - 8,976' MD 8,085' - 8,104' TVD Tubing (size. grade, and measured depth) LS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 8,431' MD SS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 5,350' MD Packers and SSSV (type and measured deptl{)t i s XX0 SSSV landing npl 1.875" ID @ SS = 525'; LS = 554' Otis WD 7", 29# Perm Pkr w/ SBE @ 5741', Otis RDH 7", 29# RET Dual Pkr ~_ 5__343' MD 13. Stimulation or cement squeeze summary ,i~EEVC I.ED Intervals treated (measured) .~NOV ~' o ]-,q~9 Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data - ... <,,,,i' ~richor3o~ :.,~--- ;'""? :": OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing PreSsuY~ ' SS LS SS LS SS LS Prior to well operation 9/19/89 S/I 0 0 240 340 2600 2900 Subsequent to operation 10/13/89 SI 0 0 0 15. Attachment~ I / 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations _X. Oil ~ Gas x Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~¢~~~ z~r~:~'~'~'~"'~¢;~ Title 0 500 500 Service District Operations Engineer Form ~--404 Rev 06/15/88 Date//-/~; SUBMIT IN DUPLICATE Attachment #1 Summary of Daily Operations Beaver Creek Well #lA 9/26 and 9/27/89 RU CTU BOPE and snubbing unit BOP's. Pump 1-5/8 bbl 3% KC1 and kill short string. PT snubbing unit BOPE and choke manifold to 4000 psi and CTU to 2700 psi. SIFN. 9/28/89 RIH w/ dressing mill and dress TOF. RIH w/ CT overshot and engage fish. Pull 22,000 lbs, parted fish, POOH. Recovered 13' of CT fish. 9/29- 10/5/89 Continue working over, cutting and pulling 1-1/4" CT fish. Recovered total of 1115' of CT fish. RD snubbing unit and remove CTU BOPs. RU snubbing unit. 10/6/89 PT BOPs. OK. Unsuccessful attempt to fish guide and control. RIH w/ 1" pipe and mill. Broke through bridge at 238'. Continue to 484~, pushing junk. POH. 10/7/89 RIH w/ 1" pipe and mill Tag bridges at 546', 549' 617' 648' 840' 984' RIH to 1191'. POH. 10/8/89 RIH w/ 1" pipe and mill. Wash to 1796'. Broke through bridge and RIH to 4229'. PU 3 jts and SD. 10/9/89 RIH to 8861' CBU PU to 5884' SD. 10/10/89 POH. Test flow Beluga. SI : 1900 psi. Well logged up several times and died. Daily Operatiori ~eport Beaver Creek Well lA Page 2 10/11/89 RIH w/ 1.70" GR. Tag bridges at 5328', 6744', 7055'. Unable to get deeper. (Appeared to be hanging up on fill at tubing collars.) POH. RIH w/ chisel bottom sample bailer. Obtain sample at 7055' (1/2 QT' muddy fluid w/ sand, coal, and shale). RD. 10/12/89 LS : 1650 psi. Bleed off to 0 psi. Pump 35 bbls, 9.6 ppg NaC1 water. P = 700 psi. Bleed off to 0 psi. Pump 23-1/4 bbls, 10.35 ppg CaCI^ water. P: 4000 psi. Bleed back 16-1/2 bbls water. P: 500 psi. SS = 75(~ psi. Bleed off SS and pump 20 bbls 10.35 ppg CaC12. P = 1500 psi. RD snubbing unit. 10/13/89 LS : 875 psi. SS : 875 psi. Bleed off LS and SS. LS : 0 psi. SS = 0 psi. Pump 3-1/2 bbls, 9.6 ppg NaC12 down. SS = 500 psi. Pump 4-1/2 bbls, 9.6 ppg NaC12 down LS. LS = 500 psi. Install BPV in SS and LS. Release snubbing unit. \docs\BC\BClA Marathon Oil Company ~.,-~. Alaska ion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 November 7, 1989 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well lA. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em~docs\ml\6 A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter Casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate )...~.( Other Z._Gravel 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-lOW-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-lOW-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-1\OW-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-lOW-SM 5. Type of Weil: Development Exploratory Stratigraphic 99 9 Service Recompletion & Pack feet 6. Datum elevation (DF or KB) 15' KB Above 6L 7. Unit or Property name Beaver Creek Unit 8. Well number BC lA 9. Permit number 67-9 10. APl number 50-- 133-20006-01 11. Field/Pool Beluga/Sterling Gas Pool 12. Present well condition summary Total depth: meas'ured true vertical Effective depth: 10,296' feet 9,390' feet Casing Structural measured 8,994' feet true vertical 8, ] 22 ' feet Length Size Plugs(meas c C E RE:T BP 8,994' @ 9,001' " @ 9,033' Junk (measured,~(")\; (.)~.~° ~r~,~tQ¢~:l ~,'~tska 0it & Gas Cons, Comraissio[~ Cemented : I~~¢epth True vertical depth Conductor Sudace Intermediate Production Liner 526' 2,220' 5,130' 9,697' 20" 1,000 SX 526' 526' 13 3/8" 3,500 SX 2,220' 2,220' 9 5/8" 1,800 sx 5,130' 4,819' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling- B-3 5,488' - 5,520' MD 5,117' - 5,143' TVD truevertic~eluga- 8,522' -8,564' MD 7,667' - 7,707' TVD 8,797' -8,817' MD 7,931' - 7,950' TVD 8,956' - 8,976' MD 8,085' - 8,104' TVD Tubing (size, grade, and measured depth) L$ = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 8,431' MD SS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 5,350' MD Packers and SSSV (type and measured depth~t i S XXO $SSV landing npl 1.875" ID @ SS = 525'; LS = 554' Otis WD 7", 29# Perm Pkr w/ SBE @ 5741'; Otis RDH 7"~ 29# RET Dual Pkr @ 5343' MD 13. Attachments 1 & 2 Description summary of proposal -X- Detailed operations program X.-. BOP sketch ~ &3 14. Estimated date for commencing operation November 13, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas x__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.~/~//CC'?/-c~ TitleDistrict Operations Engineer ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance' Subsequent form required 10- Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev O6/15/88 Original Signed l~Y Da,,id W. Johnston Commissioner SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek lA Workover Procedure Beluga Gravel Pack with Optional Sterling B-3 Production · 2. 3. 4. 5. 6. 7. 8. 9. Mob workover rig and equipment. PT BOPs. Pull LS and SS. Lay down pipe. Mill up LS packer and recover tail pipe. Cement squeeze the Upper Beluga, B-4, and B-3 sands. Drill out cement and retainers. Test squeezes. Cleanout fill to bottom. Perforate Lower Beluga sands. Clean out fill to bottom. Gravel pack Lower Beluga sands. 10. Run isolation packer -3000' 3-1/2" tubing. Stab into GP packer. 11. Set packer plug. Perf and test B-3. Recover packer plug. 12. Run packer, 3-1/2" isolation tubing, and sliding sleeve across B-3. 13. Run 3-1/2" tubing. 14. ND BOPs. NU tree and test. 15. Demob. Note' Maximum anticipated SBHP is 3650 psig. \docs\AFE\31.doc MARATHON OIL CFIMPANY ;BEAVER CREEK UNIT W~LL, ~CU-1A ~l~-~d Oo~: 3/13/67 APl ~: 50-133-~0006-01 D~'l~ln~! RKO, 15' ~bove GL Co~ple~lon Do~e~ t~/1t/~ T~ oP ~eebn9: 5300' MD M~x~um Hole An~ 3¢ 8 4458' Top oF Bel~, 8057' M9 Through S~eri~ 3~ ~nulu~ Flu~ 9,5 PPg 0~Cl2 Throug~ Beluga: ~ ~l ~ep~hs ~pe RKB ND ~o Re~erence L~ 9~L 4/19/67 ~ o~ equipment, ~V~RY S~or ~c S~crlng Veil Type, Producer New [] Wc~kover [] Reco~ple~ion [] DEPll-I A. FMC TC-60 Spill; Duo, I, H(~nger 15' D. 3' D-t:I~ Flow CpI!~ 519' C O'tis 'XXD' S$SV Lo, ndlng Nipple (1,875' ID) ]). 3' O't:l~ Flow Cpi9, 527' E, 8-3/8' 4,6# AB ~ But~ N-80 Tbg, 5350' F, O*l~ RDH 7; 29t~ Re~c. l]u~t Pkr, 5343' G, Crossover 8-;3/8' £UE 8RI) Box x 2-3/8' ]~u~ pin, 5350' FL O~is 'XN' L~ndln9 Nipple (Him 1,791' I])> 5351' Long SHcr~ng 1, 3~ Oi:lz Flow Cplg. 54-8' 2. O'tlS 'XXD' S$$V L~ncllng Nlppte (1,875' ID) 554' 3. O-~l~ Flow C43I. g. 5~' 4. E-3/~ 4,6~ AB ~ 9u~ N-~ ~ 84~' ~ E B~k~ Heavy ~tt ~s~ Jotn~s (~' Length) 541~ ~ O~is 'X' Ntppte ~,87~' ID> 57[8' ~ O~s V~ 7~ ~ Perm P~ ~/SBE, M~ttout Ex~ & XO 574)' O~ls ~{~e R~en~y guide. S<xncI Plug- ~ 560'1' OIL 2/8/89 B-I B-3 B-4 CASING & TUtIIN6 ~' 94~ H-~ 0 5~6' CS9 13-3/8' 6i~ ~55 0 ~EO' ' 9-5/8' 43.5~ N-~ 0 1400' 9-~/8' 40ff N-~ 1400' 5i~' 7~ ~6W N-~ 0 ~ 7' 8gfl P-$tO ~ 9697~ ~ Tb9 2-3/8' 4,6~ ~80 0 LS Tbs 8-3/8~ 4,6~ ~ 0 843~' PERFB~T]DN ~TA [n~e~v~[ Zo~ ~ ~ Da~e Gun ~te~n9 5~0'-53[~ B-$ 30' ~ Squeezed 54~*-~45~ 9-~ 35' ~ 54~-55E0' B-3 3~' 8 4-t/E' T~ 5~'-5675' B-~ ~ ~ Bel~ 8797'-8817' ' ~ 8 8~'-8976' ~ ~ 8 9~'-91~4' Un~eFl~ 10' ~ E-L~e 500' 5380' 5480~- 5600' AD Mod Bu't't AD Mod Bul:l; 8600' 6/30/67 1L/1~/88 1i/~6/08 1L/llY88 8900' 11/24/88 lt/~1/88 6/20/6? 899~' Flit togg~-d I~ 886[' (10/7/89> F~,-~ervolr Doi:La'~ S~e~[i~-5~' ~ Se~ Betugo- ~00' Sub ~ S~ck Re~ ~s ~ 89~' & 90~' Revision D~te, 10/t3/89 ~tuck Ret ~P E ~3~ Revised ~ NEF Reo~, T~gged Fill P~e~ous R~v~, 1~/~7/88 7' Csg 3-I/~"' [njec'tlon Por't 3-1/2' Tbg X Nppte B~ker SC-1L Re%rlevable Pkr 3-1/E~' Heo, vy W~lt Pipe 3-1/8' XP ~bdm9 Sleeve Baker SC-1L Retrievable I='kr X Nipple B~ker SC-1L Gr~vel P~ct< Pkr 4-1/~ Prepock Szzreen X Nipple B~ker Model 'O' Sump PEr,. Re~rlev~bte ~P MARATHON OIL COMPANY Proposed Compte~ion ~C-tA B-1 5300'-5310' B-~' ~f430'-5445' B-3 5488'-55c~' B-3 55~0'-5540' B-4 5655'-5675' UndeFined 8~--~'-8364' UndeFined 8797'-8817' B-C 8956'-8976' UndeFined 9~04'-9114' ') Attachment #3 ~ [~-~:RATHON'OIL COMPA~" BEAVER CREEK WELL NO.'I'A".' 13-5/8' 5000 psi BOP Assembly Mud Pan Flowline Drilling Nipple Rotating Head 0 0 Clamp Connector 0 U 13 5/8' x 5000~ ,.Annular Preventer (Hyd-ril) Clamp Connector Collar 13 3/8' Surf'c' c''ing ~8' __~ 30' Conductor Marathon Oil Company A~ on ~ o°"'e°"° ~r°c~u°'°'~} R i ~ ! N A [r RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 12, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupi ne Dr. Anchorage, AK 99501 Dear Mr. Chatterton Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #lA. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em\docs\m1\6 RECEIVF D SEP 1~ Anchorage A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate ~ Change approved program __ Pull tubing __ Variance ~ Perforate __ Other. 2. Name of Operator ~' I 5. Type of Well: Marathon 0i 1 Company i Development X_~ Exploratory __ 3. Address | Stratigraphic_ P. 0. Box 190168 Anchorage, AK 99519 Service__ 6. Datum elevation (DF or KB) 15' KB Above GL 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-lOW-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-lOW-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-lOW-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-lOW-SM 7. Unit or Property name Beaver Creek Unit 8. Well number BC lA feet 9. Permit number 67-9 10. APl number 5(1&3-20006-01 11. Field/Pool Beluga/Sterling Gas Pool 12. Present well condition summary Total depth: measured true vertical 10,296' feet 9,390' feet Effective depth: measured true vertical Casing Structural Length 8,994' feet 8,122' feet Size Plugs (measured) Junk (measured) Cemented Stuck RET BP @ 8,994' " @ 9,001' " ¢ 9,033' 1-1/4" Coiled Tubing O'- Measureoto~e~l~ (1 ong ~tCv~l~I depth Conductor Surface Intermediate Production Liner 526' 2,220' 5,130' 9,697' 13 9 20" 1,000 sx 526' 526' 3/8" 3,500 sx 2,220' 2,220' 5/8" 1,800 sx 5,130' 4,819' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling - true verti~l~l uga - B-3 5,488' - 8,522' - 8,797' - 8,956' - LS = 2-3/8", SS = 2-3/8", Tubing (size, grade, and measured depth) Packers and SSSV (type and measured deptf0t i S XX0 SSSV Otis WD 7'l 29# Perm Pkr w/ SBE 0 5741'; 13. Attachments 1, '2, Description summary of proposal X__ &3 5,520' MD 5,117' - 5,143' TVD 8,564' MD 7,667' - 7,707' TVD 8,817' MD 7,931' - 7,950' TVD 8,976' MD 8,085' - 8,104' TVD 4.6# AB Mod Butt N-80 Tbg to 8,431' MD 4.6# AB Mod Butt N-80 Tbg to 5,350' MD landing npl 1.875" ID @ SS = 525'; LS = 554' Otis RDH 7", 29# RET Dual Pkr @ 5343' MD Detailed operations program __ BOP sketch 15. Status of well classification as: ~ Oil__ Gas ~ Suspended,~P Service lt~a~t, 0il & Gas Cons. G0mmissi0[ 14. Estimated date for commencing operation September' :[8, :].989 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/Z~ ~ TitleDistrict Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Approval No. Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Wel 1 BC-iA BC-iA LS, Recover Fish/Clean Out Fill Note: Communication between long string and short string has been isolated by pumping plastic into the void area of x-mas tree. 1. Turn on methanol/pump (slow rate) while rigging up. Continue injecting methanol @ 554' during snubbing operations. 2. Shoot fluid level in short string and use pump and bleed method to kill short string Sterling zone w/ 34 KCl. Monitor pressure and fluid level throughout job. 3. RU Otis snubbing unit to long string. PT equipment to 4000 psi. 4. Dress top of fish externally. 5. RIH w/ packoff overshot on bottom of 1" CS hydril pipe, engage fish, check stretch and attempt to circulate. Make blind pull and pull fish free or separate coil tubing (804 yield of 1" 2.25# CS - Hydril is 42,780 lbs). (Yield of 1-1/4" coil tubing is 25,400 lbs.) 6. POH. L/D fish. If 1004 of fish not recovered, continue with blind pull method. 7. If blind pull method is deemed ineffective, RIH w/ washover spring dog shoe and 15' of washpipe. Engage fish and recover in 15' sections to 545'. Return to blind pull method w/ jarring assembly until 1004 recovery. 8. RIH w/ 1" CS hydril pipe w/ 1-11/16" mud motor and 1-3/4" cleanout mill and wash to 8431' (end of tubing). Circ until clean. Ensure well is dead. 9. Displace hole w/ 50 bbls 10.5 CaC12. 10. RD snubbing unit. NOTE: Maximum anticipated SBHP is 3630 psig. \docs\bc\bclA.doc RECEIVED $£P ! 31989 AlaSka 0il,& 6as Cons. t;ommissio Anchorage ' ~? ATT A C HIENT d~ 2- '~ BEAVER CREEK lA Coile-d Tubing Lubricator w/Associated BOPE Double BOP w/1 1/4" Rams 5000 psi WP See Attm~ment ~ 8 . *. Hydraulic Ram8 Tree Cap Swab Valve ./// 2" Wing Valve Master Valve8 I 5000 Christmas Tree RECEIVED SEP ! :~ 1989 Seal Flange Alaska Oil & Gas Cons. Gdmm'mior, Anchorage 'ATTACHMENT BEAVER CREEK lA Snubbing Unit BOP Stripping Ram See attachment Stripping Ram Pipe. Ram Blind Ram. · Shear Ram Pipe Ram Pump tn SubRECEIVED SEPI~lg~ Alaska Oil & Gas Cons~ Commis~on Anchom{le Marathon Oil Company Alas~ on Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 oRIGIN September 12, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" cancelling the approved Sundry Application for Beaver Creek Well lA approval #9-531. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment \docs\ml\6.doc RECEIVED SEP 1 )1989 Alaska 0il & Gas Cons. Gommissio.[~ Anchorage A subsidiary of USX Corporation /-,-,, ~ STATE OF ALASKA ^~KA OIL AND GAS CONSERVATION COMMISSION REPORT OFSUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing Alter casing u Repair well ~ 2. Name of Operator ! 5. Type of Well: Marathon 0il Company 3. Address P. 0. Box 190168 Anchorage, AK 995 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-lOW-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-TN-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-TN-1\0W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-TN-10W-SM Development Exploratory Stratigraphic Service Perforate ~ Other ~ Noti ce of Cancel 1. tti on 6. Datum elevation (DF or KB) 15' KB Above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC lA 9. Permit number/approval number 9-531 10. APl number 5o433-20006-01 11. Field/Pool' Beluga/Sterling Gas Pool feet 12. Present well condition sUmmary Total depth: measured 10,296 ' feet true vertical 9,390 ' feet Plugs (measured) Effective depth: measured 8,994 ' feet Junk (measured) true vertical 8,12 2 ' feet Casing Length Size Cemented Structural Stuck RET BP 0 8,994' " La 9,001' " La 9,033' 1-1/4" Coiled Tubing O'- Measure~ldelpStl~ (long strin.a). ~rue vertrca~ depth Conductor 526' 20" 1,000 sx 526' 526' Surface 2,220' 13 3/8" 3,500 sx 2,220' 2,220' Intermediate 5,130' 9 5/8" 1,800 sx 5,130' 4,819' Production Liner 9,697' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling - B-3 5,488' - 5,520' MD 5,117' - 5,143' TVD trueverticBa~luga- 8,522' -8,564' MD 7,667' - 7,707' TVD 8,797' - 8,817' MD 7,931' - 7,950' TVD 8,956' - 8,976' MD 8,085' - 8,104' TVD Tubing (size, grade, and measured depth) LS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 8,431' MD SS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 5,350' MD Packers and SSSV (type and measured deptl~t i s XX0 SSSV landing np! 1.875" ID La SS = 525'; LS D554' Otis WD 7", 29# Perm Pkr w/ SBE La 5741'; Otis RDH 7 , 29# RET Dual Pkr La 5.~_43.~ ~ 13. Stimulation or cement squeeze summary RECE Vt 14. Intervals treated (measured) Treatment description including volumes used and final pressure mi & Cons. Representative Daily Average Production or Injection I~'-' - OiI-Bbl Gas-Mcr Water*Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations __ Oil ~ Gas ~ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned /.~e~ ~ ~ Service District Operations Engineer Title Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Marathon Oil Company Alask~ ,ion Domest,u Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 9, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approval" for Beaver Creek Well BC-1A. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, 'K. Corlett District Operations Engineer Attachment em\docs\ml~6 R E C E I V E D JUN ! 9 ~_989 Alaska Oil & Gas Cons, Commission Anchorage A subsidiary of USX Corporation STATE OF AI.ASKA APPLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ~ Alter casing ~ Repair welt __ Change approved program __ 2. Name of Operator ! 5. Type of Well: Marathon Oi 1 Company l' DevelopmentX Exploratory __ 3. Address Stratigraphic w P. 0. Box 190168 Anchorage, AK 995 9 Service__ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension ~ Stimulate ~ Pull tubing __ Variance w Perforate __ Other 4. ~) $1~, ~,~J38 FEL, Sec. 33-7N-lOW-SM Locat'o f/w I t surf c , At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SN At effective depth 688' FSL, 37' FWL, Sec. 34-7N-lOW-SM Att°tll,d~t~' FSL, 1,966' FWL, Sec. 10,296' 9,390' 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 8,994' feet feet 8,122' RECEIVED 6. Datum elevation (DF or KB) 15' KB Above GL 7. Unit or Property name Beaver Creek Unit Casing 8. Well number BC lA 9. Permit number 67-9 10. APl number 5o]-33 - 20006-01 34-7N-IOW-SM JUN feet Plugs (measured) feet Alaska 0il & Gas Cons. C0mmis'~r011;;k (;J'lip RET BP @ 8, 994' @ 9,001' Anchorage ,, @ 9,033' J u n k (m easu red) 11. Field/Pool Beluga/Sterling Gas Pool Size Cemented Measured depth True vertical depth Structural feet Conductor Surface Intermediate Production Liner 526' 2,220' 5,130' 9,697' 13 9 20" 1,000 sx 526' 526' 3/8" 3,500 sx 2,220' 2,220' 5/8" 1,800 sx 5,130' 4,819' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling - true verticale 1 uga - 8-3' 5,488' - 5,520' MD 5,117' - 5,143' TVD 8,522' -8,564' MD 7,667' - 7,707' TVD 8,797' -8,8~7' MD 7,931' - 7,950' TVD 8,956' - 8,976' MD 8,085' - 8,104' TVD Tubing (size. grade, and measured depth) LS = 2-3/8", 4.6// AB Mod Butt N-80 Tbg to 8,431' MD SS = 2-3/8", 4.6/t AB Mod Butt N-80 Tbg to 5,350' ND Packers and SSSV (type and measured deptiOt i s XX0 SSSV 'landing np] 1.875" ID @ SS = 525'; LS = 554' Otis WD 7". 29# Perm Pkr w/ gRF fa B741'; nf.i~ [~n, 7" ~(~ DI:T r't,,.~l Obv, ia r.'3a'3, Mn 13. Attachments 1 & 2 Description summary of proposal X--. Deta~ed ~)-p~r,~tior~s I~r~)~ra~-. '__ .... BOIS'~ke{'ch"-~- ..... 14. Estimated date for commencing oPeration 115. Status of well classification as: June :[989 16; If proposal was verbally approved Oil ~ Gas ..z_ Suspended ~ Name of approver Date approved · ServiCe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. II signed ~--~'~' ~ !~'~' . ~g~L,~ FoRTitteCOMMISSIoNDistriCtusE0peratiOnSoNLY Engineer Date ~,/O~/~ ~ .. Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10. ~) 9' Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH .JApproval N o. ¢_,,~---~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment //1 Beaver Creek Well #lA LS Procedure 1. RU CTU, pumping equipment, and tanks. PT to 5000 psi. 2. RIH w/ CT. Circulate tubing clean. 3. RIH. Tag bottom. 4. Circulate out fill to 8994'. 5. POH to 2500'. Unload well w/ nitrogen @ 250 SCF/min. 6. POH. RD. Bring well on line. 7. Test well for 1-2 days monitoring production for signs of sand or coal production. 8. RU CT unit, pumping unit, and tanks. PT to 5000 psi. 9. SI well. RIH w/ CT. Tag bottom. 10. Pump acid/clay stabilization treatment. 11. POH w/ CT to 2500'. Unload well w/ nitrogen at 250 SCF/min. 12. POH. RD. Bring well on line. em\docs\BC\BClA RECEIVED UUN 19 t9 9 Alaska 011 & Gas Cons. Commission Anchorage Attachment #2 BEAVER CREEK Coiled Tubing Lubricator w/Associated BOPE Double BOP w/1 1/4' Rems 5000 psi WP _~.~ Tree Cap Swab Valve Hydraulic Rams ~ 2' Wing Valve Master Valves 4 1/2' 5000 Christmas Tree Seal Flange Marathon Oil Company Alaska ~ ,on Domestic Production Ott61~ ~"~ RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 April 28, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with appropriate attachments for Beaver Creek Well #lA. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml A subsidiary of USX Corporatio~n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OFSUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate m Plugging Pull tubing __ Alter casing __ Repair well __ Pedorate ~ Other 2. Name of Operator Marathon 0il Company 3, Address P. 0. Box ]90168 Anchorage, AK 995 5. Type of Well: Development X_ Exploratory __ Stratigraphic 9 Service __ Loca~o¢7ol w tsu c ~1~.,~, r~,§38, FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-lOW-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-lOW-SM Attoti¢8%t~' FSL, 1,966' FWL, Sec. 34-7N-10W-SM 6. Datum elevation (DF or KB) 15' KB Above GL 7. Unit or Property name Beaver Creek Unit i~cW~I,~number 9. Permit number/approval number 9-161 10. APl number 5o~3-20006-01 feet ,, 11. Field/Pool Beluga?Sterling Gas Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Length 10,296' feet 9,390' feet fe~ 8,994' feet 8,122' Size Plugs (measured) Junk (measured) Stuck RET B'P @ 8,994' " @ 9,001' " @ 9,033' Cemented Measured depth True vertical depth Conductor Surface Intermediate Production Liner 526' 2,220' 5,130' 9,697' 13 9 20" 1,000 sx 526' 526' 3/8" 3,500 sx 2,220' 2,220' 5/8" 1,800 sx 5,130' 4,819' 7" 730 sx 9,697' 8,807' Perforation depth: measured Sterling - true vertic~el uga - Tubing (size. grade, and measured depth) B-3 5,488' - 8,522' - 8,797' - 8,956' - LS = 2-3/8", SS = 2-3/8", Packers and SSSV (type and measured depth]Ot i S XX0 SSSV (lti~ WD 7"_ ?q# PPrm Pkr w/ .~RF 0 E741'' · 13. Stimulation or Cement squeeze summary 5,520' MD 5,117' - 5,143' TVD 8,564' MD 7,667' - 7,707' TVD 8,817' MD 7,931' - 7,950' TVD 8,976' MD 8,085' - 8,104' TVD 4.6# AB Mod Butt N-80 Tbg to 8,431' MD 4.6# AB Mod Butt N-80 Tbg to 5,350' MD landing npl 1.875" ID @ SS = 525'; LS = 554' Intervals treated (measured) Treatment description including volumes used and final pressure 14. MAY--.1 ],g~ ~aska Oil.& Gas Cons. Cemrn/s$i0F~ Representative Daily Average Production or Injection Data ' ~ ~mcl~0rage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachment~( 1 & 2 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil ~ Gas x Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service District Operations Engineer Title Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 BCU Well BC-1A Daily Summary of Operations 3/22/89 RU E-line and PT lubricator to 2650 psig, OK. RIH w/ pressure and temperature gauges. Correlate to TDT-P log and tag fill @ 8971~. Brought well on, stabilized @ 4100 MMCFD, 1700# TP and ran flowing gradient survey across lower Beluga making stops @ 8962~, 8807~, 8707~, 8607~, 8540~, and 8470~. FBHP @ 8962~ : 2448 psig. Ran temperature survey from PBTD @ 8971' - 8470'. SWI And POOH w/ logging tools MU 1-11/16" Silver jet strip gun, 6 SPF, 0v phasing. RIH, flow weli@ 500 MCFD to maintain a 500 psi drawdown, correlate to TDT-P log and perforate 8956~ to 8971~, POOH. Flow well @ 1746 MMCFD, 2500# TP. RIH w/ pressure and temperature gauges, stabilize well @ 4240 MMCFD, TP = 1750 psig and run gradient survey. Final rates = FTP @ tree = 2100 psig Rate = 4300 MMCFD FBHP : 2613 psig em\docs\bc~BClA Marathon Oil Company February 27, 1989 Alaska ,ion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approval" for reperforating Beaver Creek Well BC #lA. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 RECEIVED A subsidiary of USX Corporation STATE OF ALASKA ' AL, ,., JA OIL AND GAS CONSERVATION COMMI,., ~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casmg Repair well __ Change approved program __ Operation shutdown Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate x_.._ Other __ 2. Name of Operator ! 5. Type of Well: Marathon Oil Company ~ Development 3. Address Exploratory P. O. Box 190168 Anchorage, AK 9~519 StratigraphiC__service ! 4. Location of w_ell at surface 1 17' FSL, 1,338' FEL, Sec. 33-TN-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-10W-SM 6. Datum elevation (DF or KB) 15' KB Above GL 7. Unit Or prop~tY"n~me Beaver Creek Unit feet , , 8.~11 ~mber 9. Permit number 67-9 10. APl number 50--133-20006-01 11. Field/Pool. Beluga/Sterling Gas Pool 12. Present welt condition summary Total depth: measured true verdcal Effective depth: measured 8,994 ' feet Junk (measured) true vertical feet 8,122' 10,296' feet Plugs(measured) Stuck RET BP @ 8,994' 9,390' feet " @ 9,001' " @ 9,033' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Sudace 526' 20" 1,000 sx 526' 526' Intermediate 2,220' 13 3/8" 3,500 sx 2,220' 2,220' 5,i30' 9 5/8" 1,800 sx 5,130' 4,819' Production Liner 9,697' 7" 730 sx 9,697' 8,807' r rti~ : asured Sterling - B-3 5,488' - 5,520' MD 5,117' - 5,143' TVD i~¢~i~ ~..; ]~ ~ruevertical Beluga - 8,522' - 8,564"~ 7,667' - 7,707' TVD .... ~ 8,797' - 8,817' ~ 7,931' - 7,950' ~D ~S~~~:~~~~reddepth) 8,956' - 8,976' ~ 8,085' - 8,t04' ~ ~..~.:i~i~C~0~g~ :, LS 2-3/8" 4.69f AB Mod Butt N-80 Tbg to 8,431 ~ SS = 2-3/8", 4.6~ AB Mod Butt N-80 Tbg to 5,350' ~ Packers and SSSV (type and measu[ed depth) Otis ~O SSSV landing npl 1.875" ID ~ SS = 525'; LS = 554 Ot~m ~ 7" 29~ Perm Pkr w/ SBE M 5741'' Otis ~H 7" 29~/ RET Dual Pkr 9 5343' ~ 13. A~achmen~ 1 & 2 Description summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operation ~ 15. status of well classification as: March 1989 16. If proposal was verbally approved Oil __ Gas ~ Name of approver Date approved ServiCe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.~f~/~ Title District Operations Engineer FOR COMMISSION USE ONLY Suspended __ Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ 2-/~ d CoPY Mechanical Integrity Test__ Subsequent form required 10- ~ ' Agprove . ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Commissioner FOrm 10-403 Rev 06/15/88 lappr°val N°' Date ~ ---,,~- ~ SUBMIT IN TRIPLICATE ,,~ Attachment 1 Beaver Creek lA Long String Reperforate Deep Beluga Sand Procedure 1. RU E-line on long string. PT lubricator to 3000 psi. 2. Choke well to 2.5 MMCFD & RIH w/ MWP system w/ 1-11/i6" Enerjet strip carrier loaded w/ 4 SPF, 0° phasing. Run out of tubing tail @ 8,431'. 3. Increase rate to 5 MMCFD and allow well to stabilize. Obtain gradient survey from PBTD to 8470' to determine: 1) if perforations from 8956' to 8976' are producing gas, and 2) pressure/temperature gradient prior to perforating 4. Perforate from 8956' to 8970' w/ 3100 psi BHFP (500 psi drawdown) adjusting well rate to obtain proper underbalance. 5. Allow well to stabilize and obtain second gradient pass from PBTD to 8470'. 6. POOH, choke well back as necessary. RD E-line. Return to prior production rate. Monitor and record tubing pressure, gas rate, and water rate every 6 hours for 48 hours (well test data sheet). Maximum anticipated SBHP is 3630 psig. Alaska Oil & Gas Cons. commi~]o~t ~, ~mchomge Attachment #2 BEAVER CREEK~ 'Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) Lubricator Manually Operated BOP Long String Lower Valve R-24 ~ )2-380-( Short String Upper Valve I ~, Dual 2 1/16' Valvel 5k / ., FMC iwab L FMC aecond maater ! i I FMC · maater I 24-216-250 O~ 5k Flange R-54 STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION REPOFIT OF *SUNDRY WELL OPEFIATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging Pull tubing __ Alter casing m Repair well __ 2. Name of Operator [ 5. Type of Well: Marathon Oil Company ~ Development Exploratory Stratigraphic Service 3. Address ~ P. O. Box 190168 Anchorage, AK 9 519 4. Location of well at sudace 117' FSL, 1,338' FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-10W-SM Perforate __ Other x__ Recompletion 6. Datum elevation (DF or KB) 15' KB Above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC iA 9. Permit number/approval number 8-464 10. APl number 50--133-20006-01 11. Field/Pool feet Beluga/Sterling Gas Pool 12. Present well condition sUmmary Total depth : measured 10,296' feet Plugs(measured) Stuck RET.BP @ 8,994' true vertical 9,390' feet " @ 9,001' " @ 9,033' Effec!ive depth: measured 8,994 ' feet Junk (measured) true vertical 8,122 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 526' 20" 1,000 sx 526' 526' Surface 2,220' 13 3/8" 3,500 sx 2,220' 2,220' Intermediate 5,130 ' 9 5/8" 1,800 sx 5,130 ' 4,819 ' Production 9,697' 7" 730 sx 9,697' 8,807' Liner Perforation depth: measured Sterling - B-3 5,488' - 5,520' MD 5,117' - 5,143' TVD true vertical Beluga - 8,522' - 8,564' MD 7,667' - 7,707' TVD 8,797' - 8,817' MD 7,931' - 7,950' TVD 8,956' - 8,976' MD 8,085' - 8,104' TVD Tubing (size, grade, and measured depth) LS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 8,431' MD SS = 2-3/8", 4.6# AB Mod Butt N-80 Tbg to 5,350' MD Packers and SSSV (type and measured depth) Otis XXO SSSV landing npl 1.875" ID @ SS -- 525'; LS L554 Otis WD 7", 29# Perm Pkr w/ SBE @ 5741'; Otis RDH 7", 29# RET Dual Pkr @ 5343' 13' Stimulati°n'°rCement squeeze summary RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure ~l~b Oil & I~a.~ C~n,~. Cnmmi~ion 14.Representative Daily Average~ P~md, qtl~__'_t~__ ~jection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation SHUT-IN Sterling 18.67 346 0 890 Beluga 3010 2 0 2400 15. Attachment~ # 1 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__x Oil m Gas ___x Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~Z:, Signed ~/~cz/~~ Title District Operations Engineer Form 10-404 Rev 06/15/88 Date I/z7/~¢~' SUBMIT IN DUPLICATE Attachment #1 Daily Well Operations Report BCU Well #1-A Workover 11/05/88 Mobilizing Grace Rig # 158. Raise derrick. 11/06/88 Cont RU. Fill pits, repair leaks. Repair mixing pump. RU lubricator to pull BPV. Accept rig @ 0600 hrs 11/7/88. 11/07/88 Pull BPV. TP = 1000 psi. Yerf tbg @ 5077'-5079'. Circ out gas w/ 3% KC1. Perfs taking 15 BPH. M & P 20 BBL bridge sal pill. Still losing 10 BPH. M & P 29 BBL bridge sal pill. Set BPV. ND tree. NU BOPE. 11/08/88 Fin NU BOPE. NU flowline & choke line. Testing BOPE. 11/09/88 Test BOPE to 5000 psi, annular to 1500 psi. Release Baker FHL pkrs. POH. LD tbg & completion equip. Test kelly cocks & new manifold valves. Racking DP. 11/10/88 PU 6" bit, scraper, DCs & 3-1/2" DP. RIH. CO fill 5433'-5699'. Circ until clean. Set 20,000# on fill. POH. LD bit & scraper. MU 24 its 2-7/8" tbg tail & 7" pkr. RIH. 11/11/88 Cont RIH. Set pkr @ 4980' tail @ 5701'. Est inj rate of 1BPM @ 1000 psi. Release pkr. Mix & spot 90 sx (18-1/2 BBL) Class "G" w/ additives for bal plug. POH 8 stds. Reset pkr. Sqzd 5-1/2 BBL 26.8 sx into Sterling perfs, final press = 1750 psi. SI DP w/ 1750 psi for 8 hrs. Bled off press. POH. MU 6" bit. RIH to 4332'. WOC @ 0600. 11/12/88 WOC. RIH. Tag cmt @ 5314'. Drl cmt 5314'-5350' CBU. Press test old sqz perfs 5300'-5310' to 900 psi, OK. Drl cmt 5350'-~600'. CBU. Test sqzd B-2 Daily Well Op~ tions Report Beaver Creek iA Page 2 & B-3 perf(5430'-45' & 5490'-5540') to 500 psi, OK. POH. MU dry test assy. RIH filling DP for 1100 psi cushion. Set pkr @ 5365'. Dry test perfs 5300'-10', 5430'-45', 5490'-5540', OK. POH. 11/13/88 RIH w/ bit. Drl hard cmt 5660'-5700'. CBU. Press test sqz perfs to 500 psi, OK. Wt brine up to 9.5 ppg. Drl cmt & junk 5700'-5706'. CBU. POH. Lost 2 cones on bit. MU mill & boot baskets & RIH. 11/14/88 RIH w/ mill. Mill 5706'-5712'. POH. MU rolling dog OS. RIH. Mill over fish 5712'-5716'. POH. Recovered 2" of cable head, 1.5' CCL, 2.3' of 2-1/8" weight bar, 2 pieces of 3/4" stem, pieces of cone & tools. RIH w/ rolling dog OS. Work over fish 5716'-5726'. POH. 11/15/88 POH. Recovered 7.5' of retrieving tool & 2 pieces of 3/4" rod. PU bit & RIH. Drl & push junk 5725'-7096'. POH. Bit worn. RIH w/ new bit. Drl 7096'-7131. 11/16/88 Wash to 8400'. Cleaning mud pits. 11/17/88 Clean mud pits. Drl cmt to 8416'. Tag retainer. Test sqzd perfs to 500 psi, OK. Drl on retainer. POH. Test BOPE to 5000 psi. 11/18/88 RIH w/ bit #6. Drl retainer @ 8418'. Drl cmt to 8536'. RIH. Tag BP @ 8688'. Drl thru BP. CO to 9017'. POH. PU csg scraper. RIH. Clean mud pits. 11/19/88 Filter brine. POH. Running TDT-P log 9017'-5000'. 11/20/88 Fin running TDT-P. MU Baker TCP guns & pkr. Correlate guns w/ GR. RU T-Pak for testing. Perf'd Beluga sand 8797'-8817' & 8956'-8976'. Presently testing Beluga perfs @ 6.183 MMCFD @ 2400 psi TP on 24/64" choke. Daily Well Opt .tions Report Beaver Creek IA Page 3 11/21/88 Flow tested Beluga perfs @ a stabilized rate of 5 MMCFD, @ 2700 psi TP, 0 BWPD on 16/64" choke. SI @ 1554 hrs for 6 hrs PBU. Opened bypass in pkr. CBU. Released pkr & CBU. POH. Well started flowing w/ BHA in table. Stabbed FO safety valve. Check press = 170 psi. MU dart valve strip in 1 stand. Had gas blow around annular. Pressure = 50 psi. Prep to RIH. 11/22/88 Circ gas out. DPP = 0 psi, CP = 0 psi. RIH. CBU. Short trip 10 stds. POH to 4500'. CBU. POH. LD gauge carriers & TCP guns. RU E-line. Run CET. RD E-line. 11/23/88 Evaluate CET log, RIH w/ RBP & set @ 8700' - test to 500 psi - dump 3 sx sand on plug. POH. RIH w/ TCP/DST assy. RU E-line & correlate. Position guns & set Pkr @ 8489'. 11/24/88 RU & test surface lines to 5000 psi. Perfed 8522'-8564' DIL w/ 8SPF. Performed DST#2 - stabilized 5.6 MMCFD w/1420 psi FTP, 0 BWPD on 24/64" CK. SI for PBU. Backside taking ½ BPH. Reverse out. Release & RIH w/ UB valve to 8604'. CBU. POH. 11/25/88 POH. MU BP retreiving tool & RIH. Release RBP @ 8702' & CBU. POH to 8480'. Attempting to reset RBP. No success. RIH. Tag RBP @ 8717'. Would not move up w/ 40K. Pushed to 8747'. Attempt washing over & working. Moves down & not up. Max 70K over. Push to 9001' DPM. CBU. POH w/ retre±ving tool. RIH w/2nd RBP set @ 8480'. Drop 3 sx sand. POH. Set RTTS @ 5710'. Will locate leaking perfs. 11/26/88 Tested Sterling perfs w/ isolation packer. Found B-2 perfs leaking. POH. Test BOPE. MU TCP guns & RIH. Perfed B-3 5488'-5520'. Flow testing B-3 at 7.5 MMCFD, 1120 psi FTP, 5 BWPH. 11/27/88 Continued flow testing B-3 perfs at 8.3 MMCFD, 1110 psi FTP, 62 bwpd. for 4 hrs & 5.4 MMCFD, 1300 psi FTP, 51BWPD for 5 hrs. SI well for PBU. Released packer. CBU. Spot 30 bbl HEC pill at perfs. POH. Daily Well Op~ tions Report Beaver Creek IA Page 4 11/28/88 Fin POH. LD DST assembly all shots fired. MU RBP & retrievable pkr. RIH. Set RBP @ 5468' & set pkr @ 5458'. Test RBP to 500psi ok. Pull pkr to 5250'. Dump 3 sx sand on pkr. Tag sand @ 5456'. PU to 5444' set pkr. Test RBP to 2000psi ok. Reset pkr @ 5320'. Mix 100 sx class "G" w/additives & spot at pkr. Squeeze 8bbl below pkr when communication developed to annulus. RO 19 bbl cmt. POH. MU bit & BHA & RIH. Wash 5140'-5454'. CBU. POH. 11/29/88 PU pkr & stinger & RIH. Set pkr @ 4725'. Attempt to establish injection rate. Test perfs to 2100 psi. POH. MU Dry test tools. RIH. Dry test Sterling B-1 & B-2 perfs. No leaks, POH. RIH Release RBP @ 5468' & reset at 5145' test RBP to 1000 psi OK. N/D BOPE to change out tbg spool. 11/30/88 N/D BOP. Replace tbg spool for dual tree. N/U BOP. Test BOP to 5000 psi. RIH w/RBP retrieving head. Release RBP @ 5145' Circ gas cut brine. POH. 12/1/88 POH w/RBP. RIH w/RBP retrieving head. Circ. & raise brine wt. Release RBP @ 8469'. RIH to 8990' and circ. gas cut brine out. POH slowly. RBP hung up @ 8702'. Attempt to free RBP. Release running tool POH. PU bit, scraper, jars & 12 DC's. RIH. Engage RBP. Bump down & release RBP. Unable to work RBP up. RIH to 8994', set RBP. POH. 12/2/88 POH w/RBP running tool. LD fishing tools. PU 2660' of 2-3/8", 4.6#, N-80, ABM tbg Otis "WD" permanent pkr. RIH set pkr @ 5740' DPM. CBU. POH with DP. LD DP. 12/3/88 Fin LD 3-1/2" DP. RU to run dual 2-3/8" tbg. MU tbg hanger & set in tbg spool. Unable to get pressure test on dual rams. Ram blocks out of spec. Order new set of blocks. P.U. & RIH w/3-1/2" DP to CBU. 12/4/88 RIH w/ DP. Tag pkr at 5740'. CBU. POH. Installed 2-3/8" dual rams. Unable to test. Remove 2-3/8" dual rams. RIH. Presently circulating. 12/5/88 Circulate hole clean. POH, LD DP. Install & test 2-3/8" dual rams. MU seal assembly, carbide blast joints. Run completion assembly. Daily Well Opt tions Report Beaver Creek iA Page 5 12/o6/88 Competed running 2-3/8" dual completion. Tagged packer, spaced out. Made up tbg hanger & controls. Land hanger & started displacing inhibitor to annulus. 12/07/88 Fin displacing inhibitor. Set pkr @ 5343'. Tested csg & hanger to 2200 psi. Set profile plugs in both strings. Set BPV's. ND BOP. NU xmas tree. No test on tree. Changed O ring in hanger to teflon ring. Test OK. Cleaning mud pits. 12/08/88 Fin cleaning mud pits & RD rental equipment. RELEASED RIG @ 1200 hrs 12/8/88. FINAL REPORT. em/47A/BC Marathon Oil Company Alaska .~ion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 January 18, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" and the "Well Completion or Recompletion Report and Log" with appropriate attachments for Beaver Creek Well #lA. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml RECEIVED Alaska 0il & Gas Cons. Commission A subsidiary of USX Corporation STATE OF ALASKA. ~'% Page 1 of 2 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [~] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name Of Operator 7. Permit Number Marathon Oil Company 67-9 3. Address 8. APl Number P. O. Box 190168 Anchorage, AK 99519 50- 133-20006-01 4. Location of well at surface 9. Unit or Lease Name 117' FSL, 1338' FEL, Sec. 33 7N-10W-SM Beaver Creek At Top Producing Interval ~ 10. Well Number 591' FSL, 46' FEL, Sec. 33 7N-10W-SM BC- lA At Total Depth 11. Field and Pool 1003' FSi,, 1966' ~-~, Sec, 34 7N-10W-SM 5, Elevation in feet (indicate KB, DFi etc.) I 6. Lease Designation and Serial No. Sterling/Beluga 15' KB above GLI A-028083 Gas Sands 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.' Susp. orAband. 115. Water Depth, ifoffshore 116. N°.°fC°mpleti°ns 3/13/67 6/13/67 . . 12/8/88 N/A feetMSL 2 17. TOtal Depth (MD+TvD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10,296' & 9390' 8994' & 8122''YEs[] NOI~]I 525' & 55~eetMD N/A . 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20;; ~4# u-40 0:'' ~z6: ~ 26:: i0uu sx class G N/A 13-3/8" 61# J-55 O' 2220' 18-5/8" 3500 sx Class G N/A 9-5/8*' ~3.5/40# N-80 O' 5,130' 12-1/4" 1800 sx Class G " N/A 7" 26/29#N-80/Pl10 O' 9,697' 8-1/2" 730 sx ClaSs G N/A 24. Perforations open to'Production (MD+TvD o.f Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Sterling B-3, 5488' - 5520' MD "SS-2-3/8" 5,350* 5,343' 5117' - 5143' TVD LS 2-3/8" 8,431' 5,741' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Beluga 8522' - 8564' MD; 7677' - 7707' 3:VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8797' -8817' MD; 7931' - 7950' TVD 8956' - 8976' MD; 8085' - 8104' TVD 5430'- 5675' 5.5 bbls Class G cement Ail intervals were perforated 4-1/2" TCP guns,5320' - 5468' 8 bbls class G cement with 8 HPF. , 27. PRODUCTION TEST Sterling Gas Sands · Date First Production I Method of Operation (FloWing, gas lift, etc.) ......... 12/20/88I Flowing .Gas Well Date of Test ' Hours Tested PRODUCTION FOR OI L-BBL ' ]'GAS-MCF wATER-BBL CHOKE SIZE I GAS-OiL RATIO 12/27/88 24 TEST PERIOD ~ N/A 1867 346 N/AI N/A Flow Tubing Casing Pressure CAL~CULATED oiL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pre~s. 890 0 24-HOUR RATE ~ N/A 1867 346 N/A .. 28. CORE DATA Br ef description of lithology, porosity, fractures, apparent dips and preSence of oil, gas or water Submit core chips. RECEIVED Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30~ GEOLOGIC MARKERS FORMATION TESTS .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP of Sterling B 5423' 4911' TOP of Beluga 6385' 5700' TOP of Lower Beluga 8057 ' 7082 ' 31. LIST OF ATTACHMENTS Attachment ¥~1 - Current Wellbore Diagram 32. I hereby certify that the foregoing is true and correct to the best of my.knowledge ?~L~ - District Signed " Title' Operations Engine6art;" . INST. RUCTIONS ~, ..' General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ~. .. , . .item 1' Classification of Service Wells: Gas injection, water injectiOn, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation-is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. . . Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion),-so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be.separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground-level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- cernerJ~ ng tool. ing and the IocatiO~ o~'~h~ ~'' ~' "~' l't. er:-~ 28' ['f no cores taken~, in(~cste "note", Pase 2 of 2 I~CeM ~27 Beluga Gas Sand 87 PRODUCTION TEST ])~e Firs~c Produc~clon 1/13/89 D~ce o~ Tes~c / Hours Tes~ced 1/16/89 [ 11 Ftow Tui01ng Co. slnO Pressure Press. ~ ~ 0 0 0 Me%hod o~ Oper=~lon (Flowin.~ gas IIF%, e~c.) Flowing Gas Well JPRODUCTION FOR TEST PERIOD CALCULATED 84-HOUR RATE OlL-BBL NA OlL-BBL NA GAS-MCF 1380 GAS-MCF 3010 ~ATER-BBL 2 WATER-BBL 4 CHOKE SIZE ~GAS-nIL RATIO NA[ NA 0IL GRAVITY-API (tort) NA WELL, BCU-I~ MARATHrlN OIL COI4PANY BEAVER CREEK UNIT Spud D~te, 3/13/67 API #, 50-133-80006-01 Well Type, Flrlglnal RKB, 15' above GL Completlon D~te, 12/11/88 Top of Sl;erllng, 5300' MD : M~xlmum Hole Angle, 39' 8 4458' MD New Top of Beluga, 8057' MD Through S'terllng, 35' Workover Annulus Fluid, 9.5 ppg CaClp Through Beluga, 19' Recompletlon ReFerence Log, DIL 4/19/67 All depths are RKB MD to top o¢ equlpmen~c. 18 B-1 F B-8 B-3 B-4 JEWELRY Short String A. FHC TC-60 Spilt Du~l H~nger B. 3' Dtls Flow Cpig. C. Dtls 'XXO' SSSV Landing Nipple (1.875" ID) Il. 3' Dt~s Flow Cpig. E. 2-3/8' 4.6~ AB Mod Butt N-80 Tbg, F. Dtls RILH 7', 89# Ret, Du~l Pkr. G, Crossover 2-3/8' EUE 8Ril Box x 2-3/8' Butt pin, H. l]tJs 'XN' Landing Nipple (MIn, 1.791' ID) Long S~rlng 1, 3' Dtls Flow Cpig. P. Dtls 'XXD' SSSV Landing Nipple (1.875' ID) 3, a~cls Flow Cplg. 4, 2-3/8' 4.6# AB Mod Bu~t N-BO Tbg. 5. 2 Baker Heavy W~ll Bl~s~c Joints (40' length) 6, C~rblde Bi.st Joint Rings (71' length) 7, 2 B~ker Heavy Wall Bl~st Joints (40' length> 8, D~s 'X' N~pp~e (1.875' ID) 9. O~ls Str~lgh~ Slot Lock,or Se~ls & Mule Shoe Guide lO. Dtls WD 7', 29~ Perm PEr w/SBE, MllJou~ Ex~ ~ XD (3-~/8' EUE BRD x 8-3/8' ~u~) 1~, D~Is WlreJlne Re-en~ry guide. CASING & TUBING Size WRight Grqde 80' 94# H-40 13-3/8' 61# J-55 9-5/8' 43.5# N-80 9-5/8' 40# N-80 7' 26# N-BO 7' 29~ P-110 SS Tbg 8-3/8' 4,6# N-BO LS Tbg 2-3/8' 4,6# N-BO PERFORATION DATA. interval Zone S~cerllng 5300'-5310' B-1 5430'-5445' B-2 5488'-5580' B-3 5520'-5540' B-3 5655'-5675' B-4 Beluga 8522'-8564' UndeFined 8797'-8817' ' 8956'-8976' B-C 9104'-9114' Undefined B-C Stuck Ret BP's @ 8994' & 9001' Stuck Ret BP 8 9033' TD @ 10.296' Gas Producer DEPTH 15' 519' 585' 587' 5350' 5343' 5350' 5351' 548' 554' 557' 8431' 5410' 5474' 5640' 5718' 5741' 5741' 5770' 8431' 0 5350' AB Mod Butt ToE Bottom DescrlplL 0 586' Csg 0 8220' 0 1400' 1400' 5130' 0 ' 9697' ' O 8431' AB Mod Butt FT SPE Da~e Gun Type 10' 2 6/30/67 Squeezed 15' 2 11/18/88 " 32' 8 11/26/88 4-1/2' TCP 19' 2 11/11/88 Squeezed 80' 2 11/11/88 42' 8 11/24/88 4-1/2' TCP 20' 8 11/81/88 ' 20' 8 11/21/88 10' 2 6/80/67 E-Line Reservoir Datum, S~eri~ng-5000' Sub Se~ Beluga- 9000' Sub Sea Revision Date, 'i8/27/88 Revised By, NEF Reason, RecoMpletlon Previous Revlslom 9/15/87 STATE OF ALASKA -'"' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: AbandOn [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing I~ Amend order [] Perforate [~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Marathon OiI Company 153' KB feet 3. Address 6. Unit or Property name P. O. Box 190168 Anchorage, AK 99519 Beaver Creek Unit 7. W~l~ n~ber 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' PSL, 37' FWL, Sec. 34-7N-t0W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-10W-SM 8. Permit number 67-9 9. APInumber 50-- 133-20006-01 10. Po~er[±n[ ~as Yoo[/ Beluga Gas Pool 11. Present well condition summary Total depth: measured true vertical 10,296' feet 9,390' feet Effective depth: measured 5,718' feet true vertical 5,306 ' feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural 9,617' - 10,296' (cement) 8,689' (Magnesium BP) 8,417' (Cement Retainl 5,718' - 5,720' (Cement & ] 9,023' - 9,033' (Stuck RB] 5,703' Measured depth Conductor Surface 526' 20" 1,000 sx Intermediate 2,212' 13 3/8" 3,500 sx Production 5,099' 9 5/8" 1,800 sx Liner 9,697' 7" 730 sx Perforation depth: measured ~£C£1I/ED ~,~o, B-3 5,490' true verticaIjUtv 2 J .19~'~ B-4 5,655' A/as_ka ~ Tubing (size, grade and measu[~, &:lG~.tC~0n$. 3 1/2" N-80 @ 5,386' AnChorage Packers and SSSV (type and measured depth) Baker FHL Packer @ 5,096', Baker FHL Packer @ 5,348' - 5,445' MD - 5,540' MD - 5,675' MD 526' 2,212' 5,099' 9,697' r) (BP Setting Too~s) True Vertical depth | / 526' 2,212' 4,793' 8,807' 5,070' - 5,082' TVD 5,119' - 5,160' TVD 5,254' - 5,270' TVD 12.Attachments 1,2,&3 Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1988 14. If proposal was verbally approved Name of approver FOi, al ~~~_~-¢./~, Date approved 15. I hereby( certify that the foregoing is true and correct to the best of my knowledge ORIGINAL SIGNED BY LONNIE C. SMITH Commission Use Only Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance &pproved Copy Returned Conditions of approval Commissioner Approved by Form 10-403 Rev 12-1-85 Date I Approva' No. ~_. -~ ~ ~/ the commission Date ~:2 "//~'' Submit in triplicate Attachment # 1 Beaver Creek iA Recomplete to Dual Beluga/Sterling Gas Well Workover Procedure 1. MIRU workover rig. Bullhead filtered 3% KC1 water down tubing. RU WL and shift open sleeve at 5060'. Circulate well dead. Install BPV, ND tree, NU BOPE and test. 2. Release Baker FHL packers at 5096' and 5348' and POH. LD 3-1/2" tubing. 3. PU DP and cleanout to 5700'. 4. RIH w/retrievable cementer and 20 joints 2-3/8" tubing tail. Lay balanced cement plug from 5700' to 5300' PU 10 stands (20 joints), set packer and squeeze. WOC. 5. Cleanout and pressure test squeezed perfs. Resqueeze, if necessary. 6. Increase WO fluid weight to 9.5 ppg. Cleanout to 9020' with mill-tooth bit and junk basket, making 2 trips, if necessary. Note: Pressure test squeezed perfs at 8526' - 8561' prior to drilling out BP at 8689'. Resqueeze, if necessary. 7. RU WL and log from PBTD to 5000' w/PDK-100. 8. RIH w/TCP/DST assembly· Correlate to perforate Beluga intervals 8797' to 8817' and 8956' to 8976'. Set packer and perforate w/800 psi underbalance. (Beluga reservoir pressure is 3865 psi.) Flow well for clean-up and obtain PBU. ~EC~/I~ 9. Reverse well dead· POH. Set SB packers at ±8500' and 86 . plug in top packer and test·Alo~.L 'J[J~! ~ ~8 · Correlate to perforate'§~%~l~~ Sands 10. RIH w/TCP/DST assembly Perforate w/300 psi underbalance~g-~°~e~'~$fO~~~ according to PDK-100. for clean-up and obtain PBU. 11. Reverse well dead and POH. RIH and CBU. Retrieve packer plug. RU WL and RIH to PBTD w/sinker bars and CCL. RD WL. 12. RIH w/dual 2-3/8" tubing strings. Circulate inhibited water down long string. Land tubing and set dual packer at ±5350'. Test dual packer and 7" casing. Set BPV's, ND BOPE, NU tree. Release rig. 13. Hook up flowlines. RU WL. Remove BPV's and open sleeves on SSSV's. Unload both strings w/CTU and N2. 14. Produce both Buluga and Sterling Sands for clean up and perform deliverability tests. PMO/em/47/Sundry At tachme~t #2 BEAVER CREEK WELL -~IA 526' 2212' 5099' 5416' Top of 20-40 sand/barite -~ ~/5' cement cap at 5,495' DIL Top of Yish @ Top of Cement @ Thru tub~g bridge plug @ 5720' Cleaned out to 6339' 8023' 8417' 8689' 9023' 9033' 9617' 9697' ]0,296' Current Comoletion ,L~--.. 20". 94~ H-40 ! ~ 578 Otis XL nipple (2.75" ID) Methanol f~jection point 13-3/8", 61~, 9-5/8", 40 & 43.5~, N-80 3-1/2", 9.2#, N-80, AB modified buttress 5060 Otis XA sliding sleeve (2.75" ID) 5096 Baker FHL~Packer (3-1/2" Butt p x b) Peri 5300'-5310', sqz w/ 125 sx 5348 Baker FML Packer (3-1/2" butt p x b) 5386 Baker shear sub w/ 1.~ guide (3.00" · Top of Sterling Gas Sands B-2 Peris, 5430'-5445', 2 HPF · -3 Peris, 5490'-5540'. 2 ~F B~-.4 Peris, 5655'-5675', 2'H~F 7", 26 & 29~, N-80 & P-110 Cement Retainer Peris, 8526'-8561', sqz w/ 100 sx Hagnesium BP Perfs, 8797'-8817' Perfs, 8956'-8976' Stuck retrievable BP Perfs, 9104'-9114' Proposed Completion AFE 8125-8 ~Dual 2-3/8" Tubing Strings Peris, 5300' - 5310', sqz w/125 sx Dual Hydraulic Packer @ !5350' SterlinR Perforations: B-2 Peris, 5430' - 5445' (sqz'd) B-3 Perfs~ 5490' - 5540' (sqz'd) B-4 Peris, 5655' -.5675' (Reperfed) sealbore Packer at i8,500' Peris, 8526' - 8561', sqz w/lO0 sx Sealbore Packer @ ~8600' Beluga B-C Perforations: 8797' - 881{'-(Reperf) 8956' - 8976' (Reperf) ,,,ARATHON OIL COMPAr~Y BEAVER CREEK WELL NO. 1 13-5/8' '5000 psi BOP Assembly i Mud Flowllne Drilling Nipple Rotltlng Held · · 0 Clamp Connector 0 13 yAnnullr . . 5/8' x 5000d~ Preventer (Hydrll) 0 .Clamp Connector. 0 3' x 5000d~' Kill Line L_~ (Blind 13 3/8' Double-Olte-CIW , 3' x 5000d~ Choke Line I " I Collar '. ~_13 3/8' Surf'c' C'''ng 28' 30' Conductor -~~ 1.2' x 300'Od~ Cleing Heed ' w/Flanged Outletl & Velvel · "~" STATE OF ALASKA ,--'"~ ALAS/ OIL AND GAS CONSERVATION COMI :~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other k-I 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 153' KB 3. Address 6. Unit or Property name P. O. Box 102380 Anchorage, AK 99510 Beaver Creek Unit 7. Well number BC iA 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-10W'SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-10W-SM 8. Approval number 449 9. APl number 50-- 133-20006-01 10. Pool Sterling 11. Present well condition, summary Total depth: measured true vertical 10,296 ' feet Plugs (measured) 9,390' feet Effective depth: measured 5,718' feet Junk (measured) true vertical 5,306' feet Casing Length Size Cemented Structural Conductor Surface 526' 20" 1,000 sx Intermediate 2,212' 13 3/8" 3,500 sx Production 5,099' 9 5/8" 1,800 sx Liner 9,697' 7" 730 sx Perforation depth: B-2 5,430' - 5,445' MD B-3 5,490' - 5,540' MD B-4 5,655' - 5,675' MD 9,617' 8,689' 8,417' 5,718' 9,023' 5,703' Measured depth - 10,296' (cement) (Magnesium BP) (Cement Retain - 5,720' (Cement & - 9,033' (Stuck RB (BP Setting Tool ~ue Vertical depth 526' 2,212' 5,099' 9,697' 5,070' 5,119' 5,254' - 5,082' TVD - 5,160' TVD - 5,270' TVD 526' 2,212' 4,793' 8,807' Tubing(size, grade and measured depth) 3 1/2" N-80 @ 5,386' Packers and SSSV(type and measured depth) Baker FHL Packer @ 5,096', Baker FHL Packer @ 5,348' 12. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment #1 RECEIVED OCT 2 4 1986 Alaska 011 & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 9/13/86 6,585 280 605 psig Subsequent to operation 10/20/86 2,870 66 800 psig ~bing Pressure 1,300 psig 1,315 psig 14. Attachments~ #1 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title District Operations Engineer Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment #1 Beaver Creek Well #1-A Water Shut-off October 12, 1986 . 1. RU coiled tbg and pump truCk. Pressure tested lines to 3,000 psi. 2. Pumped 45 bbls 3% KCL water while RIH'w/coiled tbg. Tagged @ 5,555' and pumped 45 bbls 3% KCL water. Well dead, POH w/coiled tbg. 3. RU wireline company. Tagged @ 5,555' DIL, Dump 10.0 gal. neat cement 5,545' - 5,555'~DIL. 4. Shut dOwn. WOC for 24 hours. Well shut-in. October 14,-1986 1. RU coiled tbg and pump truck. Pressure tested lines to 3,000 psi. 2. RIH and tagged soft at 5,548' 'and firm at 5,555'. 3. Spotted barite amd sand plug @ 5,555'. Shut down for sand to settle. 4. Tagged Sand plug @ 5,506' DIL. 5. RU wireline company. Dump 14.6 gal neat cement 5,506' - 5,497'. 6. Shut down. WOC for 48hours. Well shut-in. October 17, 1986 1. RU wireline company. Pressure test lubricator to 1000 psi. 2. Tagged @ 5,487' DIL. Obtained sample of sand and barite. 3. Well dead. RU CTU pressure test to 1,100 psi. RIH to 3,000'. Unload well to tank until well capable of flowing into 1,100 psi pipeline. Vented approximately 400 MCF unloading the well. Returned well to production. MDC/em/47A/Sundry RECEIVED OCT 2 4 1986 Alaska Oil & Gas Cons, Commission Anchora.qe STATE OF ALASKA ALASi, r ' 31L AND GAS CONSERVATION APPLICA, ON FOR SUNDRY Al-. ROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ~ 5. Datum elevation (DF or KB) ,ee Marathon Oil Company 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of wellatsurface 117' FSL, 1,338' FEL, Sec. 33-7N-lOW-SM Attop ofproduc9veinterval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM Ateffective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM Attotaldepth 1,003' FSL, 1,966' FWL, Sec. 34-7N-10W-SM 11. Present well condition summary Total depth: measured true vertical 10,296' feet 9,390' feet Effective depth: rrmasured 5,718' feet true vertical 5,306 ' feet Casing Length Structural Conductor Surface 526 ' Intermediate 2,212 ' Production 5,099 ' Liner 9,697' Perforation depth: 153' KB 6. UnitorProperty name Beaver Creek Unit 7. W~% n~ber . 8. Permit number 67-9 9. APl number 50-- 133-20006-01 10. Pobl Sterling Size Plugs (measured) 9,617' - 10,296' (cement) 8,689' (Magnesium BP) 8,417' (Cement Retain~ Junk (measured) 5,718' - 5,720' (Cement & 9,023' - 9,033' (Stuck RBP) 5,703' (BP Setting Tools) Cemented Measured depth True Vertical depth r) P) 20" 13 3/8" 9 5/8" 7" ~-2 5430' B-3 5490' B-4 5655' 1,000 SX 3,500 SX 1,800 SX 730 SX - 5445' MD 5070' ? 5540'.MD 5119' - 5675' MD 5254' Tubing(size, grade and measured depth) 3 1/2" N-80 @ 5,386' Packers and SSSV(type and measured depth) Baker FHL Packer @ 5,096', Baker FHL Packer @ 5,348' 526' 526' 2,212' 2,212' 5,099' 4,793' 9,697' 8,807' 5082' TVD 5160' TVD 5270' TVD t~ F 0 7 1986 Alaska 0il & Gas Cons, Gommiss[o Anch0ra_~8 12.Attachments Description summary of proposal I~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation ~ lO 14. If proposal was verbally approved Name of approver Date approved 15; I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)/~Cc,~hL~ Title District Operations Engineer Date 10/7/~G Conditions of approval o Approved by Commission Use Only Notify commission so representative may witness [] Plug Integrity nBOPTes, r~LocaUonc,earancelAppr°va'N°' ~--~~ , /o-. - by order of Commissioner the commission Date Form !0-403 Rev 12-1-85 Submit in triplicate Beaver Creek #lA Procedure 1) RU CTU & pump truck. 2) SIW. Pressure test all equipment to 2500 psi. 3) RIH with coiled tubing, kill well by circ. 3% KCL fluid. 4) Wash sand:fill from 5446' DIL to 5505' DIL. 4.1) If a,bridge is in the well and it becomes necessary to spot additional sand, the following slurry will be used: a)50#/ 1000 gal. HEC polymer b)10#/ gal. sand and barite ( 50-50 mixture) c) 2 hour breaker 4.2) Spot the slurry out the coiled tubing and gradually pick up at 5 ft/min as the plug is circulated. Displace with 3% KCL. 4.3) PU to 4000 ft and wait 6 hours for the plug to settle. 4.4) RIH with'coiled tubing and tag plug @ 5505' - 5500' DIL. 5) POH & RD CTU. Keep well dead by pumping 3% KCL down the tubing as required. 6) RU WL Test lubricator to 2,000 psi· 7) RIH with cement dump bailer; dump 5 ft. of cement on top of sand. TOC~ 5500' DIL (8 gal. cement will be required; use 10 gal. for 25% excess) 8) POH RD WL Hold well dead for 48 hours. 9) Unload well to tank. Return well to production at 5 MMCFPD. "';",'1' 0 7 ~ STATE OF ALASKA ~----., ALAS~ .-OIL AND GAS CONSERVATION COMI ~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-10W-SM At top of productive interval 591' FSL, 46' FEL, Sec. 33-7N-10W-SM At effective depth 688' FSL, 37' FWL, Sec. 34-7N-10W-SM At total depth 1,003' FSL, 1,966' FWL, Sec. 34-7N-lOW-SM 5. Datum elevation (DF or KB) 153' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC lA 8. Approval number 9. APl number 50-- 133-20006-01 10. Pool sterling 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 526' Intermediate 2,212 ' Production 5,099 ' Liner 9,697' Perforation depth: 10,296 ' feet 9,390' feet 5,718 ' feet 5,306 ' feet Size 20" 13 3/8" 9 5/8" 7" B-2 5430 ' B-3 5490 ' B-4 5655' Plugs (measured) 9,617' - 10,296' (cement) 8,689' (Magnesium BP) 8,417 ' (Cement Retain Junk(measured) 5,718' - 5,720' (Cement & 9,023' - 9,033' (Stuck RBP) 5,703' (BP Setting Tools) Cemented Measured depth ~rue Vertical depth 1,000 sx 526' 3,500 sx 2,212' 1,800 sx 5,099' 730 sx 9,697' 5445' MD 5070' - 5082' TVD 5540' MD 5119' - 5160' TVD 5675' MD 5254' - 5270' TVD 526' 2,212' 4,793' 8,807' Tubing(size, grade and measured dePth) 3 1/2" N-80 @ 5,386' Packers and SSSV(type and measUred depth) Baker FHL Packer @ 5,096', Baker FHL Packer @ 5,348' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHMENT #1 Treatment description including volumes used and final pressure t d'l'0 7 1986 Oil & Gas C,~i,.',. Gummi~ion Aar~orage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachmentg: #1 I~RR~Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 124-85 Title District Operations Engineer Date/o/?/~ Feet ~P) Submit in Duplicate ATTACHMENT Well Beaver Creek %lA Water Shut Off October 1, 1986 1. RU pump truck and lines to BC-1A tree. 2. Pressure test lines to 2500. psi 3. Mixed & Pumped 13.1 ft3 of sand and barite slurry. Displaced tubing w/ 3% kcl water 4. Shut down to let slurry settle across B-3 interval. October 2, 1986 1. RU wireline company & pressure test lubricator to 2500 psi. 2. RIH w/GR & CCL. Tag sand plug @ 5499' DIL. 3. RIH w/dump bailer w/3.6 gal neat cement. Tag @ 5468' DIL. POH w/bailer. 4. RIH w/dump bailer & CCL. Tag @ 5446' DIL. POH w/bai ler. 5. Shut down. BC-1A shut in. October 6, 1986 1. RU pump truck & lubricator. 2. Pressure test labricator & lines to 2000 psi 3. Kill well w/ 46 bbls 3% kcl water. 4. RU wireline company 5. RIH w/dump bailer & CCL. Tag bottom @ 5446' DIL. POH w/bailer. 6. Suspend operations pending alternate water shut-off procedure using coiled tubing. BC-1A shut in. STATE Of ALASKA AlaS~, OIL AND GAS CONSERVATION COM, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension E Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other::~] 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 153' KB feet 3. Address 6. Unit or Property name P. O. Box 102380 Anchorage,. AK 99510 Beaver Creek Unit 7. WelIBc n~ber 4. Location of well at surface 117' FSL, 1,338' FEL, Sec. 33-7N-lOW-SM At top of productive interval 591' FSL, 46' FEL, At effective depth 688' FSL, 37' FWL, At total depth 1,003' FSL, Sec. 33-7N-10W-SM Sec. 34-7N-10W-SM 1,966' FWL, Sec. 34-7N-10W-SM 8. Permit number 67-9 9. APl number 50-- 133-20006-01 10. Pool Sterling 11. Present well. condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 526' Intermediate 2,212' Production 5,099' Liner 9,697' Perforation depth: 10,296' feet 9,390' feet 5,718' feet 5,306' feet Size Plugs (measured) 9,617' - 10,296' (cement) 8,689' (Magnesium BP) 8,417 ' (Cement Re taint Junk(measured) 5,718' - 5,720' (Cement & 9,023' - 9,033' (Stuck RSP) 5 703' (BP Setting Tools) Cemented ' Measured depth True Vertical depth 20" 1,000 sx 13 3/8" 3,500 sx 9 5/8" 1,800 sx 7" 730 sx B-2 5,430' - 5,445' MD B-3 5,490' - 5,540' MD B-4 5,655' - 5,675' MD 526' 526' 2,212' 2,212' 5,099' 4,793' 9,697' 8,807' 5,070' - 5,082' TVD 5, 19 TVD Dw Tubing(size, grade and measured depth) 3 1/2" N-80 @ 5,386' Packers and SSSV(type and measured depth) Baker FHL Packer @ 5,096', Baker FHL Packer @ 5,348~' OCT 0 2 1986 Alaska 0ii & Gas Commission Anchorage 12.Attachment~: #1 Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation S~ptember 30, 1986 14. If proposal was verbally approved .. Name of approver Blaire Wondzell Date approved 9/30/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /,~),~'~~"- Title District Operations Engineer Datel-- Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP T. es, tc,J~,Location clearanceI - ~r,...~ ~Approved by by order of Commissioner the commission Date Form.l.0-403 Rev 12-1-85 ;~,. Submit in triplicate BEAVER CREEK-lA Plug Back Procedure This procedure proposes to shut off the majority of the water production from the B-3 sand by placing 20-40 sand and barite over the perforations and then capping the sand with 5' of cement. Procedure 1. RU pump~uck and related equipment. 2. Pressure test all lines to 3,000 psi. 3. Mix 10 bbls 3% KCL and polymer @ 50#/1,000 gal water with a 2 hour breaker. Water to be heated to 100°F. Add 1,370 lbs sand and 1,220 lbs barite for 49' fill up in 7",'29# casing with 25% excess. 4. Bullhead slurry down tubing at 2 BPM or greater rate. Maximum pump pressure 2,500 psi. Displace with 46 bbls 3% KCL fluid. Stop displacement 5 - 10 bbls short if pump pressure begins rapid increase due to bullheading polymer fluid into formation. 5. R/D pump truck. Allow sand plug to settle 6 hours. 6. R/U W..L. Pressure test lubricator to 2,500 psi. 7. RIH with sinker bars and CCL. Tag fill. POH. Contact engineering with the DIL depth of the sand plug (should be 5,500' DIL). 8. Place 1.0 ft3 cement (5 ft fill up in 7" casing) with dump bailer on top of sand plug (the top of the cement plug should be ±5,495' DIL). 9. R/D W. L. WOC 48 hours. 10. Unload and test well. PMS/em/132/0E12 RE£EIYEI) f 0 2 1986 Gas Cons. ,,., .~ Anchom~Je ""'" STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION CON. ,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other ~ Water Shut-off 2. Name of Operator - 5. Datum elevation (DF or KB) Marathon Oil Company 153' KB Fee' 3. Address 6.~nit or Pr..opert,y P. O. Box 102380 Anchorage, AK 99510 weaver ~ree~nr~et 4. Location of well at surface 117' FSL, 1338' FEL, Sec. 33 - 7N - i0W- SM At top of productive interval 519' FSL, 46' FEL, Sec. 33 - 7N - I0W - SM At effective depth 688' FSL, 37' F~L, Sec. 34- 7N -i0W- SM At total depth 1003' FST., 1966' ~-~, Sec. 34 - 7N - 10W- SM 7. Well number BC iA 8. Approval number 9. APl number 50-- 133 10. Pool Sterling 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 526 ' Intermediate 2,212 ' Production 5,099 ' Liner 9,697' Perforation depth: measured 10,296 ' feet 9,390 ' feet 5,718 ' feet 5,306 ' feet Plugs (measured) Junk(measured) Size Cemented Measured depth 20" 1000 sx 526' 13 3/8" 3500 sx 2,212 9 5/8" 1800 sx 5,099' 7" 730 sx 9,697' See Attachment 1 true vertical Tubing (size, grade and measured depth) 3 1/2" N-80 @ 5,386' Packers and SSSV (type and measured depth) FIlL pkr @ 5,096' FHL pkr @ 5,348' ~ue Verticaldepth 526' 2,212' 4,793' · 8,807' RECE!Vr 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MAY ! ]986 Amska 011 & Gas 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 0 5,047 121 990 0 4,132 4 930 ~bing Pressure 1,440 1~590 14. Attachments See Attachment 2 -,~a~ Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title District Operations EnFineer Date 5/12/86 Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment 1 Beaver Creek Well #lA Perforations Sterling Gas Sands 2 HPF B-2 B-3 B-4 5,430' - 5,445' 5,490' - 5,540' 5,655' - 5,675' TVD 5,070' - 5,082' 5,119' - 5,160' 5,254' - 5,270' WJL/em/089/LAV Attachment 2 Beaver Creek Well #lA Water Shut-Off Sand plug operations began on April 18, 1986, and were completed April 24, 1986, as follows: 1. Rig up CTU and Pump Unit and Test to 3,000 psi. 2. RIH w/ CTU, hit bridges from 5,499' to 5,664'. 3. Pump 14 FT3 sand/barite plug. Top at 5,520'. 4. Pump 12.5 FT3 sand/barite plug. Top at 5,525'. 5. Pump 14.6 FT3 sand/barite plug. Top at 5,501'. 6. Pump 8.3 FT3 sand/barite plug. Top at 5,476'. 7. Pump 5.4 FT3 sand/barite plug. Top at 5,472'. 8. Pump 3 FT3 sand/barite plug. Top at 5,465'. e 10. Jet tbg clean with N2. Returned well to production. Note: The sand/barite plug is 40# polymer, 3% KC1, 100 mesh and 20-40 mesh sand with 25% barite with a two hour breaker. WJL/em/088/LAV MAY !986 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COwlMISSION sUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL i-~ OTHER [] 2. Name of Operator Marathon Oil Company 3. Address p.O. Box 102380 4. Location of Well Sur face: 117' FSL, Anchorage, AK 99510 1 338' FEL, Sec. 33 7N-IOW-SM 5. Elevation in feet (indicate KB, DF, etc.) 153' RKB 6. Lease Designation and Serial No. A-028083 7. Permit No. 67-9 8. APl Number 50- 133-20006 9. Unit or Lease Name Beaver Creek [hi t 10, Well Number BC ~I-A 11. Field and Pool Beaver Creek Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [~ Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). BEAVER CREEK #1-A WATER SHUT-OFF An attempt to shut-off water in BC #1-A was completed January 17, 1985. See attachment for a record of operations. RECEIVED FEB 1 1 1985 Alasi~ ud ~, ',~ts dr)ns, Commissior 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed % ~ ~. ~'~/C~"¢~ Title ~'~- ~---~ '~-- The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 COMMISSIONER By Order of the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate BEAVER CREEK #1-A PRODUCED WATER SHUT-OFF Operations began on November 3, 1984. 1. A through tubing bridge plug was set at 5720' CCL. 2. Four 20' bailers of cement were dumped on top of the bridge plug. 3. SI well 36 hours WOC. 4. Returned well to production. Operations continued on January 15, 1985. 1. Rig up and tested coiled tubing unit, BOPE, and lines. 2. Ran in hole and tagged cement plug at 5724' CTM. 3. Pumped 30 bbls of sand slurry (3 PPg of 20-40 mesh sand in 3~ KC1 pol.vmer water). 4. Tagged top of sand plug at 5600' CTM. 5. Returned well to production. WJL:cas 02-06-85 RECEIVED Alasita Oil & Gas Ce. ns. C[m'~missior~ ,~,p.r, horaue , ~ STATE Of ALASKA "~ ALASKA OiL AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Marathon Oil Company 3, Address P.O..Box 102380 Anchorage, .AK 99510 4. Location of Well Surface: 117 ' FSL, 1338 ' FEL, Sec. 33-7N-1 OW-SM 5. Elevat[o/~_i~ feet (indicate KB, DF, etc.) 153 I 6 . Lease Designation and Serial No. A-028083 7. Permit No. 67-9 8. APl Number 50- 133-20006 9. Unit or Lease Name Beaver Cr'~c,k 10. Well Number 8C ~IA 11. Field and Pool Beaver Creek Field 12. Check ApPropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). BC ~IA WAT~ SHUTO~ It is Marathon's intention to perform a water shutoff on the B-4 sand. T,brk is expected to begin November 5, 1984, and be completed according to the attached procedure. ~';,-~b~equent Work Reporte~l RECEIVED NOV 0 ! 19~ Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. si,. _ The spacet~el;~v for ~sion use Conditions of Approval, if any: Approved by 01tlGI~A[ SIGNED BY H~XR¥ W. KIIGLEil COMMISSIONER Approveci Copy Returned,-- By Order of the Commission Date ..... Submit "In Triplicate Form 10403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ~_ BC ~i-A W~TER SHI~.-OFF PROCEDURE FOR B-4 SAND AFE ~8102-4 1. Riq up on well with electric line unit. Pressure test lubricator to 2500 ,osi. 2. RIH with thru-tubing bridqe pluq. Use GR end CCL to nosition ~luq in 7" casinq. 3. Set plug. at 5730' DIL. 4. Dump bail 10' of class "G" cement on top of plug.. ( .ArLp. roximatelv 3 runs) 5. POH and rig down electric line unit. 6. WOC for 24 hours. 7. .Rig ~ coiled tubing unit and pressure test POPE to 3000 psi. 8. Rig up ptmp truck to circulate sand/water mixture on top of pluq. 9. RIH with coiled tubing unit and tag plug. 10. Circulate 20-40 mesh sand mixed at 3 ppg on top of plug from 5720 '-5580 '. Gradually~ POH as circulate sand. 11. Wait 12 hours to allow sand to settle and ~ack. 12. RIH and tag sand too w/ coiled tbg. .POH w/ coiled tbg. 13. Bring well back on line qradually while monitorinq water production. ~_ Check for sand Droduction during_, this period. Recommended flowrates during_ startup_: R ErE/ 4 MMCFD for 6 hours (or until well is stabilized) V£D 5 MMCFD for 4 hours ~OV 0 ~ ~-- 6 MMCFD for 4 hours P 8 MMCFD for 4 hours Alaska O# 10 MMCFD for 4 hours & ?~$ ~o~s. ~ornmiss~o~ ar~chorage 14. Should significant water production be noted, continue sanding ,up. hole over lower B-3 perforated interval and repeat flow test above noting water end sand ..production if any. 15. Should there be sand production, a 10' cement cap could be spotted on top of the sand column. 16. Rig down coiled tubing unit and pump truck. 17. Return #I-A to normal production level and closely monitor well for both water and sand production. P~4: cas 09-25-84 ALASKA ( ] AND GAS CONSERVATION C(~-~,~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS4 /. · Drilling well [] Workover~ '~1~u~' ' 2. Name of operator 7. Permit No. Marathon Oil CompanY 67-9 3. Address 8. APl Number P.O. Box 2380, Anchorage, AK 99510 so-133-20006 4. Location of Well at surface 117 ' FSL, 1338' FEL, Sec. 33-7N- 1 OW-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 138' GLI A-028083 9. Unit or Lease Name Beaver Creek 10. Well No. BC #lA 11. Field and Pool Beaver Creek Field For the Month of. 0ctober ,19 82 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 10,296' TD; 8023' PBTD RU over the well 10/20/82. Flow test B-2, B-3, and B-4 perfs. Killed well and pulled tubing. Washed fill to 6339' DPM. Isolate B-4 perfs and test. Ran 3-1/2" tubing, lower pkr at 5348' tubing'measure, top pkr at 5096' tubing measure. Isolated sqzd perfs 5300'-5310' DIL. Ran GR/CCL. Perf B-4. Flow test B-2, B-3, and B-4. Set BPV. Operations completed 11/01/82. 13. Casing or liner run and quantities of cement, results of pressure tests NA :14. Coring resume and brief description NA 15. Logs run and depth where run GR/CCL 5800'-5300' DIL 1G. DST data, perforating data, shows of H2S, miscellaneous data B-4 sand perforated w/ "Sl imkone", 4 HPF, 0© phasing 5655'-5675' DIL. RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOV ! 9' 1982 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev_ 7-1-F~O Submit in duplicate r--',, STATE OF ALASKA ~ ALASKA ._~. ,L AND GAS CONSERVATION C~.,¢IMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Marathon Oil Company 67-9 3. Address 8. APl Number P. O. Box 2380, Anchorage AK 99510 50- 133-20006 4. Location of Well Surface' 117' FSL, 1338' FEL, Sec 33-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) _ 138' GL 6. Lease Designation and Serial No. A-028083 OTHER [] 9. Unit or Lease Name Beaver Creek Unit 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans ' [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 10. Well Number BC #lA 11. Field and Pool Beaver Creek Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Workover operations began on October 20, 1982, and were concluded on November 1, 1982. See Attachment for a record of operations. RECEIVE ) NO'U 0 8 1. B2 Gas Corm. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ATTACHMENT BC #1. A workover was completed as follows' 1. The well was flow tstd from Sterling B-2, B-3 and B-4 perfs at 4.33 MMCFD, 1540 psi FTP, 0 water. Ran wireline and tagged fill @ 5601' CBL meas. 2. The well was killed w/ WO fluid and the 3-1/2" tbg was pulled and layed down. 3. Fill was washed to 6339' DPM. 4. A retrievable pkr was set @ 5592' DPM. The annulus was pressurized and there was no communication between B-3 & B-4. 5. The well was flow tstd from Sterling B-4 perfs @ 2.9 MMCFD, 1440 psi FTP, 0 BWPD. 6. The well was killed and the pkr was pulled from 5592' DPM. 7. The 3-1/2" tbg was run w/ the bottom 7" pkr set @ 5348' tbg meas and the top 7" pkr set @ 5096' tbg meas. Isolated sqzd perfs 5300'-5310' DIL. 8. Ran Gamma Ray/CCL. 9. Perfd Sterling B-4 w/ Slim-Kone "Big Hole" gun, 4 HPF, 0° phasing, 5655'-5675' DIL. -~ 10. The well was flow tstd frOm Sterling B-2 (5430'-5445'), B-3 (5490'-5540'), and B-4 (5655'-5675') @ 9.54 MMCFD, 1705 psi FTP, 83 BWPD (WO fluid). 11. .The BPV was set and the well was left SI. Total gas flared - 3980 MCF. RECEIVED NOV 0 8 ]982 Alaska Oil & Gas Cons. Commission Anchorage /~', STATE OF ALASKA ALASKA ~.~L AND GAS CONSERVATION C~.,~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 2380, Anchorage AK 99510 ' 4. Location of Well Surface' 117 ' FSL, 1338 ' FEL, Sec 33-TN-10~-SM 5. Elevation in feet (indicate KB, DF, etc.) __ 153' KB 6. Lease Designation and Serial No. A-028083 7. Permit No. 67-9 8. APl Number 50- 133-20006 9. Unit or Lease Name Beaver Creek Unit 10. Well Number 11. Field and Pool Beaver Creek Field 12. (Submit in Triplicate) Perforate. [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] - Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon' s intention to conduct an open flow potential test on Well #lA upon completion of well workovers in thru field. The testing should be completed by the end of October, 1982.. ~ . 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use ] Conditions of Approval, if any: FORM 10-421 (GAS WELL OPEN FLOW POTENTIAL TEST REPORT) to be submitted~, in d~upli_99te % ORIGINAL SIGNED ~.. Refurnecl ~ Lu~rd), ~ "-'/~7~/- (~ BC~yY Order °f" Date ' L~---~-/~"'~-- ~ ~ ~ Approved by ~ LONlltE C. SMITH COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA _ AND GAS CONSERVATION C !iMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL 1'3 COMPLETED WE LLM~ OTHER E] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 2380, Anchorage AK 99510 4. Location of Well Surface: 117' FSL, 1338' FEL, Sec 3-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 153' EB 12. I6. Lease Designation and Serial No. A-028083 7. Permit No. 67-9 8. APl Number 50-133-20006 9. Unit or Lease Name Beaver C~eek Unit 10. Well Number BC #lA 11. Field and Pool Beaver Creek Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data . NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate ~[ Alter Casing : r-I ~ Perforations stimulate [] Abandon [] Stimulation Repair Well ~ Change Plans I-'J Repairs Made Pull Tubing ]~ Other . ' [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] I-I Abandonment [] I--I Other r'l 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). .-. Proposed operations for August 1982 include pulling and inspecting tubing, installing a methonal injection system, and reperforating Bench 2, 3, and 4 as follows: Bench 2 5430' - 5445'.DIL, 2 HPF' Bench 3 5490' - 5540' DIL, 2 HPF Bench 4 5655' - 5675' DIL, 2 HPF E~u/p/W~NT e~Ns/S'~ltV~ oF /l 13~/~,' ~~ J U L - 9 i982 AI3ska Oil & Gas Cons. Commission /~,nchorage 14. I hereby certify that the foregoing is true and correct'to the best of my knowledge. Signed~_,~L,~O~ ~-"~' ~,,,?~_~ Title OperatioIls Et/E±l%eer The space below for Commission use DateJuly 6, 1982 Conditions of Approval, if any: Approved by f ~Ipproved "opy Returned , By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate -, UNITED STATES DEPARTMENT OF ThE INTEriOR GEOLOGICAL SURVEY 800 "A" Street, Suite 109 Anchorage, Alaska 99501 Narathon 0il Company P.O. Box 2380 Anchorage, Alaska 99510 Attn: C.F. Ferguson IN REPLY REFER TO: March 3, 1977 Gentlemen: In answer~t~our request for approval to conduct isoehronal gas testing on wells ~-~ 2, 3, & 7 at the. Beaver Creek Unit, we have no objections provided you co~mply with notice to lessees #4, "Royalty Payment on 0il & Gas Lost;', and 30 CFR 221.44 "~easurement of Gas`P, and that the drawdow~ test not exceed 15 hours for each well. We ask that you keep the flaring to the minimum necessary to achieve test results by shortening the drawdown test periods to the minimum, and by e~iminattng drawdown tests which are not necessary. We also ask that you contact this office 24 hours prior to any testi~ so that we may have a representative there to witness testing operations, and to furnish test results to this office upon completion of the testing. If you have any questions concerning the above requirements please feel free to call. Sincerely yours, (OR!,G. SGD.) R. A: SMITH Rodney A. ~th 0il & Gas Supervisor Alaska Area cc'~--Division of Oil & Gas Conservation, State of Alaska Marathon Oil Company February 17, 1977 Ancho on Produ¢ ,'ations US & Canada PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 Mr. H. H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: L'r'"'~2, 3 & 7 BEAVER CREEK UNIT WE~~ ~-~mA STERLING GAS SAND - I L TESTING The purpose of this letter is to solicit your approval for flaring of gas duri.ng testing of the Sterling. gas sand in several wells at Beaver Creek. Marathon Oil Company propOses to run modified iSochronal tests on each of the above referenced wells during the month of March, 1977. Each well will be tested for a period of several days to maximum rates of about 10 MMSCFPD through a portable separator and flare stack. An outline of the proposed tests is attached. Very truly yours,~ C. F. F~ergus'on ~ Division Petroleum Engineer CFF- kbs cc: R. A. Smith U. S. G. S. R. A. Richey U. S. Dept. of Fish and Wildlife RECEIVED FEB 1 8 1977 Division of 0tl & $~ ~O~a~iorl BEAVER CREEK FIELD GAS WELL TEST PROCEDURE 1. Run the bottom hole pressure bomb/to the well. , 2. OPen the well for 15 hours drawdown test at a stabilized rate of 2000 MCF per day. 3. Shut the well in for 15 hours buildup. 4. Run modified isochronal test at daily rate of 2000 MCF, 5000 MCF, 8000 MCF and 10,000 MCF at a At of 1 hour. 5. A surface recorder is also needed during the above test. 6. Pull the pressure bomb at the end of the test. AtD = A~tB = 15 hrs atl = At2 = at3 = At4 = At5 = At6 = 1 hr. At7 = tpss = 2 hrs. if A = 640 acres K = 2 darcys Marathon Oil Company January 29, 1976 Mr. Rodney A. Smith Oil & Gas Supervisor, Alaska Area U.S.G.S. P.O. Box 259 Anchorage, Alaska 99510 Manag( ~, .... .., Division Produc, ,3perations US & Canada .... ---' ' C- I"'"'~'- ~ ~G ~ , I .' lolephone ~07/274 1511 Dear Mr. Smith: As you requested in your letter of December 17, 1975, enclosed is a schematic drawing of our production facili- ties at Beaver Creek Field. All oil and gas metering points are shown on the drawing. A list of the meters and abbreviations to be used in the following discussion 'are: Beaver Creek #4 Separator Gas . . . #4 S.G. Beaver Creek #5 Heater-Treater Gas ............... #5 H.T.G. Beaver creek #4 Gas Lift Gas. . . #4 G.L.G. Beaver Creek #5 Gas Lift Gas. . .. . #5 G.L.G. Beaver Creek #lA Makeup Gas .... #lA M.G. Beaver Creek #lA Injection Gas ............... #lA I.G. Fuel Gas .............. F.~G. Beaver Creek #4 Separator Oil Turbine Meter ......... · #4 T.M. Beaver Creek #5 ~eater Treater Oil Turbine Meter' . ....... #5 T.M. The disposition of all gas at Beaver Creek as reported on your Form 9-329 is as follows: Beaver Creek #lA Injected Gas = #iA I..G., Metered Beaver Creek #lA Produced Gas = #iA M.G., Metered Mr. Rodney A. Sm__h January 29, 1976 Page 2 Beaver Creek #4 Produced Gas = #4 P.G. = #4 S.G. - #4 G.L.G. Beaver Creek #5 Produced Gas = #5 P.G. = #5 H.T.G. - #5 G.L.G. Fuel Gas = F.G., Metered Total Produced Gas = T.P.G. = #iA M.G. + #4 P.G. + #5 P.G. Shrinkage = (#4 G.L.G. + #5 G.L.G.) x 0.021452 Flared Gas = T.P.G. - F.G. - #iA I.G. - Shrinkage The shrinkage shown above is to allow for condensation of liquids in the compressor after coolers and scrubbers. As shown on the diagram, this liquid is blended with the 'oil and sold as oil. The small amount of liquids involved would be difficult to.meter with any degree of accuracy. Instead, the shrinkage was calculated with the NGPA flash program utilizing observed pressures and .temperatures on each scrubber and a known gas composition. Please advise if you need additional information. Very truly yours, ~l~eChl~, jr. Division Operations Manager AM/pr Enclosure cc: Mr. O. K. Gilbreth, Director Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 ! k ¢0DE' 50-133-20006 . . · Re,~ese Date: ._:9.1_-69 State of Alaska Department of Natura) Resources' DIVISION OF HINES AND HINERALS Petroleum Branch T. 7N · , R. !O ~ INDIVIDUAL WELL RECORD ,,~8 ...... Heridlan Permit No. -_ 67_-9_ __ Issued __ 3~10-67 ..... Operator !~arathon Oi!_,C~,~ ......... Location (Surface) 11_6.9' ESL & _1338_.~'_Fg~_,8.e,..c.,~.33 Lease No. A-028083 or Owner R~.m~ n~ ~ Loc. (Bottom) 1003" ffSL & 1~.~6~ ~ Sec. 34 -. .. .. Wel 1 No. 1-A Area Spud Date_. 3,13_-67 ' ._ .D,rilling Ceased ._;__-= _ S uspen dad Abandoned ..................... Gas .............. Completed (F-GL-P) ....... 8-_!~67 _ .... IP ,. ~_,, ,B/D. Grav._ii.j~z_API Total Depth 10.296" E levat ion,_. ~62~_R,Tj '~ Cut Ga s..Lla./t~jl._.M C F/O, Bean ___/64 Casing: Size . ~ SxCmt 20'-9Z~# 526' 1,000 CP psi, TP 15.92 psi Perf: p,.,,a_ Tn~- ~lugs. over fish 6550'._-_6-z~O0'6~.T 8956-76 , 8797'-8817' Bt,PS 9s033m cat. to 9023' 8956-76 ...... B.P. 8689m . .................. - ........... 8689 ~-8599 ' -&- sx 8526~.61~ · 13 3/8"-61~ 2209' 3,500 ''- ' _ _. ~ ~ (700 DVC~_.~..O80 5 , 75 ]3.~. 5600' 7~: 9700 730 5490'~-40' . . . GEOLOGIC FORHATION$ PRODUCTIVE HORIZONS Surf~c~ k~t T~t,d ~m ~epth .~ : -.- , -[,.__ _ , _ IL ' _ _ --_ _ ~ ' -- - .... L _ _ - L - - _= ...._~hru~re}_a_tn_er...&., 84!7 (_8_0 Sx out- side) · WELL STATUS Year Jan Cab i Mar Apr Ma),. June July _,Aug ~_Sept ..... OCt,__, Ng~ .... D~C Ping'back 3963' tb 3650' & redrilled Oas Sh0vs 540~-~5"& 548~5-25"M,~ Dev. & 7085~ 36° 1~~ (630.6 N & 2228 S'T, Tools & drill,s asse~ly, Fishins asse~ly ~d wash pipe 7722~,65~O~., redrilled !rom 6~001 - 77221 (1322I) 8797~-8817' ~ Tes~ Rem rks: 8956-76 -- --- ---"- ......... 5655'-5675" lest' 8,150- X~'/O .... -' '~ID-¥' c , .... z s ..... - = ~ ~ . ._ ... ..... ... __.. ~,, .~_~ n~n - ~ _ ,__ _sa. !25 :ak. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~Form approved. '~'~k Budget Bureau No. 42-R856.5. L,,o o~,cE ...... __A_.n__c.0__o_r~..e. ......... · E^s~ .u..~. A-028083 LESSEE'S MONTHLY REPORT OF OPERATIONS Tl, e followin~ is a correct report of operations and prod~etion (ineludin~ drillin~ and prod~ein~ .- wells) for the montl~ of ........ _A~9~._ll ..................... ,19_.6..7.., ............................................................................ "'- ~e~'s address ..................... .?.~..l____I_:_~S..t,_..r..e._e..~.. ..................... Company Marathon Oil Company .. ............................................... ............ ..... ~'~one ..................................... 2l~.-.~.4.1l,: .......................... .~e,~t' s ,~,t, ___D!.s__t_r__i__c_.t.__9_~..e.r..a..t._i..o..n..s_...M. ~ r... ..... ~tEC~ AND ' BARREL8 Or OIL GRAVITY (In thOtL~nCtS) GASOLINE WATER (Il (If drlilinz, depth; if shut down. '~ or ~ ~'wr. RANGE WELL DaYs CU. FT. OF GAS GA~ONS or BARRE~ Or REMARKS ' NO. PaOD~O~D . ~ECOVERED ~0~O~ ~ 8~tO) ~ ~d rNult ~ t~t for .- eou~t ~ , .:, ,, .. ,. /Sw/s[ 7. ' .:.,. ~e14;tatc dttring .mont~ of Augusl ,. 1967. s , ..~..-**** ', j :. ,. ,...- · : '.~.. : ' : j . ' , ::. . · j' ...' . · .. .' [ · .'.. . ":.~ · .. .-.,. : . -~... ::-' . . . . . ' ~ '~ . -. · .: .'. -, . , .:., .. . . . . . , '.-} · , .'. . . ' . . ., '. .. , .. .. . q I . . . , '. . ,'' .. .. ..' . - . ~ · .. :' .- . . . . . . , . . . . , . ,. ~-,~ . . ' .. . , . . ' . ', . ' :. · '.. · ,' ...,....~ ·. . : . t ,. . · I . I ,, i . .. i., No?E.--There were .......... B.0 ........................ runs or sales of oil; .................... .n..0_ ...................... M cu. ft. of gas sold; .................. _0__0_ ...................... runs or sales of' gasoline during the month.. (Write "no" where applicable.) No,-.--Report on this form is required for each calendar month, regardless of the status of operationz, andmust bo filed in FoFm 9-829 (Sanitary 19fd}) l~&TO6'-O U.I. eOV~##llfN? PIIINTING OeP*iCe SEP ? 196f DIvISIoN OF MINES & MINERALS ANI'i. Hr~AGE FRee.m,9-330 · UI'~"¥:D STATES _. SUBMZT Z. DUrLk._/ DEPARTMENT OF THE INTERIOR ,, GEOLOGICAL SURVEY' : reverse ,ida) WELL COMPLETIONO~ RECOMPLETIONREPORT AND LOG* ~a. TYPE OF WELL: O11, ~ (;IS ~ '~ ' '- ;-', w ~L~ w E u, Da Y Other I~ TYPE OF COMPLETION: , - - ,NEwr~ woRi, E3 D..-E] ..UGE3 D,..~ ,,,-"" !~' Ell, l, O%'E~ EN BACK ngsva.:~ Other 2. NAM~ OF OPERATOR .';~ ~. Marathon Oil Company 731 I Street, Anchorage, Ahska 99501 Form approved. Budga Bureau Iq'o? 5. LEASE DESIGNATION AND 'SERIAL NO. A-028083 .... 6, IF INDIAN, ALLO~EE .OR TRIBE 7. UNIT AGREEMENT NAM~ ' . ~ Beaver Creek ~n~t~ 8. FARM OR L~ASB NAM~ ' _ Beaver Creek Unit. 9. W~L NO:. ~ '- ~: _', ~ .. r: ~" "Wi 1 dcat:.:' '- '::': ";': *t,,~,e 116.9' N & 1338.1' W from SE cOrner~:~Sec. 33 T7N RIO W SM At top prod. ·interval reported below " :.~ ~ 517.9' N & 46.1' W from SE corner, 'Sec. 33; T7N, RIOW SM At total depth ~ 1'1,. SEC., T., a., M.., OR BDOCK AND ;'L~ :;OR AREA'. ~ .i ~i ~" Se~' :~ ~",~ c!: ~;33!iTT'N:!i Ri0W'.iSM lO03'N & 1966'E from SW cornerl ,. PERMiT:.O,''I/ Sec. 34, TTN, RIOW SM - -.- .-I State 67-9. DATE ISBUED I .,..3/!o/67 12: COUNT~ OR l' 13. STATE':~ ' '" ' ' .... '; :PA,R]SH -', ....] A1 kai' ~r :~'i Aerial ~. as 15. DAT" SPUDDED3/13/67 J 16. DATE T.D. REACHED ]6/13/67 17, DATECOMPL.(Re~ytoprod.)8/1/67 j ,~s...v..o. (., .., .,., .~.). B'] 5312 GR-] 38.4 2~~fl~V a ~ J 21~PLU~iC~T~., MD a ~ J 22. ~ M[!LTIr~E'COMPL.,I '~ I ~23. INTERVALS . 9.392 TVD I 7 ~ TVn ' I ..... ~ ,~ ~,:, l j ~ I '~:::'~:;"~:"~ ND - 5,430-5,445' TVD - 5,069-5',083' ~' i.,,:"; ~ ~ 5,4'90-5,540' ' ' ' 5,1~5-5,171'~ :~'[~ ~ ~'~. ;:[ lES, Sonic, Ga~a Ra~, Continuous Dipmeter,:~TmperatQre & Cement Bond - . 2,2. '" CASINO SIZE WEIGHT, LB./FT. · 20" 94 CASING RECORD (Report alt strings set'in well) .; .. ).: :f 'j 9.697.83 .. :-8~1/2'I I ': CEItIENTIN(I RECORDS.' .) ? 1,000 s x: ; -;- ::,- 13-3/8" , !9-5/8" 40 & 43.5 i7" 26 & 29 · , SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* C EN (MD)i ! SIZE DEPTH SET (MD) " PACKER Si2T (MD) J:'. 82/,. 'ACID,, SHOT, mAC.RE.-CEMENT SQUEEZe. ETC.?'.; ;;~: J " DEPTH INTERVAL (MD) A~IOUNT."AND'KIND OFf,MATERIA~ USED;; ': -{- .- '- : ':-F .... -- ., , ?~' , Perforated various intervals from reports for details. - . ,025 sx.. .- :' ,500 sX 730 s;x;. DATE fIRST PRODUCTION J PRODUCTION METHOD (FlOWing, gas Iqt,.pumpt#g~size a#d-tppe o! pump) %: I. WELL STATUS (P~oguet~g ' ' [ ....................... ~:~ 2." ' 'i ": ~ ; ~: ~;['" '.-shut-in)".. .J.o...,. .o......I ~.o..,z.' .o...o.~:;'~ 'o?'. ~ ':~. :~ i ?~;l': ~; ~'shutq'n;:..':. I I · I ~BB~ P~RIOD i'~ ,~ , : ~'; y ' , :. -: ::, ~' ~' -: -: 11' ' 8/1/67 I 8 h~s I vaHablel >~< ~ ~--:,'~'.".~::,le.i -- I :'~'::~:-':-:' t"?:'.l- Variable I packer i ' > I -0- ;~.g:~];1 26,16'4' I ,:o:; :ti--. :---',,-. _:.. ~:~ .~?._~: ~'~:: .~;' ::'. :' '.' ~' '~ ~' -, ~ ,- . '.... :.' 4 .~ ~. Alaska Oil & Gas Conserwt~on Co~. Fo .No;, G-1 and:Curve ?.: :: '- -.." , i~,~ , '- ' *(m I.,~.,o., ..a SEc" ~o, aaa,,~o..'l Data on R.m. Side) AUG .01¥!$10N OF lvllN5 & INSTRUCTIONS · . e"¢,al: This form is designed for submitt~n~ a ~omplete and c~rrect Well comPletion' report and log on ail type~ of lands and lea~es to ~ither ~ F~eral.agency o~ a S~te a~nc~, ~ ~th, pu~uant to applicable F~eral and/or S~te laws and regulations.~ Any necessary s~ial inst~ctions Conceding the use of this form and the number of copi~ to ~ubmitted, particularly with regard to local, area, or re~onal pro~ures and ~ctic~, either are shown below or will be ~su~ by, or may be ob~ined from, the local Federal and/or State offi~. See i~tructions on items 22 and 24, and ~, below regarding separate reports for separa~ completions. ' .... '~ - ~ not filed prior ~'~ the time this summary r~rd ~ submitt~, ~pies of all currently available 'logs '(drillers, geologists, sample and core analysis, aH types elecfric, etc.), f~rma-' flon ~nd Pressure ~tests,~ and directional surveys, should be at~ched hereto, to the extent require'by applicable Federal ~d/or S~te laws and re~lations. All attachments ~our~ be listed on this form, s~'item 35. ~ ~ = --~ I~em.4: If there are no applicable S~te r~uiremen~, i0catio~s ~'-F~eral-or '~ndfa'd' land shoUld be de~c~i~ in accordance wi~h F~eral 'r~uirem~n~. '~C°~sult local or F~eral offi~for specific instructions. ~- ~ - ~ .................... X :'~;' I~em 15: Indica~ which elevation is us~ as reference (where not otherwi~ shown) for depth measuremen~ given in Other spaces on thi~ form and ~ an~ attachment. I~em~ 22 and 24: If this ~eH is completed for separate producti°n from more than one interval zone (multiple completion), so sta~ in item 22, and in i~m 24 show the producing. interval, or intervals, top(s), bottom(s) and name(s) (ff any) for only the interval re~ ~ i~m ~. Submit a ~parate rep~ (page) on~t~ form, ad~uately identified, for-each additional interval t0 be sepa~ly produc~, showing the additional data pertinent to such interval.. - ~'~ ...... :- Item 29:~;"Sacks Cement'": A~ch~ supplemen~l-re~rds for th~ well shoed show the de,lis of any multiple Stage Cement~g and t~e lo&ti0n Item 33:'Submit a ~payate completion re~rt on this form for each intervalr.~o..~e separa~l~Pro~uc~. (S~ inspection for items 22 and 24 a~ve.) _: j , ~4-' DEI~T;~ INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN, FLOWING AND SHUT-IN I~RESSURES, AND' RECOVERIES Th~' ~ell ~s ~nd~numer°~ -~es~s ~un on :~etvs'ls 'f~om';~9',]'14' ~o /:: ; .? ~:, c~ ~ ~ ~ ..... '. · 5,300"~: The ]ifferent i~tervalS'"a'n~'results ~obt~ine~:tfi'eref~6m':~a~:.''be~ .~":~ '~ ,-' "BJ'?Z-n~~;.- , -u ~ ..... : ~,-,.. 5;~22''~. ":' :5,061' found'on previously submitted repor~ ~4 ~ I 4-POINT TEST Test Init,a, ~r] Annual ~'~ Special ['-] Field :-.Operator County Wildcat Well Reservoir Kenai Gas Zone - Cook Inlet Fm. Completion Date 3/,1_/67 Producin~ Thru [ a'.~e"°ir I Weimead [ CSa. SI'-e Set@ TBG.x I CSG. Temperature101 'F ' Temperature35.2'F 7 I! 9697 I,LT?t Date 8/1/67 ILease Marathon 0il Company Beaver Creek Unit Kenail Location 116.9'N & 1338.1'W from SE corner I Sec. 33 T7N R10W SM ! · - 26 & 29 ~76 & 6.184 · __3-l/2 9,;2 3.500 2.992 5376 ~.~o~L,~]~ . 3118 ''--' Pipeline Connection [ Type Taps none I 'pipe,' .... Multiple Completion (Dual or Triple) ~ingle Type production from each zone 10,296' , 5422 5430-5675 Gravity of Liquid (Apt) OBSERVED DATA Flow Data Time .... (I~]~X) ~ Press. Diff. Tubing., . Casing ., '. Flowing No. of Flow (Line) (Orifice) h Press. ' Press. Temp. Hours Size : Size psig w psig pstg 'F , S~ ''' ' I .... 1863 I ,. 1-1/4 , 6", 2.750 ., 605. 12 .1811 packer ,-.15 ~. 2-,,3/4 6" 2.750 595 21 1762 packer -4 ~. 2-1/4" , ,'6" ' 2.750. 610 36.5 1670 packer +5 4.., - ]-3/4,, J, 6" .... 2.750 610 51 ' ' 1592 packer ," '~10 FLO%V CALCULATIONS Coeffi- Flow Temp. Gravity Compress. No. etent ~ hw p Pressure Factor Factor. Factor Rate of Flow (24 Hr.) m psia F rl F F Q MCF/D t g . pv a.' 43.20'~ 86.25 620 1.081 1,313 1 ,'094 5,786 ~.~ 43.20 113.20 610 1.068 1.313 ,. '1.0~)4 7,433 a.... '43.'20 151.05 '625 1 '.057" ' 1.313 1 ·079 " .9,772 4~'.20 178.53 625 .... 1.052' ' ' 1.313 1.077 1'1,473 PRESSURE CALCULATIONI P eS_] P W p., F Q (F Q)' Cal. ~ . (psis) . ~Z Z- S sP Pt es:t ~ ~ L/H L/H(C~,. x x~ P~ S . f ~' - ~' - ~x.'% f , , ., ~.1826 4341.3 14.77 233.64 70.6 4411'[9 183.1 2100 O,,~ - , , , , , z 1777 4108.2 19.02' 387'.44 116.6 4224.8 370.8 '2055 0.96 ~., ,, 1685 3688.1 25.19 679.6 20~.2 3891.3 704.3 .... 1973[ ,:, 0'.92 ~. 1607 3349.4 29.72 946.0 281.0 3630'.4 965.2 1905 0.89 Absolute Potential ] n 26,164 >~CF/D 0.44577* ,.. ,..., , Adv. CERTIFICATE: I, the undersigned, state that I am th. Pet- Fn?'_ of theMa~ath0n iii l Company (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are tr~), correc~ and complete to the best of m.y knowledge. *In that slope is less. than .0.5 acurve Signature/~'~ .wi th a slope of 0.5 was used to arrive at the above potential. . Alaska Oil and Gas Conservation Commission R E C E-IV E D AuG 7 1967 · DIVISION, OF .MI~,~ES'& MINERAL8 Gas Well Open Flow Potential Test Report (4-Point Test) Form No. Authorized by Order No. 1 ,, Effective October 1, 1958 "- 6 . 1 . . · ... Q- MCFPD 2 2,5 3 4 5 6 7 8 9 10 DOCUMENT TRANSMITTAL , Marathon Oil Company 731 "I" Street Anchorage, Alaska 99501 Date: ~-14-67 WELL:, , HARATH.,9['I .... . .... LEASE: BEAVER CREEK NUMBER 1-A SEC.33 The following data lis h6reby transmitted, to Mr. Thomas R. ~:lgrshall (Operator) R !l 0¥'I ' ~ SimBM .of the STATE OF ALAS_KA - Div. Mines & Minerals Company Please acknowledge recei . pt by signing and returning one copy to Marathon Oil Blue Sepia I I '1 qlue iSepi~ I I I I I I i i I I I Other Blue Sepia i I SWS i J Conventional IES Log DIL Log Sontc Log Dens i ty. Log Micro Log Dipmeter Log Neutron Log ., Cement Bond Log Temperature Log_ Core Description. Core Analysis ] SWS. i ' ' ] Conventional Cores [ JWashed I I Unwashed [ ] Charts~ ~ J Data Ditch Sampl es Fomation Test 1 Copy DST #4 5., 7 9 lO HYdro~,Carbon Analysis i ii ii i i i ~ I I ~ ~l im'm , '1 i DIVISION OF MINEs & MiNEfeaL,e . . ,.,.-~::~ · -) ~CHO~GE' . .... Well History Other Company. Well Field CORE[ LABORATORIE[$, INC. Petroleum Reservoir Engineering DALLAS, T£XAS August 3, 1967. Marathon Oil. Company Beaver CreekNo. 1-A Formation County. State Page_l of 5 File RFL 4539 8956-'8976 F,t, ~klaska HYDROCARBON ANALYSIS OF DST No. 4 ,GAS SAMPLE GPM Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso.Pentane n-Pentane plus 0.16 99.67 0.11 0.05 0.01 Trace Trace Trace 100.00 0.014 O. 003 0.017 Calculated gas gravity ( air = 1.000) = O. 556 Calculated gross heating value = 1 01 0 BTU per cubic foot of dry gas at 14.696 psia at 60© F. RECEIVED AUG 1 - DIVISION OF MINES & MINERAL,~ ~'NCHORAGE These analyses, opinions or interpretations are based on- observations and mate~i_al~.supplied by the client to whom, and for whose exclusive and eonfldent_~.l use, this report is made. The interpretations or opinions expressed represent the best judgment-of Core Laboratories, Inc. (all errors and omissions excepted).; but Core Laboratories. Inc. and its officers and emnlov~s, assmmo no ep~nonsibilitv and rnako no warranty or r~.nr~.son~ationa ss to th~ ~lno. itvt~v. ~,~rm~ em~. CORE LABORATORIES, INC. Petroleum R~er~oir Engineering DALLAS. TEXAS August 3, 1967. Page_ 2 of 5 Company. Well Marathon ~ Oil. Company Beaver Creek No, !-A File RFL 4539 8797-8817 Ft. Formation 8956-8976 County Field State .~klaska HYDROCARBON ANALYSIS OF DST No, COMPONENT I MOL. PER CF.~IT I .GAS SAMPLE GPM Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane plus 0.09 0.26 99.50 0.10 O. 04 0.01 ' Trace 100.. 00 0.011 0. 003 0,014 Calculated gas gravity ( air = 1.000) = 0.557 Calculated gross heating value = 1 00 8 BTU per Cubic foot of dry gas at 14.696 psia at60° F.' DIVISION OF MINEs & MINStreLS ANCHORAGE These analyses, opinions or inte~re~tions are ba~d on. obviations and ma~z!~l suppli~ by the client to whoTM, and for who~ ~clusive and confldent~l this repo~ is made. ~e in~retations or opinions ~res~ ~pre~nt ~e ~t ~ud~ent- of Core ~ra~ries, Inc. (all erro~ and o~ssio~ ~cep~)'; ~i ~o~ L~h~e~tovi~s~' Ina. ~nd its ~ffio~rs and emnlov~s_ ss~m~ no r~ibilitv and ~ke no wa~n~ or reore~n~tions as ~ ~e or~uctivi~, vro~r o~ Company Well Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS August 3, 1967. Page .3 of 5 File RFL 4539 Marathon Oil. Company Beaver Creek NCo 1-A Formation 5655- 5675 Ft, County. State Alaska HYDROCARBON ANALYSIS OF DST No. 7. 'COMPONENT MO1 PER CENT .GAS SAMPLE GPM Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane pl u s 0.34 99.56 0.10 Nil 1 00. O0 ' Calculated gas gravity ( air = 1.000) = 0o 556 Calculated gross heating value = 1 00 7 BTU - . per Cubic foot of dry gas at 14.696 psia at 60© F. RECEIVED DIVISION OF MINEs & MINERALs ~CHOgAGE These analyses, opinions or i~te~re~fioas are ba~d ca obse~afioa~ and ma~fi~l s. ppli~ by the clieat to whom, end for who~ this repo~ is made. ~e inte~re~tio~ or opMio~s ~res~ re~re.ent ~e ~.~ ]ad~e~t' of Core ~rstories, Inc. (ali error, and Company. Well Field CORE LABORATORIES, INC. Petroleum.Reservoir E~gineeri#g DALLAS. TEXAS August 3, 1967. Marathon Oil Company Beaver Creek No. 1-A Formation County. State Page 4 . of 5 File RFL 4539 5490- 5.540 Ft. Alaska HYDROCARBON ANALYSIS OF DST No. 9 COMPONENT I MOL PER CENT GAS SAMPLE GPM Hydrogen Sulfide Carbon Dioxide 0.0 3 Nitrogen 0.8 8 Methane 9 8.9 9 Ethane 0.1 0 Propane plus Nil 100.00 Calculated gas 'gravity ( air = 1.000) = 00 55 8 Calculated gross heating value = 1 002 BTU per Cubic foot of dry gas at 14.696 psia at 60° F.' RECEIV[B AUG ! 5 1967 DIVISION OF MINES ~C, HORAGE These analyses, opinions or intez~retations are based on- observations and matezLal supplied by the client to whoTM, and for whose exclusive and confldentis~l this report is made. The interpretations or opinions expressed represent the bez~ ~udgment of Core Laboratories, Inc. (all errors and omissions excepted); ~{ C. ore Labora_tor_ie_s, Inc. and its__ officers and employees, assume no responsibility and _mak_e _no warranty or repre_sentati_o_n_s as to the l)roduetivity, proper opera- CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS August 3, I96'7. Company. Well Marathon Oil Company Beaver Creek No, l-A, Field Formation · County State Page_5 of 5 File RFL 4539 54 30- 544 5 Ft. Alaska HYDROCARBON ANALYSIS OF DST No. 1.0 GAS SAMPLE COMPONENT MOL. PER CENT GPM Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane plus 0.03 0.98 98.89 0.10 Nil 100.00 Calculated gas 'gravity ( air = 1.000) = O. 55 9 Calculated gross heating value -' 1 001 BTU per cubic foot of dry gas at 14.696 psia at 60° F. RECFIVED DIVISION OF MINES & MIN~IiI,,~ ~ ANCHORAGE Core Laboratories, Inco Reservoir Fluid Division P. Lo Moses Operations Supervisor These analyses, opinions or interpretations are based on. observations and mateti_aJ_ supplied by the client to whom, and for whose exclusive and confidential this report is made. The interpretations or opinions expressed represent the best judgment' of Core Laboratories, Inc. (all errors and omissions excepted).; u~i C. ore Labora_torje_s, Inc. and its__ offieers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- REPORT RECEIVED of 'SUB-SURFACE DIRECTIONAL SURVEY MARATHON OIL C0. COMPANY' BEAVER CREEK I- A. WELL NAME WI LDCAT. ALASKA JOB NUMBER TYPE OF SURVEY DATE AL3 -467 SINGLE SHOT MAR. - JUN. 1967 SURVEY BY LO N G B E AC H OFFICE L/THO 8¥ EASICO IN U $. A, 1 2 '3 5 6 7 8 9 I0 i1 12 15 16 17 18 19 2O 21 22 23 Dec'! Correction DRI~ ! ~ ...... VERT CA~ ~l ..... 'T N ' - ........ ' ..... 00'30' 329 li N 3~'O0'E 3 b3 01' 00' 609 01' 00' 737 150.,I O0 33(~i00 610,:00 , 738, O0 '850,~oo I I 1022, '.00 1147.00 1272 O0 1400 '00 1520 O0 1746 ~00 2000 "00 2113 '00 2220 O0 2265 '00 ,, ,~ 0i 2~9 ... O0 2321 !00 2.381 '00 2444 :,oo 2506 iO0 2567 I00 ~6~5 !oo 2704 ~00 282'7 !00 289..5 ioo O0° 45 ' 1021 O0° 45 ' 1146 00' 45 ' 1771 00°45' 1399 O0° 15 ' 1519 00°30' 1745 00' 15 ' 1999 00' 15 ' 2112 00°30' 2219 00° 45' 2264 01° O0 ' 2289 02°30' 2320 05'00' 2380 0.3' O0 ' 2442 11° 00' 2503 13' 45 ' 2563 130 45 ' 2638 13' 45 ' 2696 13°~' 2815 13° ' 2881 '4 ' 8 8 8 '5 1 1 0 0 0 0 1 14 18 14 28 16 repod ~0~ dono un,Jm' r S ~:~ O0'E S 71° O0'E S 57' 00'E S 63' O0'E N 87' O0'E S 80' O0'E S 63' O0'E S 20° 00 'E S 65°00'E S 74' O0'E N 70° O0'E N 61° O0 'E N 52' O0'E N 50° 00'E .N 47' O0'E N 45' O0'E N 48' O0'E N .48' O0 'E 47' O0 '.E 45'00'E 1 27 9 35 19 59 41i39 72 37 6 7 7 8 8 36 90 79' 55 52 86 37 83 22 38 23 58 36 10 12 13 15 19 19 20 2O 22 26 32 41 51 c~r~ lo th. b~t~ ol knowledge. #I-A , 26 28 29 30 MEASURED DEPTH . DRIFT ANGLE 2938 O0 2969 co 3000 oo o~ 3 ol OO 3098 3158 31-89 oo 3229 iO0 3296,00 33~23,00 · 14°45, 1:;° 00 ' zS" ~'i5.' 1':° OO, 16' 15' 31 !::° O0 ' 32 I~° 00 ' 33 13° 00 ' 34 15'00' 3 5 ~-6' 00, 36 3385i00 i9°45' 37 3433:00 21' 45' 38' 3527 00 24'00' 39 3590 i00 25' ~5' 40 3650 ~,00 27' 30' I 41 3744 !00 26'30' 42 3775 '~00 gS' 45' 43 3836 ~00 ~4 3897 ioo 29° o0, 45 3992 I00 3i° 30 ' z~6 4086 I00 4°15' 47 4181 !00 6° 30 48 4212 '00' 49 4278 ,' O0 ' 50 ~365 ,8"30' RECORD OF SURVEY JOB NO. uA~3-46,7 March June 1967 TRUE ,I ' -- COURSE VERTICAL. I DEVIATION DEl'TH 2923 2953 2983 3013 3077 3135 326~ 3295 3353 3398 3484 3540 3593 3678 ~ Oo 3'f60 3U!3. 3894 36 58 15 03 98 i1 o3 10 8 18. 15 7 9 2o 17 38 27 27 '13 27 29 49 37 70 94 3972 ~o48 4o73 4125 52 56 18 40 DRIFT DIRECTION N 51' O0'E N '56' O0 'E N 58' O0'E N 6~' ~ O0'E N 67° O0'E 'I,~ 66° O0'E !'! 68° O0'E N 6o O0'E N 70° O0'E N 73' 00'E N 78° OO'E N80° O0 'E N 82* O0'E N 83° O0'E "82° O0'E N 73' O0'E N 73' oo'E N 73' O0'E N 73' OO'E N 73° O0'E N 73' O0"E :.ti 73' 00 'E N 73' O0'E N 74' 00'E N 74' O0'E ..... i[i Il II , , llll[., L, ' ,~ [ L RECTANGULAR COORDINATES NORTH 8T lO4 86 107 67 ll" -' 77 124123 ~OUTH EAST 123 130 137 154 168 175 2oo 207 227 245 90 12 a5 ..5~. WE$T 137. 135 139 152 156 16~ 172 187 202 219 224 ~236 250· ~33 10 86 37 84 6 31o 33'7 377 390 417 445 493 543 597 6,15 654 ~%l-A FO#M NO C"' JOJP ' i: RECORD'OF SURVEY ""°' ~' ~' "~' Pr-~~I .. JOl~ NO.--..j±~_3_-_'~.*67 l~?l~_IJa ~eh -' June - [ TRUE COURSE . DRi~ ' R E C TAN O U L A R C O O R D MEASURED DRi~ VERTICAL. DEVIATION DIR EC~ON ....... I ...... j ~ Z~ .... j WEST STA~ION DE~H J ANGLE DEPTH · NORTH j 8OUTH ' . .... ~-'~._ 54 459o'oo 3C~5' .436969 18~5~ N 75~O0'E 286~47 ~ 842109~' .. ~aa 4652~00. 36'13' 441~ 69 . 3616°, N.77'OO'E 29J~72~. .~ 877}81 56 47 ~ ~ ~O035~5~13' 41Y~440 ~83B ~ '67 ~M 76' O0 ' Z'~OO' 3011 ~ O7~ ~ 915 [33 ~. 57 4874,O03 00' 4g0i~38 91 76* E 325~58~ 1OO1;60 55 50OO~:0033'00' 470706 08.~6~ M 75'00'E 343~34 ~ 1067:88 59 5130 ;CO .-~O* l~:, 48].9~ 35 65~ 49 N - ~ : , .~ ~ 7D OO'E 36029 1131'14 bO 5pO2'CC .30~45, 48~123~6~81 N 76'OO'E 00919 1166 B6 , 61 5267.00 32'45' 49}590 B517 N 77'00'E 377~10 120! 13 62 5328 OD 3~'o0, 49~6 g7 3g 11 N' TT°00,E 3SJ~ 77 ~,~ 63 5446 'C:O 3~' 15' 5OB2 B5 6810 N. 7~'OO,E 40581 12991~4 : 64. 5180~33 .68 26 M 7.3°00'E ' 1364~t~'2 ~ ' 65 56o9i00:35000' 5281 91 71~13 N 77'00'E '441,77 1433~73 ) 66 58~4 ~oo 3? ~5' 54o0.~8 89 ~5 N T';°oo'~ j92 I ~52o 13 67 595¢,., ,'00 ~px'-' g~" 5~,9B ' 57j . 6q 85 :-: ,76' 00.,~ ~oo .61 ~ ~583 '4805 ~. · · 6~ 6oo~ oD 36'0o' 56o69 T8 TT 'N T6'00'E ~9~ 66 ~659 69 6584;00 36'00' 5583~84- 55184 I,~ 76'00'E 513:17 m'rm3166 70 6246 ~00 36'15' 5733~84 36~66 N 77~00'E 521~42 t749 38 ~ ~ · .' 71 633~ 36' 580884 54 99 N 76'00'E 72 180274 72 6400 .00 3 ~0" 585788 36 28 N 76'00'E 5935~ 18.3794 73 6~84 iOO 36' 60' 5925164 49 38 N 75° 00'E 556 ~2~ 1885.64 T~ 63~9 ~oo 0o,~ 3i 30' ~ ' 38 ~N 77'00"E . 9 197~. ' ....... . .... ~ , .. ,- - ..... RECORD OF SURVEY :,~euI .> :~,,c~ ~ . · . _ ' : ,, CHI;GKtD BY. . , ,.' M[ASUR~O DRI~ ~ERTICA~ ' COURS~ ~Rt~ · ~A~ION DE~H ANGL~ DE~H NORTH 7T 6359'oo ~,'oo' o2J~.6 ~7 75'00' ¢~Ti42 : 2069 78 7012 ~00~'' ~ ~o OO' 6374~99 ' 3~32' ,75*oO'E 6o3 ~8 2150 ~'~ 7OU9'00 34015' 6438:63 3 34 74'00'E 650 92 2!91~'34 ~U0,35~00' 6553~32 80'30 N 74000'E · 673~ 7229 [~ . ~05 2269 ~03 _.. . 5392 82 7436~00 34'4~'~' 6~3 4! E 701~6/ 2383 ~5 u, ~ 43 }~i55 I'l 76'00'E 710t03 24:17 37 85 7666[00 ~35'45' 6~I1 88 N 77'00'E 33 i5 2512~54 ~ 7727 }oo 3~]45' 6960 65 35 64 N TS'oo'E .74o 56. 2547 4o 87 7823:00 36,15' 70}9 04 '55, 40 ~,,1 [~'j~O0'S '753 03 ~60~'38 88 7885 O0 3 00' '~O09 20 36; 44 N.~o O0'E T60 61 2637 O2 89 %993 ;oo 32'3o' 718o 29 58'03 N 76'OO'E 774~6~ : 2693 33 90 8096 ~00 ,~' ~ OO' 7270 37 '49 ,93N 75' OO'E, 787 57 2741.56 91 8221[00 24'15' 7~84~35 51 34 N 76'00'E 799 99 2791 38 92 8345.00 21~15' 749~ 92 44194 N 76'00'E 810 86 ,. 2834 99 93 8407'00 19'~0' 'Ih5 36 20~70 N 7Y'OO'E 815.,52 ~ 2855~16 94 8537i00 ~8' 5' 768~ 46 4~178 N 77'00'E u~92 2895 87 95 8593 ~OO. 19' 45' 773~ !7 18 9~ N 76' O0 'E 829 ~50. .~, 2914 23 96' '8714 ~OO ~17'00' 7849 88 35 38 N 77'00'E '837146 ~948 [70 98 9030i00 13'15' 8156~'96 ~4~61 N 77'OO'E 853 55 ~ 30~II 99 9 'r5 Ioo 3'oo, a 98 63 oo 86o { 3op3 100 ' 9310 ~00 12'00' 8430 29 28~ O7 ~ ~2~ OO'E 864 [ ' 30U1 18 . ~A~R .. I - -- --~ . [ I i _ I. IL I I 'lll --] I j I : ll ll ll I LOi 104 105 106 !o7 lO9 !10 M EA.~U RE.'D 9433 ! 9d05 ~co 9739 9~oo ~oo 99!9 ~co 9970 OO 10156 ~ O0 ~0296 O0 DRIFT ANGLE 12° !3° !3° 30' 30' 3C ' 00' 30' 00' 00' 4D ' 30' DEPTH 855o 37 8907 O7 9022 ~~ 9072 932~9~"~'~ 9~' 939o 33 RECORD JOS NO. ' 'AL3-~.6,7 COUR$~=' DRIFT DEVIATION i3° 13° 26 35 23 13 62 71 !1 .~0 93 20' DIRECTION N 83° O0'E N 33° O0'E II 84° OO'E N F, 0° O0 'E N 82° O0'E N 75° O0'E 27 11 1!1 cnosm~s 3~t21 OF SURVEY ,, DATE March - June 1967 RECTANGULAR COORDINATE~ _ , , NO R~'H ~OUTH 867. P'"t' 876 878 88.3 885 885 4.8 83 51 ,4.O .q-O 31o7 3166 3178 3193 323,2 32'?~ 3289 3304 0o 4: 02 88 ?'4 WEST 'i .... UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R865.50 LA.o omcE ......... .A..n._c_.h__o..r..a.g.e.. ...... L,sE ,u,,~, ....... .A. _-. .0_ .2. .8. .0. ~ ~ ......... u,,T ...... .~__e.o.v_.e.r...C.r.e..e.k..U.n. j ~._ LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska Kenai Wildcat Well 2tare · Go~ty .................................... Field ................................................................... The following.is a ~rreet report of operations a~d prod~etio~ (inel~din~ drilli~ and prod~ein~ wee~ ena~ ng wells) for the ~gglTg~Z ................ _8_l.3./6_Z ............ ,19 ...... , ............................................................................ 731 I 5~ceet Navathon Oil Company ~l~ent' s address ................................................................... Company ............... ~. .................... : ...................... - ' · Anchorage~ Alaska . 99501 , ,£~ ~; ,::,... --,~,~.~.,, .~:. ,':~ ~,, .............................................................................................. S~ ~r~ed ....... .-.~...~.~.:...~ .... '~'~':~"Z ....... :"~:' '~'~-'~"' ~one ............................... ~f2.-..S._4.]._7. .................................. ~e~t's titU ..6_c_~g.....P.!~...~p_.e.£.a.~j.o..n_.s...~.r.. SEc. AND Da~m C~. FT. or GAs GALLONS o, BAR~.~S or REMARKS ~ OF ~ ~WF. RANGE WE~ BABRE~ OF O~ ORA~TY OASOL~E ' WATER (~ (If drilling, depth; If shut down, ~ECOVERED none, ~ 8~tO) oon~t ~ ~epth.'10,296' gD .. totot depth, FglD 8 417' g~ .. tan ami calculated itbsol[te open fl,w po :ential test on 8/1 t57. ~repar' ng to su~mi.t well completion repoi't. ;losed master v~lve~ and secured we 1 wi :h chain a~d lock. ~11 s :art repoeti,ml oper'at~ons on ~his q~ell on a n~onthly . . . .. ". : , REC[IVE[ ' ~IVISiON OP MINES & MINI ~d, iC~iOEAG; nO no 1NTo~.~'rhe~e were ...................................... ~u:~ o~ ~le~ o~ off; ............................................ M eu. ~t. ot ~ ~old; .............. f..__J~O ...................... ~u~ o~ ~le~ o~ ~a~oline du~i:~ the mo:th. (~ite "no" where ~ppl~e~ble.) No~..--Report on this form .is required for each calendar month, regardless of the status of oper~tious, and must bo filed in duplicate with the supervisor by the 6th o~ the succeeding month, unless otherwise direoted by the supervisor. For]n 9-329 (lMlllary 1950) 16--05766-9 Ill. S. GOVERNMENT I~O#TING O~FICI' Budget Bureau No. 42-R355.6. UNITED STATES L^,o OFF,C~ ....... ../~._.c..h._o._r_.a..g_.e_ ......... DEPARTMENT OF THE INTERIOR LEt~S£ ,UM,E, ..... A---028083 ........... GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS TAe following is a eorreot report of operations and production (ineh~ding drilling and producing _ ........ -..:_2._6.:.6._7. ............................................................................................... wells) for tl~e ~l~fffM/ //. i_ ,19 , .~gent's .aare~s ......... .7..3.3...!._.s..~.Y.?..?.~.. ............................. :... Company Marathon Oil Company f) r, ' ...a.. c,b ~,~ · k kY- '' '/~ '" .................... ~ ............... ~.n..c. ko.r._a_g.e..,..~.a__s, ka.. ..... .9._?.5..Q3. ....... ~ gnea ............ PI~one ......................... 2~2---54~7 .......................................... .4gent's title S~c. AND D~x~ GALLONS or BARR~L~ Og REMARKS' ~ OF ~ TW~. RANGE WE~ CU. FT. OF GAS GASO~E WATER (H (If d~l~, depth; ff shut NO. PRODUOmD BARRE~ OF O~ ORA~TY (~ though) ~E~VERED none, ~ s~to) ~M snd ~ult of ~t f~ , ,, e~nt of ,/SW/SE 7N 10W 1-A ~nable ~o oberlin repair pare~, for alcohol pu~p ~n rp~p has >een repaired md it is ~nticipated that testing will be :onducCed Augus~ . . . . . . . . No?E.--There were .......... .OD....~ ................... runs or sales of 'oil; ................ .~..0. ......................... M ou. ft. of g~s sold; no ' runs or s~les of gasoline during the month. (Write "no" where appliesble.) · No~m.--Report on this fern is required for e~ch c~lendar month, regardless of the status of operations, and must be filed in dupliea'e wi$h 'he ,upervLso, bY 'ho §th o[ ,ho ,uooeedin, men,h, unless o,herwise direol~dby ,he~ ~.~vv' ~ .V- ~ 0~' (lanusry 19~o) 16- . . f, u ~ ~ ~cf~ JUL ~; 8,1967 DI¥1$1ON O~ MINES & MINERAL5 UNITED STATES DEPARTMENT OF THE INTERIOh GEOLOGICAL SURVEY 17ora approved. Budget Bureau lgo. 42-R356.$. Anchorage LANO OFFICE ........... A::02 80'83 ....... LEASE NUMBER ................................ LESSEE'S MONTHLY REPORT OF OPERATIONS State .... Alaska ................. County ....... /~aaai .................. Field ..... ~_ildca~__N.e_l! ...................................... The followin.6 is a cpFrect report of operation, sated prodz~ctiot~ (i~t, cltedil~ drillin, o~ and prod~cinc2 w~ek enaxng wells) for the ~az~;~ ................... 2zig J_6_7 ......... , 19 ...... , ............................................................................ 731 I Street · Marat. hon Oil Company .g ~ent' s address ........ A'h'6'fi'6'k'J{[&'~'-'Kf/f&'k'A ....... 9'9'501' ......... Company ............................................................ .............................................................................................. Si~ned .!__'_;__.:_~Z; ....... ;':f; ...... -.i..-.,:::'._~..~,.?~ .......... Phone ....................... 222_-.f412 ............................................ ¢l¢~e~t's title &¢.g_&ng_.P_k~._t_r..i..c._t.._.O.p..e..r..a..t.i.p..n..s..._Mgr. J4 or ~4 ' No. 33/SW/S5 1-t Moved in nd i~;ge howe~er hidra:e~ k alcohol ilto ~lc.w obtai~ st~bil .z¢.d D*vs P~ODUC~D BARRELS OF OIL - to!al depth, ~ up !est e~uipr ept f~rming in GRAVITY CU. FT. OF GAS (In thousands) BARRELS OF %VATER (If none, so state) PBTD 8,417' MD mnt. I Attempted :he cloke body. line lo allevia:e hy!rates. A1 flow. ~ate becaute of hydrates. ,. GALLONS OF GASOLINE i~ECOVERED to rune Rigged :ohol pun pen flow ip alcoho !p broke REC JUL !DIVISION of REMARKS (If drilliag, depth; if shut dowa, cause; date and result of test for gasoline content of gas) potential test, pump and pumped town. Unable to EIV. ED MINES & MINEP, A~ IC.,HOi~GE NoT~..--There were ...... .no ............................ runs or sales of oil; ............. no_ ........................... M cu. ft. of gas sold; .............................. 33.0 ........... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.--l%eport on this forxH is required for each calendar month, regardless of the status of operations, and must be flied in duplicate wi~h ~he supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Forna 9-329 ($anuary 1950) 16--26766-9 u.s. GOWRS~4£.'r I'alsT~sa o~lc~ Form 9-331 (May 1963) P'~TED STATES sU~mT z~ ~c,T~.. (Other instruc' ~on re- DEPAR'J'[ ,'T OF THE INTERIOR verse~iae) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a di~erent reservoir. Use "APPLICATION FOR PERMITm' for such proposals.) OIL ~ CAS ~] WELL WELL OTHER 2. NAME OF OPERATOR Marathon 0il Company Form approved. lSu(lget 5. LEASE DESIG,~ATION A-028083 IF. INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AOREEMENT NAblE ___~_a_yer Creek Unit 8. FARSl OR LEASE NAME (Operator) Beaver Creek Unit ADDRESS OF OPERATOR 9. WELL NO. 731 I Street, Anchorage, Alaska 99501 1-A 4. LOCATION OF V~'ELL (Report location.clearly and in accordance with any State requirements.* See also space 17 below.) At surface 116.9' from south line and 1,338.1' from east line, Section 33, TTN, R10~., S.Ho,surface location. Bottom hole location - 1.003' from south line, 1,966' from west line, Section 34, T7N, ~ow S .M. 14. -/,~ff,qi~* NO. (State 67-9) 15. ELEVA~ONS (Show whether DF, ET, OR, etc.) 138' GR 10. FIELD AND POOL~ OR WILDCAT Wi ldcat SEC., T., R., M., OR BLK. AND SURVEY OR AREA . . .sec. 3'3, T7N, R10W, SM ~2. COUNT~ o~ PaaISaI :tR. ST~T~ ~ Kenai Boro I Alaska 16. Check Appropriate Box To Indicate Nature of Notice, RepOrt, or Other Data NOTICE OIP INTENTION TO: TEST WATER SHUT-OF~ ~'~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) New Farm or Lease Name SUBSEQUENT REPORT O WATER SHUT-OFI? REPAIRING WELL FRACTURE TREATMENT ALTERING cAsING SmOOT~NG OR ACWIZING A~ANDONME~T* ,. (Other) ~" NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PnOPOSEO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent' dates, including estimated date 'of starting any proposed work. If well is directionally drille~ give subsurface locations and measured and true vertical depths, for all markers and zone~ perti- nenl; to this work.) * :¢: ' . , ' :;' "., ;.~ ~ ~: [2 '- ' ' ...... ".'.. ~C.' 18. I hereby certify that the foregoing is true and correct (This space for Federal or StateS.ce use} APPROVED BY '3 ' TITLE Actg. Dist Operations M~r:,'"" '. 7/19/67 · '_' _, ~.' , DATE - CONDITIONS OF APPROVAL, IP AN~: *See Instructions on Reverse Side JUL 2 0.1967 DIVISION OF MINES & MINEEAI~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY l%rm approved. Bud~e~ Bureau No. 42-R3~$.~. LAND OFFICE ..... _ _An.c. h_o_ _r__a_ g_e. ...... :._.. LEASE NuM.E. _._A.-..0_2_8..0__8_3 ............. U~IT ............. ~_ .e. _a. ~.e..r...C..r_ .e_ .e_.k.. .... LESSEE'$ MONTHLY REPORT 'OF OPERATIONS t/vi... State ........ Alas~ ............. Coz~nty ....... tienai ...................Field .......Wildcat_Well .................................... Tl~e follozvi~ is a correct report of operatio-~s a~d prod~otioz~ (i~cl~din, g drilli~ a'~d prod~ci~ wells) for thew~e~e~k*~n~ing 7/12167 "' 19 ...... , .,~.~.m~ .~.Fa ................. ~ ..... ~ .................. ~ ~- ........................................................................... Jge~t's address ........ 7..3..1....I.._.S..t..r..e_.e..t.. ................................ ].. Comvanu Marathon Oil Co._m~a~I r -' ......... 7 ....r .............................. ~7' ......... · ,-:/ ,-. · 9.~/:' ,.. -f,: .... (t . Anchorage, Alaska 99501 SiZzled ......... d:>...:>: .... :...J:L::-."...:.~.:.".::'::::-.:~:v ...... ....... : .... : ........... ........................................... SEC.~oF~AND.t.~TWP' RANGE 33/SW/SE '10W Dept~ - ,29~ Dis' 5 30 O, on 1 .$ MCFD a st, MCFD, Left and WELL D~YS NO. Paonoemn 1-A BARRELS OF OIL GRAVITY , . Cu. FT. OF GAS (In thousands) (]ALLON$ O~ (}ASOLINE RECOVERED BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; if shut down, cause; date and result of teat for content of :al depth, PBTD 8,417' ~iD and in am~ular space betw~ . Set. BakeI permanent pressule, ested pack flow. Made ~wo swab ru~s and k~ up. FlSwed ~ell for 30~minutes pressur~ of ~,700 psi a,~ a calct , fluid. C6ange~ choke to ~/4" and tu~ing.pressi~re o~ 1,900 psiI at a ca; not fluid. S!~ut w~ll in and ~urface iggled~ down dr: llin~ equipment and mcr in test lequipment o ru~ potential test. 7" 4asing perf, rmat~on~ 5,430-5,445', hroue 3-1/2" O tubing. ~.en tubi~ and ca drillab!e'~' hydrau ~r with ,500 psi .cked wel through [lated fl flowed w .culated ~ressure ~.d off lc ;ell comp ,490-5,~ sing with fresh lic packer at on casing for 1 off. Flowed well 1/2" choke with ow rate of 10,650 ell for 30 minutes with flow rate of 2,800 remained at 1,900 psi. cation. Now pre- leted as a single 40', and 5,655-5,675' R!ECEIVED JUL 1 ? 1987'. DIVI$1C~)N OF MINES & MINERA~ ANCHORAGE no no No~m.--There wer~ ......................................runs or s~l~s of off; ............................................. ~ ~u. ft. of gas sold; no ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 16--2G76G-9 u, 8. GOV£1~N#£#T /~alNTIHG OFFIC~ (January 1950) AMERIC&H STR&TIGRAPHIC P.O. BOX 2127 · ANCHORAGE. ALASKA TRANSMITTAL COMPANY 14. 1967 ~'-.3X ~ .. .. Mr. Tom Marshall State of Alaska Mining & Geology Branch Dear Sir: We have transmitted this date via. nersonal delivex-v samples from the: Atlantic Richfield - #1 Trading Bay 450 - 10940 (7 boxes) Marathon - #1-A Beaver Creek 0 - 1O3OO . l~lease acknowledge receipt by returning one copy of ~his transmittal. Re c eipt acknowled ged Very truly yours, onald G. Brockway American Stratigra~hic ., Remarks: MARATHON OIL COMPANy PRODUCTION-UNITED STATES AND CANADA July 14, 1967 RECEIVED 18,1967 DIVI~51ON o.~. MINEs 4, Mlhti~d, 645 "G" STREET , SUITE 201 ANCHORAGE, ALASKA 98501 Mr. Thomas R. Marshall, Jr. Executive Secretary Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Marshall: Enclosed are one copy and one sepia each of the 1"=200' Induction-electric log and the mud log that were run at the Marathon Oil Co. Beaver Creek 1-A well. It will be .... -- ,l,, ,l,, , i 11 11 appreciated if you will ack~°wledge receipt of the logs by signing and returning the attached copy of this letter. Very truly yours William G. Noonan Geologist WGN/ap Encl. ~' Ui COMPANY MARATHON OI L COHPgNY ' O ~ 0 , o. ~ z WELL BEAVER CREEK I g ~ ~ 0 "' - ~ ~ FIELD WILDCAT 'Z - ~ ~ ' ' ~~ m ~ COUNTY KENAI BOROUGH STATE ALASKA · Z. ~ , ~0 ~ [0~110~ 116.9~ ~ & 1338.1~ ~ O~h~r ~ o~ ~ FROM SE CORNER TH, BSL-GR, ~.6~ ~ C~, CST , I Drilling Measured From KB G.L. 138.4 I I Date . 3-22-67 4-19-~7 5-13-67 S-31-67 ~-13_67 Run No. ONE TWO THREE FOUR Depth~Driller 2000 513 0 7720 ' 9702 I 029~ Depth~[ogg~r 2000 5137 6560 9712 8~. to~ Interval 1999 5136. 6 559. 97 1o~ [o~ In,~r~l 52 5 2209 5 i 09 6'200 96~8 ~C. dn~Drill~r 20,, ~ 526 13:~" ~ 2200 ~-~" ~5099 9i~-" ~ 5099 7,, 111 Bit Size 1 2~,-,, 1 2~,. ,, 8~ 8,,, 6,, T~p~ Ruid i. Hol~ g9UgGEL CHEi4 EgUL CHEH EHUL CHEH E;'4UL pH J FluidLols __ J -- mi 9,5 4 mi 10:0 1,2m1' 9,5 3. Sourc~ofSompl~ CIRCULBTED gIR~ULgTED CIRCULATED CIRCULgTED ~ ~~.1~. 5.8~ 52 °F2.95 ~ 56 °F 2 i8 ~64 °~ 2 97~66 Time Since Circ. I HR. 2 HRS. 2 HRS. 7 HRS,, 3 HRS, Max. Rec; Temp. 8 5 OF 100 °F 102 °F 136 OF i 40 Equip'. J'Location. 3502 J ~K 3502 J AK 3502 J. AK 3502 J AK 3502 J ~K R~cqrdedBy, KAUR ' UDELHOVEN UDELHOVEN" KAUR CAT'S , ~ , Witnessed B~ ~ ~ , ~ .~ " ATCHISON ATCHI SO~ ~TCH I SON ATC~I SON LIg~ RECEIVED :' ' 'i ' JUL 18.1 67 i DIVISION OF MINES 8~oO · 8400 . I I'1'i I -. I I 1.1 I.-I llllI,J~ . ~1~1 I~l/l/l~ , 8500. .. ! i r, 8600 8700 , 8800 8900 9000 , 9i00 9200. 9300 ............ i-~,~"o~ .... ~" ~'"~d ' , , I~'I' , ..... I · 9900 ' I0000 I0100 Suiy ?, !,967 Beaver i~eek#l-A Mara~m Oil ~auy, Operator Albert I the above. ~tio~d ~It. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY l~orm aDDroved. Budget Bureau No. 42-R356.5.' LANO OFF'C£ ........ LEA~E NUMBER A-028083 u,,-r ................. :S a,;-z.veZ...C.r~ek. ~ ¥/ LESSEE'S MONTHLY REPORT OF OPERATIONS State ......... Al_.a_.s..k_.a_. ............ County ........ .Z..e..n...a..~_ ................. Field ............W.i..1..4_c._a__t_..U_._e..l_.l. ............................... The followin~ is a correct report of operations arid production (i~cl~din~ drillD~, arid prod~cin~ wee~ ending wells) for the ~eTrM~xe~ ................ 2]_5].6.7 .............. , 19 ...... , ' ~'l ~ent' s address ...... .?.B__l..__I_ ...~.~.r. ge__t. ..................................... Company _..~...r_.a..t..h.p..n....O.~..~....C..g.m.~.a..n. 2] ........... , ....... · % ; /' ?~ ' ,~. !.. ....... ... P h o r~ e ...................... .2..7..2..-._5.~_1_.7. ............................................ .4 ~ e n t ' s title __A._c__t_l~......D_.i..a.~......_OP_.e..r._a..t..i_9_.n..a._.~.n..a. get , , SEC. AND BAItREL~ OF OIL OItAVITY (]ABOLINE WATER (If (If drilling, depth; if shut down, ~ or ~ TwP, RANGE WELL DAYs CU. FT, Or OAfS (]ALLON8 OF BARREL8 or RE~V~ARKS No. PnonuomD (In thousands) dat~ mhd reeult of test for ifmolin, RRCOYmRED l/one, 9o state) ,out,ut of aM) . tAW/AR ?N 10~ lA Depth - 10,2961' I~D- total depth - PBTD - 8,~17' I~D Schlu,~berger p,~.rfo:'ated ?" casing at 5.,~30-/45'. ~'an and s,*.t retri~vable bridge plug at ~,~,65'. We~t. i~ hol~ with Howco res' tools to test per:is at ~,~0-~'. Set test packe~ at 5,/41:!'. Op-n~d tes~ tool and flowed well to pit Well flowed 7,800 MCF per d~y throug]~ 1/:'," choke. Produced n, water. ~ulled ou~: of hole with test tools. Went ~.n hole w:~th ~'etri~ving tool and 1,~tched on ~o retrie, rable bridge plug and oulle¢ out of m'le Schlumberger 3et H,,wco DC cast iron b::id~e vl~g on wire line at ~,~.00'. $c]~lum~,erger ~erfarated ?" :asing at 5,300-10' Went in hole with Howco test ~:ools and set oacker at 5,259'.. 0 ,ened test tools an,i well f~iled to flow. Left t:ool open 2-1,'2 hours. No .as or ,rater to surface'. ?,lled out of hole with test l'.ool and ~eco~,ered water cushion, :athole mud, format:kon water and sand. Went J.n hole wkth I[owco DC Cement ~etai~ter on tubing and s~:t at 5,177' to squeeze perfs at 5,300.-10' Broke formation do~m at 2,800 psi. Mikxed and pumped 125 sacks of Cl~;ss C cem.~.nt. Pumped 107 sac.~s of cement into formatlkon and left 18 sacks in casin~. Final maxd.mum pressure - 5,000 psi. WOC 24 hours Went d.n hole w:[th t,it and drilled :emen~ retainer at 5,177 . Drilled firm cement from .~ ,191' to 5,3].0'. Tested squeezed perfs at 5,300-10' with 1,200 psi. Held OK. Drill~;d cast il,on t,ridge plug at 5,400' and cleaned out to 8,023'. Ran 3-1/2" OD S.L.t.ubing an~t Baa;er permanent dr~llabl.e hydraulic packer Landed packer at 5,375'. Now d~.splactng mud with treated fresh w~tter. . , , ** ** t ~ 33 No?~a.--There were .......... JXO ........................ runs or sales of oil; .............. l'lfl ........................... M cu. ft. of gas sold; .......................... ..11.9. .............. runs or sales of gasoline during the month. (Write "no" where applicable.) No?~,.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the suoeeeding month, unless otherwise directed by tJ~~,.t~trj ,~.~ ~ X~ 9-329 (Jintmry 1950) I f I o4r~ict MARATHON OIL COMPANY July $, 1967 NOTE - We are sending you a corrected copy of our Sundry Notice dated 7/3/67 because o~ an error in the depth footage on the third interval of sand tested (first line of second paraEraph)' Please destroy the · copy sent you on'J.vly 3 and replace it with this corrected copy. A1 Hechler, Jr. Acting District Operations Hgr, RECEIVED JUL Cll¥1,SlOI~I OF MINES & MINERA~ ANCHORAGE; ,~ ~ ,t- ~.~ Form 9-~31 t 1963) } %.... ~ .,.- : '-': ...... --~- SUNDRY NOTICES AND REPORTS ON WELLS . ,. Use "APPLICATION FOR PERMIT--" for such p~po~) ~"N ITED STATES sa~mT (Other lnetr~ DEPART' NT Of THE INTERIOR verseslde) GEOLOGICAL SURVEY (Operator) WELt. WELL OTHER iff '~ ~,,',: :~., ;, ,' ' .. j .i :-.:,L - .": ;:' .' 2. NAME OF OPERATOR 731 I Street, Anchorage, Alaska 99501 4. ~OCATION OF WELL (Report IDeation clearly and iR &eeordRnee with any State gequl~eme-ta.· See also space 17 below.) At surfa~ 116.9' from south line and 1,338.1' from east line Form approved. .'/i-. Budget Bureau No, 42-R1424, ~ 5. L~ASE DESi0NATiON AND SnaLJr, 110. '~'" :~. A-028083 [.UNIT AOREnMENT NAME, ., ,, . , Section 33, T7N, R10W, S,M, 14. X'RaM~T NO. 15. BI,BVATIONO (Show whether DF, eT, OB, e~.) 138' GR 8. FARM OR LEAfJE NAME - , -. Beavdr Cr~k · 9..WELL NO. '. ,.'. ' .. .. ,, ,, :: · -:_ ._i-A .:: 10. FIELD AND POOL; 0E WILDCAT :' ':;'( :;' 11. BEC., T., a., M,, OR BLE. AND Check Appropriate Box To Indicate Nature of Notice, Rep rt, or Other". Data NOTICE OF INTENTION TO: · FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDI~E ABANDON· REPAIR WELL CHANGE PLANR (Other) Proposed completion program WATER SHUTOFF FRACTURE TReATMeNT 8H~TINO OR ACIDIZINO "' ~' ABAN~NMENT~ (Other) ' . · ... ,~ Com~etion or Reeompletion Report and !-; : '- 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent'dates, Including estimated date 0f starting any :', '[::.,/"" proposed work. If weU Is directlonaU~ drffied, five subsurface locations ~ud meamJred and true vertical depths for nil markers' and ~ones ~er~l- , .._...'. nent to this work.) * ,. ,. . .. r' :, ~,,' :~ ' ~ ,-~:. , - :.. ' .~ - -. , ,.~ ~:, . .- :,: A leas sand was'tested at 8,956-76~ and found productive. ~fter testing this z0ne:,:".a':~agnestu=.:i: ~,..h~ ' ' . .. ~, .:- bridge plug was sec at 8,689~ and a 90~ cement plug placed on top of the'bridge plug~: :The gas' sand at 8,525-61' was found to be water productive. This zone was :aqueeZed of~- with '.100 .... i.- of cement through a retainer set at 8,417'. :':'°:: !::':," ?" ;:.' ~::::: "~'~--7 ~-.:-' ~e following three inCe~als of sands were tested at 5,430-45', 5,540-5,490',::and ~ .'~ "%>~and found to be productive. ~e initial plans were to dually complete' this well." ~orough '~'.~ ~: this well. Special ~as tree equipment would require two to three weeks, delivery time. ;'-, Furthermore, the 7" casing places limitations on the two sizes of tub,lng thac Could, be run '.. '¥. ', ' '"( this well was dualed. ~e are also of the opinion that the deviated hole could;:cause .severe <-..?~~echan~cal problems in running dual equip~ent. ~e zon~ ag 8,956-76~:Wtll"be penetrated in .... ~ell ~2 which w~ll be ~ ~tr~ght hole. If th~ ~and ~ found to be produe~ver~n ~eII ~:, . . . .;...~. ts no~ p~oposed ~o a~CempC .a comple~ton tn ~e11 '#2 ~ is pgopo~ed ~o singly com- ' Jones:: ::':''~ '.:'::~he ge ~ o ~e -[:.:::~e folio, trig compleCto, pgocedu~es a~e ~ubmtcCed: (1) D~tll ceme, Cf:tetat~e=?acS,'177'~ ~d ' ' · ' ' :' ' '~ .... cement across perfora~ions a~ 5,~00-10' (2) Dr~l~ bridge p~uS a~ 5)400'}.and:~clean ouc go":~ -.- PB~ 8,617' (3) R~ Baker S-2 pemanent drillable hydraulic packer::;on' 3,1/2" OD' Amco ' ,5?:. Sealock tubing. (1) Install 5,000 psi ~as tree. (5) Displace mud::~t~h'.'Cregted:iresh "::'::<"": · . ,a,er. (6) Set hydraulic packer a, approxt.ately 5,360'. (7) FloK~vel!'?'O',clean''up''''' "" ~d (:/('~. :~:: .conduct k-point open flo~ potential test . :: .. ~:~., ,~:~ ,:'., ..... ,, ~...,, '" ::::::::::::::::::::::::: .'~ , , · · · :': :, ~:~;: :' ~,~ ;,' .:,.. : ... ,:; ,:.:::?:/.. - , ~, ... . - .... ~ ~ ~'~i ~ ~'~ ~ ~Actg. Dist. Operations Hgr..:'~:.: ~:7/3/67 , , , ', _ _ _: , ~ .: , ....,, ...... ;~. ,,.,~:,, ::'[: '~.-,'/ . .. , .., . . : .. . '., ,, , . ~k~ .~ ~'~ · . ,...::,: . -.' ~_ :":'-. · · ' '-.,: '.'' . '~;~ r~ ' ~ ~.'.~;:,~ , ~ :' , :~ :. .."..'" ,' .'.-.:..' ',.'. .. ' .. . .': : ." '-.. g ~;~1t1~'6 ~' ' . -'.- ,,'-: :..,.. . . i /ANi~V~.P, CREF. K WI!iLL ~i-A ~ORRECTED COPY Schematic Drawing Showing previous work and completion plan 5,000 psi xmas tree production casin$ Sealo~:k tubini;, 3-~/2" OD, H-80b 9,20#/ft, · · 5,300-10' squeezed W/125 sacks of cement 'Baker Nodel S-2 packer-' Approxina~ely 5,360" · . :. , ~ ~..,; , ~ · ,' .... "::'~" ..... -" :' ; :"' · ,: ': '.'~'/',':'(' '"i'.', :'7 " ' ' · . - ".--'~..,,L ?":.~,. :. '-.,'?.". ,. ..," "i' ;,,'...,:,:.'.:;'.. '... '.. ;". I - . 8,417" Gasc iron cement retainer - 8,526-61" water and gas on DST squeezed w/100 sacks cement, - . 80 sacks pumped into formation .and 20 sacks lefi: in. 7" .casing, · i - ". i' i ' '' '~'. .~6.,,. ' . '"' ''r. ' ,. ·' .~, ' ' ,:., '"~ ~ ' -, ..... , ~.. .. . ! . · ~ .- ~., ., . . .. ~. : . ,- ,, ....,,, ~ ..... .. '..,~ ,.. - . ,., ,. .,.,. . , ., ., . . . ,.. ',,...~ =: ' ECE = "' 'R': ':IVED. -- 8,797* ' '" ,. ' -: 8~956-76" .DIV~ION',OF MINES & MINE~ ~" 9 023 To off cement I e~rievable b~idge plug cemeu~ ou ~op 0f .. ,. -,. -. 8,599.' Top of cement pi. us Form 9-331 (May 19§3) U"'~TED STATES (Other instruct' ,T OF THE INTERIOR verse side) ~/~ Form approved. Budget Bureau No. 42-R1424. DEPARTF~ GEOLOGICAL SURVEY SUBMIT IN 8. LSASE DESIGNATION AND fJBILIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dit~erent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) !On re- TRIBE NAME A-028O83 INDIAN, ALLOTTEE OR 1. 7. UNIT AGREEMENT NAME 2. NAME OF OPERATOR Marathon 0il Company (Operator) 8. FARM OR LEASE NAME. ,. Beaver Creek 9. WELL NO. ~i- ' 10.. FIEZ,D AN~ POOL, °a WILDCAT ' SURVEY OR ~A Sec. 33, T7N, ~0W, S.M. ADDRESS OO OPERATOR 731 I Street, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 116,9' from south line and 1,338,1' from east line Section 33, TTN, R10W, S.M. ELEVATIONS (Show whether DF, aT, OR, etc.) 138' Ga Check Appropriate Box To Indicate Nature o[ Notice, Report, or other D~ta 14. PERMIT NO, suBsEqUENT 'an~0a~ op: , WATER SHUT-OF~ -): C! ¥ [!. aEPAIR. ING WELL FRACTURE TREATMENT AL'ERI~G CASING SHOOTING OR ACIDIZING ABANDONMENTs. (Other) DST and .squeeze ' NoTE: Report results of multiple completion on' Well ompletion or Recompletion Report and Log form.) NOTICE OF INTENTION T~): FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) 16. 18. I hereby certify tilat the foregoing is true and correct 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If we~i ~ directionally drtlle~L five subsurface iocaiions ~nd measured and true vertical depths ,for all markers and sones perti- nent to this work.) * ...... ' ' The gas sands at 5,655:75', f,490-5,510' and 5,430-45' were tested and found ,to be gas productive. Set cast iron bridge plug on wire line at $~400~.!::('!ES ~,,~asure.ment). Schlumberger perforated 5,300-10'. Left tool open 2.-1/2 hour~. :..:NO} gas Had steady weak blo~ - decreased to very weak blo~ at end of :.test;.['/!ii ~'. Pulled out of hole and recovered 6 stds of water cushion, 5 stds':iof' rathole:mud, 32 stds of formation water and 6 stds of formation sand. Obtained '.,water~ samples to be analyzed for future log interpretation data. Set ltowco cast iron cement retainer on tubing at 5,177' to squeeze .perforation]i: 5,300-10~. Broke formation down with 2,800 psi pump pressure, i?.Mixed and Pumped 125 sacks of Class C cement, Pumped 107' sacks of cement into formation iand Lle.~ ~ow drilling ~..;on.i~ cement retainer· Planning to drill retainer :and :cement. and:test perforations ,000 squeeze *See Instructions on Reverse Side '. (This space for Federal or SMte ofllco use) CONDI~IONSl OF~AP~ibf~ IF Alq~: '~"' · "~Z4 ~,'.: ,~ .'-.' 5 DIVISION Of: ;MINES & MINEilA~ ~NcHORAGE ' UNITED STATES DEPARTMENT oF THE INTERIOR GEOLOGICAL SURVEY Form aporoved. Budget Bureau No. 42-R855.$. L,.00 ,CE ...... ......... LEASE NUMBER ....A~8~.~ ........... LESSEE'S MONTHLY REPORT OF OPERATIOI 0N 30.1967 DIVISION OF MINES & MINERALS ,S'tote ....... __A__l__a__s_k___a_ .............. Co~ty ....... Ke._n a i ................... Field ............ N:l. ld~ar...N~ll .... /~.,Ho~ ......... The followir~ is a correct report of operations a~d prod~ctio~ (incl~di~ drilli~ a~d prod~cir,~ w~e~ee~e~n~ing A/~/~7 ........................................................................... wells) for tl~e ................. .,_......,- ................. , 19 ...... , .4~e~t's address ....... _7. _3_1. _. _I. _. _S_ .t_ .r..e_.e..t. .................................... Company ..... . ..M~_..r..a. _t. _h_ .o..n... _0..t..1....C. _o..m2..a..n~, ............... ................................. ..... .......... ....... ........ Phone ......................272--5417--.- .......................................... /l~e~t' s title Cu. F?. o~ GAs SEC. AND BARRELS Or OIL ~ o~ ~ (In thou~ndz) Depth Attemp bridg trieve tubing went Worked and was of hol~ RTTS pi 9,100 produc, Pulled Sch and 1/,' ,op of dril casing SchlUmberger r Pe] at ~, 526-61 ', 150 peri1,000. MCF thru 1 a f~owing tools. Went i~ hol 8,689-1,599 drillat lec 8,526-( 1' w cement into Schlumt erge at 5,63 3' t tubing pres tools. Schlum~erge at 5,6q0'. set at{5,45 surfac1. pre wi' · st th for pe te ~ure : pc: Wen' ;sur~ et level ~ron ~00 ~ ~att( rfor ~t p of ,30( rfor~ ted inthole ~ell flo~ of[1,90( en eD sed ~ith 6 ceme~ t retainer acks of cement. n and left 20 s tted ~" casing a' !rfs ~t 5,655-75 )si. Well t" casing, with Howco ed at rate psi. Now pro& ,t 5, test of 2 pullJ IGAI~ONS OF (}ASOLINE RECOVERED I 8,417' ~ Backed !off tubil together ~nd pulle~ ~g and latqhed onto to releas~ drillab of perfs ~t'8,797-. the above a flowing :get ran du bridge plu set magnes ~t packer a Gas rat ,ssure of 5 ~potted 90 :ement. P~ and s pressu ~f cement i5-5,675'. ~11 flowed ~ced only d interval: tubing p: mp baile g at 9,0. ium dril. t 8,494' e calcul, O0 psi. cement lied out let at re 5,000 nside 7" Ran tes~ at 8,150 ry gas.' BARRELS OF none, ~o ~tate) mg while i out of retriew Le bridge 3,817 ' ar, . Flow 'essure c and dun 33'. Cai Lable of hole ~17'. S( psi. P< casing. REMARKS (I! drUl~g, depth; ff abut down, d~t~ smd rm~ult of te~t for gasoline content 04 attempting to re- -. hole with test tools· ,ble bridge plug. .- : plug. Pulled out ,d 8,956-76'. Set rate stabilized at .f 1,725 psi. Well tped two sacks of cemen .culated fill in 7" .dEe plug at 8,689'. Well ~:roduced an estimated: ~ted at ~,700 MCF per day Pulled ~ut of hole with test . ~lug on ~op of bridge plug from and ran Howco ueezed perfs at ,mped 80 sacks of Pulled out of hole. tools t MCF per Pulled c ~90-40'. Rmn and s~t retrie tools to t~st perfs at 5,4t ,900 MCF pe[r day th.tu a 1/4" n hole and set packer day, ~tt~ a.flowing ut of hole with test vable bridge plug 0-40' with packer choke with a flowing OlS. NoTm.--There were .......... .~..o.. ....................... runs or sales of oil; ............. ..~..o. ........................... M cu. ft. of gas sold; ................ no ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~..--Report on this form is required for each calendar month, regardless of the status of operations, and mus~ be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise direoted by the supervisor. Forl/x 9-329 "~ ' ' ' 1~e--2570~"~ U. I. GOVEIINI4ENT FRINTING filL'ICg (Jammry i950). Form - "i;' :~ ,-:-:*'"- -': i::, '" Budget Bureau No. 4~--R366.5. ' ' ':'?'~)~.:[;_.~ UNITED STATES '<:'~" ~omcz ...... ~chorage .......... : DEPARTMENT OF THE INTERIOR ~ .uM~. .... ~Q2~083 ............ .~ GEOLOGICAL SURVEY u,~z..~ ........... ' :. . LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska' ' ~o~y Kenat Fie~ ~LldcaC Well. - .................................................................................................................... address '731 I S~reec ' ~omp~y ~rathon 0tl ~mpany . ' ~chorage, ~aska 99501 ............. . .................. ..................................... ....... ~ ~, · cctng District Operations ~ ~ ~ ~ZA ...................................................... . SEC. A~ OU. F?. OF OAS GASOLINE WATER (H (If drU~, d~: ~ ohu~ down, ~ OF ~ ~F. ~ANGE' WE~ D&Yo ; OALLON8 OF ~ARBE~ or REMARKS NO. PBODVOBD BARRB~ OF O~ OaA~g (~ tho~) ~ECOVERED none, ~ state) ~u ~d muir ~ ~t for , . ..... ' ~t ~ /S~/SE: 7N ...10~ lA . . . ...[~.. . pth ~ ].0,296, ~) - oral depth- PR'rD - ~ ,617' ..~." '~ T open hole sec:ion 10,296 co 9,69~ with packer sec at 9,.~80' Op~n~tool'and packer tled. Pulled o~t mid**redressed padcer. ~Reset packer at 9,,i30' to teat the same open le tnt~ai. O~ene~ coo] for 5' minutes. A, nd had strong blow i~edtately. Took 1 hour ut-ih ~.nd o ~ene. i tel,1 ~'n medium bio ~ t~,.dtaCely tccreastng to stro~.g blow. ~ft en 1-1~'2 hoars. Gal .'Co ~urface tn 1 hour:. Volvo too smal~L Co measure.. Took 2 hour ut-in ~nd.~alle. t out of ~ole', Recovered 2,000' of water cu:~hton ani 1,750' of gas c rathr~!e =ad. .~ .. ce/Veal verbal a~pro~,ai ftom U.S.G.S. to plug open hole sect:Lon. Spotted ti plug -* :ks ~fr~m 10,296 Co 10,1~7', Set' p[ug t~ - 50 sack plug fr, m 9,800) to an eat/mated 530~.* ~ent in wle With. bit and tagged ~ement ac 9,699'. 1~ashed out to ft~ ce~nt 9,705 . Spotted p:ug 13 - 50 sack plug ~rom 9,705' Co an mtt~Ce~ 9,422'. ~OC 12 ars~ ~enC tn h~le ~rtch bit ~d tagged f:.~ cement at 9,617. 7" c~Stng shoe at 9~697 iced 7' casing rich 2,100 pst' fog 3~) ~m~Ces. ' Te~t ok. . ~lumbe~*ger ran~ :oll~rr log and 'cemen~'bon~l log from 9,617' t.~ 5,000', ~ment bond log )wed gcod b~andt:~g f~*om 9,617' to 5,230'. Schlumberger perf,,rated 7' casing with 2 .ho1 ~ foot tn t~e f.~llot~tng tnte~als: ' 9,:.1~' to 9,L04'; 8,9?6' Co 8,956'; and 8,817' t ~97~'. Ran DST 93 Cc test inters1 9'104~ to 9,114' with pa.:ker set at 9,083'. Open ~1 ~ttl weak bl,)~ t~med/ately increasing to strong blow· G~s co sutface for 43 minute ~k i h~ur float Ces~.. ~ell flowed ac a :rate of 40 ~CF per lay with a flowing pressure 13 ps:. ~ulle, i out of bole 'and re:over~d 2,000' cf water :ushton and ~11 amount of ~ c~c ~rachole m~d. ~ent tn hole w/ch te~C packer and retrt,~vable b~ idge plug. Set. Ce ~g ~C !~,033~. an~'pa~ker qC 8,928. ~ST t,. Co test 7"~castng first al 8,956' to 76'. O ~l.and .had strong b~.ow t~edtacely. ~ac~r~ cushion to Surfs :e tn 10 mlnutes and gas ~faCe ~n Z2 ~n~ces, · .~ell"fi°Ved c ~rougl~ .1/2" top choke wi :h a floc,tag cubing p:essur, 1,750~. Calcu~ate~ flo~ rate-'9, ~00 ~:F,.. Pulled out of ~mle. 'V~epartng Co~ teac :f°'ra~!dnn. .. at 8,81.7 to 8,797'. ' ' .. ' ~ ,. · , , .' [ ,. "' ~ ~ ,, ,, ,, DST . < i! ~ hole - ~'- 01: ';. !"-' i cuc ,- : Rece: hour,, ?~"i':'i':i~ i ' per ?'[:: [". 8, i tO( · ~: . TO( , .:. gas . [ cool ~ no no . ! ! ~ No?~..mThere were ...................................... runs or sales of oil; ............................................. M cu. ft. of gea sold; *' ! --.J-.' ............. Gg_.: .................... runs or sales of gasoline during the month. (Write "no" where applicable.) !:"i. i i . No?E.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in i.-!!(. !- - duplicate wi~h ~he supervisor by the 6th of the suooeedin~ month,, unless otherw/~e direo,ed by ,he supervisor. D ~"~ ~ / ~/ E ~V/c~ , Fonu, 9-33! ~ (Mny 1968) )~.TED STATES sVBmT (Other instruetio] ~ re- DEPARTI ;IT OF THE INTERIORverse elde.) ' GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plu~ back to a different r~servolr. Use "APPLICATION FOR PERMIT--" for such proposals,) OIr. D OAS ~--~ 2. NAMB aP OPERATOR. Marathon 0il ComPany ~DDRBBS OF OPERATOR 731 I Stredt, Anchorage, Alaska 99501 LOCATION OF WELL (Report location clearly .and in accordance with any State requirements.$ See also space 17 below.) At surface 116.9' from S. line and 1,338.1' from E. line Secl;ion 33, T7N, R10W, S.H. Form approved. Budget Bureau No. 42-R1424. 5. LmAS~ DESIGNATION AND SERIAL NO. A-028083 ~ ~:I~IN'D~AN. ~LL0~R 0R TaIBE ~-'~ ,7 ,- '.~ ....~' ~ "8.~ARM~ 0R ~il[: NAMB ~ ~ ~k ~ea~er :~ Cre~k ,, ,, .. , .. ,., ~i S~e., ~., a., ~j, Oa aLE. ~. XSec:i' 33.'¢ T7N.;%~0~, S.H. ' ' I 138' (IR [:I(enai i.~ ".,~:i, Alaska .. · .:: ,i; -._ 'i ? ~i. I;; .... ze. Ch~k Appropriate Box To Indicate Nature o~ Notice, raAc~a~ TR2AT [ [ MULTIPL~ COMPI,~TI [ ] ' (other~ ' Plug Back ~[ (~o~: ae~rt {e~ o~ d~tlWe ~mp~uoh"0ns w~ ' ' I I Comple~on o~ R.eeomple~on~ Re~rt and ~g fom~) 1i, ~lse~mi P~o~s~ oa col~ o~l~t~o~s (Ole~rl~ ~tat~ all ~rtl~nt pro~ ~orL Il ~ i l~o~ dill ~lv~ i~ l~ons ad ~e~m~r~ l~d t~ wrtt~ dePthi~Ior all ~i~k~ri ~ Io~ ~r~- nenC to this work.) * " ' ' ', ~ ,c u ;-: '.i ...... " The well was drilled ~o 10,296' and logged. Hud log analyses i, ndicac~d t _h~, ttthe¥'proJected sand had been penetrated. Therefore, the projected depth was ~ha6ged:~:from;10,600,' i,'.1'~:) to 10,296' wasHD* The openstemhOle section was loggedto non-commercial.fram 10,296' to ~,697':,:.~ ~-: ~..~ The ~°pe~'.h~leL.. ., section drill tested and found be iRece!ved' v6rb.al "approval from the U.S.G.S. to plug open hole section on June 17, 1967. ij'?Pi~,e~-~i:the;'f611owtng cement lu s: ~ =; ~' .~ ,-'- ~" Plug #1 - 25 sacks from 10,296' to 10,147'. Left 14~ mud grom=10:,&47','Sto ~,8002!~.between ,,.,,,._ , - ..,,-,., ,o,., ,.,,0.,. " : '.- · .',' Plug ~3 ' 50 sacks from 9,705 Co an es~imaCed CoP aC 9,422 . ~;~n~ole, ~'~gged fi~ cement ac-9,617'. Bottom of 7" casing shoe aC 9,~',~./~ ~' ~ ~ ~-~-'~ Nov logging and plan to test zones of interest between 8 and 9,0O~i'~ ~'~' ~ · , ,' ' · ' , ~_o ~ ~, ~ SXO=D ~~ ~~. ~ TZ~Ct,, Dist. Operations M~r.,~'::;'-i~!.,, 6[20/67 k _ · '- ~'._'.~' 4 :~ ;.';, ,/.~'~ ." ~ ~ ~ ~, ,': ,,=, ~, ,.: ~ . ~'. RECEIVED JUN DIVISION OF MINES & MINERAL~ ANCHORAGE UNITED STATES DEPARTMENT OF THE INTERIOR · . GEOLOGICAL SURVEY* ~ MONTHLY REPORT OF OPERATIONS' :. . Kenat BoroUgh - . ~Itldca'~ Well ."' Oo~n~ff'. ......: .......... : ...... ~ .... ::. .... Field operatlon~ and prod~otion (tneludind drilli~d ami produ, olnd ..&/.1hi62 ....... ...~ulgA .... , ............ : .... , ................... ..- ............. · ' ' "' Narathon 011 Company '.'~ ~ '~r~ r, ' ~ .' NO,;~ ~ . -~,u~ RECOVEaEU none, m~) ~b~d~m~ort~ttor~ho. ~ I ' '~' ' ~ ' "' ' ' ~ ' ' " -~pCh ,' I0.296 ~'"- ~oC~tl depth -.testing:"/::' : ' . - '-.." ',/ · -. ;., .. ,:., '~ . .. ~ .,,.; , ,:..~ "~: :..:. -.-;.:. , . , ,, . .,~- . .... / . · ~t.l!e t :6" hole'~ frba'9,8~t8" 'to 10.,~ 96', · . 'L · L ' ~ ' -"" .'~ - ' ,. · Prep~rtng ~;o..'test o~en"h,)le sectiozis. (1C,,296'. to 9,697') :,' · :' ~-' ' .' ' ' , . ~ . ~ , · . . , . . ., · ? ':' · , · ~viat Lon ;. '~ 9,123 ~rdt'aaCe:'a Nc~rth'. 885 E~tst 3,289..' .~.('.;' ?-'.~-'..~":' ' '-':. ;'.. . :::~'..~. ~:;~"~.,{ ::...:"". ':~ ,. ~ -.' ~- ' . -'.-'. ,;--~,L~ : ~ '-. ~ ' Z: .' ' ' '" ~ ' ' '* " '~? '..' ' ' :% ' .' ; r' ' ' ' ;.. -:/-,.~::.: ~ -..}-.-.- .;.,' ~...?~,;~...~- ' . - r.~{~ /,'.~/;:.. ;_ -~, ' .. ~ ': .-'.'- . ~. :' .;~.:: :f.. ' ." .'~ . .:._ ;. . '.~'~' · "'"' . . ~=.-.,~ .'.- -'' -. ' -..s-t: .-, . ~'z '.--' - I .... ~ ..... .- ,.,.. _'- ,' ..... . c · .¢ , . ':, '..'~ ~ ; .'~"'" ~ ad(th',.~;: '.,~ .x.- :'- 'X,~¢;;~;, '-u *¢: ?: .' :,5 ' - ~ · ,::. · . ."- -; ..; ,~.;-'t':." ;' .' :.' . .' . ~ .'. ,;~... . · ~ ,.,:;?):u ,' '. :-. ,.?-C,<~'c:¥... I '~ :',-,/ {.Ls~.}t -.. . ~ ~ . ..:;'y~.-~ '. .:~{~; R'~2: ' .:' ,.': ?;:(~;4',: .'. ?..?' "-- -..' :' ,'' - u C" ~' . i' ' .' ---.",'""~." '.' ' - . ". · ' :%'.' ~ .:?"' ' ' "h ' " ~: ?~(~i']'~:~?~ ;:~. :[.:;J'? ??.¢~x, ~.... ,.'-:~._ ....... ?~:':~?(?~.: ~h'L-q:~' :~-:~L, ~-;::':2;/c:)/;:'~ :-:';~.~ "~':~:?'b~:" .:: ' }/'. c:b~ ..'~ ~".: ,. ':: '"-' ~ ....:.,, ',....'~:. ':.. ':.. ,...~;:.'~ ,,,: ,.....,1~ :-:: ~,~ ;~.'J'{'~ i ~-: (~':';.'? ?: __. . ~.- O 'i ' . . or sales Of gasoline during the month. (Write "no" whe~ ~ppH~le,) "- month, ~g~dle~?~he s~tus of o~rs~ions,, snd mus~' be flied in ~._~ the 6th "' month, u~e~ o~he~!!:~o~ by the su~rvisor. - .... 'r. '~.'.j f~*"' ':f r_.. :~;: ...... :-: ~- Budlcet;-Bureau Ho. ..,:~f,.~ ~: '.' ~' ~,: ':-'-..J~ ":" ' ' '- .. ~ · UNITED STATES ~,o omc~ ....... ~h~gc ......... ~"~ '' ':: - :::":"" ' ~. DEPARTMENT OF THE INTE~IOR ~,u~.~, ..... ~:~.~.: ......... . .' ~ GEO~OGI~L SURVEY UN. ............... ~~..~... . . ..:(:S~'~e'[..~-~. 'Alaska ' _:~ Kenai · Wildce~ Well Tl~e foHowD~E is a correct re.vt of operations a~d prod'~o'~ion (i~otudg~d d~lli~E and PrecluDing · - ~ ', '~.~en~'s addres~ ~ 731'"~ S~reet .~: . · ~ ...... ~ra~hon 0il Company ':/~,-;.. ~'~.?~:~.:'~ : ~'p one...... ~.L "'272-5417 '... :' .."--~ , .. '::-~- '~:~"/'-~: '; '-~'.i~ : :. '-. " "' - ' . ".' '"!<.~ .' ' ' .~ ':: ': ." ' ':~:~' .::~[;~.~' Ntppl~d. UPIBOP[s a~d teSlted all eqbipme~t such as kill lin~S,' Chok~lineS, blind '/'--' .-).:'~ :;~::~-' .' ra~;,.land .~tp;~ram~ with[ 1.550 psi[ AI~ equipmen,i-ok."' Ral-;emper~,ure survey and' ;~ _ ~;:~ "'.:fOund[t°p ~f Cemen~ behiAd 7" casiAg at i5,100'. ~pC .36 hosts. ~a~ 3-1/2 O9 drill .:'~';-~.;-?":~ ~-.':': pipe ~nd d~ilI$d w~th fSat collar a,d gloat sh"oe./ Testealcasing a,d built mud ~'-. · .:~ ~ ., '- weigh to ~t/ all n before drilli g wi h-float she. Now drilling ahead. ~ '-'~ : 'hreeiconeS'~ d sha~ks dff bi~ at',.~,718, ' Ran mill an milled Junk up, Drilled '~' .:':?:.~:~': ;from ~,yzs?: tol¢,~Js'. ~."' /- .i-".', .- I / - ' '~-';~ -t -'? ~ ~' /' .[il .. : .... ;: -':'-" ' ' ' ' - ] " - ' :. i-', ~ i ' - -' · - ' ": - - ' · i - ' ~" ~ "-"; "' ' i ' [- ' j" ' · t [ - ;'~?.'-.~ . j } ' . - . .- :- . .. .] "' . ~:~ -' :' I t .l · r j'' . . I " '., .... :' ', . / :;~F'.'~ ' -. ' -' -'(~ ~' · I . '.I ~ :'I ' ' ' : I I L,:. ~ ' ' / :~:;_~, ,.. ~....~..],......"'~;'~ ' ' " '"" '""'~ ' " ' "J .:,.?:~ ,"-'' 'l I"' ' ' I ?~:~ '-';-,~, ' . . ':-..(::'~', i :,.-:~":,' .... .'- )~ - ' ' ..' .: . ' '. ~?..:.~ ,., .... . .-,.. s.. . .: , ,, .... ~ ~ i . I:.~.-.... I' ' '~ ' I ':~'?'-:'.."~;' ."-:---. "~,~; '!' I. ':.-. .-'.'. j '- :'- , I .:-,"'. ''l '-' "-~(~:?'.-':'~.' ~ '/: :',l- ' -!- - I .-:.-' ,- ': :':(-?: ~ . ' ! · ';;~l-f~. ..:. :[ ~ ..~'...~...-' .,,.:,-~ ;:. ~ ' , ~ -[..~ : ,. , ~ . . ?1'-,'::: :'-'t ':'-' :: "'" i ':,::' · :LI E.C-.E I V.' E D · · · . JUN 9_1967 i ( L"-': : . : · . ~ .. . ~o~$.--~e~ were'~,--,.=.,Lg.9 ..... L:::~;--..: .... ru~ or ~los of oU;.:" ' '" 'no .:" ' . ~0~ ~O :: " - ' . , ' ' ..,,' ~ ' ' ~" .............. .runs pr.~!es of gasohne dumng ~he mo~th .... {Write no where app~cable.) :' No~.~epo~ on th~ fo~n is ~q~f~::~0r each calendar month, reg~,'6f,:tho stat~ of o~ratlons, and m~t be filed in . ',? duplicate with ~he supervisor by the 6~h. 6~: ~he' succe~i.g month, unles~ o~h~¢i~e' dlmo~d by tho supervisor. - -:' .'. FOrm ~-m~ ' · ~- "· ' "::}"-:-':: :~;-'-.' . - -: .... ; ..... ' .....' ' '~ ' " ' : -' " ' '~' "'/:.":~F .' " ':"'?':"':"?':'/" ~':':~1~ '. · ' "":~:L ?: :.'j } ~'~,.-. :.~ . :~ [' . x:.'~?' . -' ' '. "-'" "7 ' - ..... UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Yorm annroved. ]~udget Bu're~u 1~o. Beaver Creek LESSEE'S. MONTHLY REPORT OF OPERATIONS Alaska Kenai Wildcat Well ~"'":~"T ............. :' ............ Cou, nty .................................... Field ................................................................... . .- Tke followin~-is a °orreot report of opera~ions- and prod~t~on (lnoludin~ drillinff and prod~ofn~ week n ng 5 31 67 ' ;o, ~.~~:.:~ ............. t .... Z ................. , ~o ....... address .... ~:--33.1...~-:~~ ............. -. ,'~ Anchorage' .. ' p p~rzng'[. ~ . .to r n 7 ~a~lng. to 9] 700' Cir~ula,e~ and ~ecti(,n. ~chlu~berge~ ran leg, . rcu a~ing and [conditioning 'a:ed and 'indicate no{ st~ifica~ to 5~280' in. B~aver ~reek Well Lion,[.iscosi~'y !48. '. ~' ' i. Lttoned vid to lo ;. : Strapped out sonic and dip me :er logs from before' running :asing. ~ gas sands~bel~ 5,710' MD., · M cu. ft. of gas s01d '-Coordi - .' N°~-There were .L.,.,rLo. ............... ...,: ......... runs or sales et oil; ............ .13...0.. .......... [,[ ............... ? ~!:'. !: '.::~;::.A'~;L,~ ...................... ~.o. .... runs or sales of gasoline during the month. ,..(Write "noi' where applicable.) ' ~; -'"' No2~n.~--Report on this form is reqli~ed for each calendar month, reg~li~)of the status of operations, and must be filed !-{; '" duplicate ~ith the supervisor by the 6t~!.~t:t~.p su00eeding mon~h, unle~s o~hers~ise dirootod by the ~lllt~i~. ~ ~ · ~ ~ ~,~ ':; . .:.-...~-[:--.::.?:.:~:~ ....- .,::.:,::.. (:'.-::.~ · , - . ,: '::'Fora P-3 : '.. ; ." STATE OF ALASKA s~z~ I~aIP~ICA~;'I · ~ffect~ve: .. . . - 731 ~ S~reec, '~choraRe, Alaska 99501 I~:~;~ :~1-~ ~ ~ :, ~ 116,9'. from south line and 1.,338.1 from east line ' "': .' I 138 CR '. · .. '. :-. '" ChKk Appropriate ~x To Indicate Nature o[ Notice. Re~,. or ~echantcal difficulties due to sctcktna drill pipe and side sulCed in revising the casing and mud program, ~e casing pro~ra~~ic~{~:$h.~ : Application Co ~ill dated 3/3/67 is revised as follows: , .. . . ~t~ . , ~ ,, ~, , .. .'.7 . .-":: · 29 - .. :, N-80 , ,..:,..~. Seal-Lock/ ~ · · .. - - - . .: 'Extreme Line 7 .. .. ~ · 29 . N-S0 . '~-~. gx~re~e Line 7 '. ~': 29 P-Il0 - Extreme Line A 4,1/2",-15.'l~/foot liner will be run and Cemented if co~'rc~ )du~b~ i:~ fa~d ~: below 9,725' ~. Projected ~ i~ 10,600' ~. ~e mud weight ~ained slightly in excess of ll~/galion CO a vertical depth of iaoo } ~ ~ ... , ~- ?:. v.: ,.~. dritl depth of appro~maCely 9,725' .aC which point .'~ 7" .... ;.:, ,., ,::, ,..- ~ '% drtllina fuco ghe suspected gas zone that'S'caused the blowout a{: ~i A temperatUre su~ey and if necessa~ a cement bond log..wtll 5e~( t~: t0~fl!~e~ne. the top of ~he cement and bonding. Should this data. indicate that ,~a'ddft'~o~-a~l ts requtred, then tC ts proposed Co perforate the 7 casing an~ :p~ped,~h ~cementtng ~~~~~~~_ ._t~er ,all gas sgnds~ an~d~ t~e. th~,. t .~,, ~a~ ~o~ the..9-5 I he~eoy ~rt~y ~t :the for~o~ ~ ~e aha eorz~' .. ' ' ·: ' "~ k, ~ '~ g ~i.'~ ' ~ . , .. . . ~, : . , ~ a~ , . ':. ~ ' ~ ~e Ink. oaS on Reve~ Side ,. ,, ... ' . ~Vl~l~ OF MINES i Sundry Notices and Reports on 1;ells 17. Continued pa~e 2 Nay 29, 1967 -~ casing on the primary cementing Job. The mud weight will be increased to approxi- mately 14#/gallon before drilling the 7" casing shoe and ~hile drilling the sus- r· :.Pected gas zone belo~ 9,?25, Five thousand pound blowout preventers and high drill ':equipment rill be used during this operation, !: -'?~ * * * * * ,. Bmi~t Bu~ No. ' UNITED STATES L,~Omc~ .......Anch.orag~ ......... DEPARTMENT OF THE INTERIOR ~ .u.~ ..... &~2~0~3 ........... GEOLOGI~L. SURVEY u~ ............... 'LESSEE'S MONTHLY REPORT.'OF OPERATIONS 731 I Street ~rathon Oil Company · : . ..... ......... D&~ CU. f~. Or Oil i WATBR (If (~ ~nf, ~th: ff shut dowu, none, ~ s~te) ' o~t or ~) ~u~uu.u · ~' ~' ~ ' J ~V~R~D ~ ~d ~Mt of ~t for ,,.%,,-,,,, ,.0',-,.,~,', ':'~..,, ...,,..... .,u,..,-, tered t~ Beaver Creek ~ 11 ~l'at ;~,150-7,100'. ,pounds per galZon~ ~&scosi~y ~.. '. , " ' ' res%'~.d~. -.. ~ , . ' ' ~ 19 30' ~or~h 77, s~, : ~ ' . : . ., . · ,~ -i - - ' ' ' · -- . . . , .. ' - ' ' "' ' . i ¢ ..... '. . - : , ,. % . , :; - · . . .,~. , : . . '.; ] '-, -. :-, .... :::'.:<". I' ' _- . .' ' ~.~ ~ - ' . . .-. · -' ' ' "' ?. t' · : '. ,'.' , ~[ ' ; · . .. . . .' ...,: - ,, ,., '. .' , . . :. . - : . .. , - . . , ~ · ,. . .,. . · '1::;"'-I,' .: :: '-I'~ ~_:/'.: :'--: ..' ' ' ""-- , ,, ,' ". :' 1 :.;:..' I ,' ";:-:' '" I-. ':::.:-'::,-'..:' ' , '. E 6E-.I,V , . , - ,. % , . . · . . , s . -. , . . , . ~.1" - · ' ' , I ', · '.' : ' - ., "I -', , ' ~ " ¢ . ' ': . .... · [ ~l~ OE MINES.& MINI i"_' iI '. L..L...~..~..':'~.~...!.;.._II..O. ............. runs or sal.es, of gasoline during the month. (Write "no" where applioable.) ' !' :'.,-J. ' NoT--.~Report on this fern is required fb~fJ~eh~calendar month, regardless !6f--{he~tatus of operations, and must be filed in i' '.i. :;!: [~ duplicate with the supervisor by the 6th of the[!'~iq~',~ling month, unless otherwi~g"dir~et;ed by the supervisor. ' ' - ' ; ' ' '' ,' . ,:--:L'¢ .~.¢:, , - . ~(E . - .-.)>'._ii ,.' - :,. .:. '- _ ..,..~...-.:, _ .... .._ ,~ ...... ~. 7~ ........... ~?. :~-:-:.- .:. ' [. ..:~.- ~'' . '. . : :' '~;' -~-/-"[ ' ": -, (' ! UNITED STATES -- L~,, om~...~.~Pff, gg...~ ....... ~ ...... ':/-:*"( ?' : : LESsEE'S MONTHLY'REPORT OF OPERATIONS. : The following ~, a.oorreot report of operations'a~ production (inoluding drillin~ and ~ - ~-' 272-5117 -" ' ' '' " ' · A ' ' % - '' -- ' ~o~e ..... .._. ..................................................... ~ e~ a ~le c~t. Ois~. ~erations H r. (~ tho~) ~ASO~R WATER (~ (If drflll~, ~th: ff ~hu~ down. oau~: ~ECOVRRED none, ~ s~) dst* ~d ~ult ~ t~t f~ g~lluo . oon~nt of , /SW/SE 7N 10W lA . . ..... ~ ) ; : . . . /.',' , , . -~pth - 7, 182 irilJ.ing ~ ead ~ ', ' ' "':'.-: ' · :.. _,,, : f .- · . , ~orke< stuck ~.~sh t,'ipe Ii hourS;' - Unhbl~ to 'free.u'aSh pipe. Reduc~ d ~ud veight ~ro~ 13.5 lo 11.5 P,~undf per gallon.-"' SPotte,[ 50~bbls. mud dtsp,~rsant p~ 11 around bottom of va~h pipe.. ~orl;ed v~sh pipe' 10 hour~. Spotteg 85 bbls o~ live crude oil around bottot of ~ash pip,~.' Jsrred and .~orked drill pipe 33 hour:~. Unable to ~ree rash pipe. Backed )fl frill pipe at_6550. ]'ulled out of hole ~nd le~t 4 Joints of 7-5/8 OD vat h pipe ~ hoi.e. Cbtained.verbal ~tpproval ~zom Hr. L:[nton to plug back and sid~ track lost tbo~Ls. Seht~mberger-'ra~ lES and sonic logs ~rola 6560 t( 5090. ~xed 70. -sacks cement a ~d I~. sacks o~ frac sand ~irith 2~ calcium chl~}ride. I laced plug ~rom 6550 to 6350. Cem, nt ~ place at '10:30 p.m. 5/13/67. ~OC 24 hour,,.. Tagged top o~. plug ~t 6385. Poll shed off Plug t~ 6401~. Set 30,000 pounl veigh: on plug. ~ould not pump offf. ~ent in hole ~ith urbo-dtil] and dri .led arot,nd lost too~. No gas sho~s e~cou~lCered ~hi.le cut:tng 1,ack mud veight-or ~hile .fishing ~or lost tools, .~... ' . .. . - , .-' . ' , Deviation 7,0.19 filet 34' ' 15' N)rth '4 ~ast. ~ VD 6439 Coordinates "N651 E2191, - ~ .: .. -. . ~ud we ight, now 11.I, ~ Viscosit ? 50 :: -, -. "- . '-" ." - . ' . . -, '- , . ~' . , No'ga(' sho ~s ill mu(,, :. · - · ~ . :: ~ · ':':;,' ~'~'":- , .... ' .,. , . . '. ~ . ;- - . · ., - . ,. -,';. . : , , ., ..... .' · :: . -..~ ~ '; '. . :: . , ,. '.)':.: . . ~ . ;'., , - . · / , .. ~ . . . "?~. · '- i '??C;~'T.~:''-,, ;,,,',, ~ - .-- ................ ?------~- ..... ~ ..... . '- ............................. ; ............... g o ; ' i i} :-':;~i?:!:i"':'Lj; .... :.'Z.._ ........... ,..., ......: ....runs or'sales~0f gasoline during the month: ',{Write '/no" where &pplioable.) ;.. ~.~ ~ ~ ' ~'; ao?EimReport on this form is required f. or'~h calendar month, regardleSS'Of, the status of operations, and must be flied tn ii. ?~f~ .:? ';'. !'~:iduPHeate with the superviSor by the 6th of the sUCceeding month, Unless otherwiSe direoted by the sUoervisor. , ' ' , .,' , ':.:.i,', :-....- ,,-,,,-. ,.,..,,-,.,,,.,:..o,,,, ., J Form(May~-~31 i . ED STATES S~B~IT IN '~ TE. 1963) (Other lnstruc re- DEPART[VicNT OF THE JNTER~OR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. ,L.,:,. Budget Bureau IN'o. 42--R142~./}i ~. LEASE DESIGNATION AND SERIAL NO. j~~ A-028083 ~ 6. IF INDIAN, ALLOTTEE Oh TRIBE NAME 1. 7. UNIT AGREEMENT NAME 2. NAME OF OPERATOR 8. FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. ~LL NO. Z0, FIELD A~D POOL. OR ~ILDCA~ LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 14. PERi%IIT NO. I 15. ELEVATIONS (Show whether DF, ET, OR, et~.) 16. 11. SEC., T., R., M., OR BLK. AND SURVEY 'OR AREA 12. COUNTY OR PARISH] 13. STATE Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT RI~PORT OF: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ',~. ~,~ 'I~t~ ~ WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDO, NMENT* OTE: Report results of multiple completion .on Well ompletton or Recompletioh RePort and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and ~neasured and true vertical depths' for al! markers and zones pertt- nen~ to this work.) * ..~tI ~' s~ 517,/~.7 ~l'.l~ .~1:1~ ~ 7,7~*. ~a~ o'~. ~ 7,~t~., 18. I hereby certify ttiat the foregoing is true and correct SIGNED TITLE DATE, ' (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side DATE RECFIv[D I!,,:;AY 17 1967 DIVISION OF MINES & MINE'RAL~ ANCHORAGE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY I~orm approved. Budget Bureau No. 42-R356.5. LAND OFFICE ..... a~hm,,a~e ............ LESSEE'S MONTHLY REPORT OF OPERATIONS ,State .... ~~ ................. County .............. Y~t, .............. Field ......... ttiilzt~t,__14~.l.1. .............................. The followin~ is a correct report o/ operation, s and production (includin~ drillin~ and prod~cin~ wells)/'or the j~__r~__ .......... l~__~ .............. , 19__~, _ ............................................................................. ~l~ent' s address .............. ~__~___~'~ ............................. Company .... ~~..~k._C~~ ............... ........................................ ~I~~~__~_~]~I~ ................... Si6~ed ........ ':___~. ~,j'_ ___ Phone ............................. .~._7~_'_:~7 ....................................... ~l~ent' s title SEC. AND ~or ~4 BARRELS OF OIL GRAVIT3 aaa (DU. FT. OF GAS (In thousands) tJen%. ~ (~ALLONS OF GASOLINE RECOVERED BARRELS Off WATER (If none, so state) REMARKS (If drilling, depth: if shut down, eanse; date and result of test for gaeoliae content of gas) REC, EIVED 1967 703, DIVI$1OI', OF MINE5 & MIt",[ERALS ANCHORAGE No~E.--There were ....... ~ .......................... runs or sales of oil; ................... ~O- ...................... M cu. ft. of gas sold; ........... ~ ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.---Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16.--,25766...9 U.S. GOYERN~ENI' PRIN'i'INC OFFICE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~'orm approved. Budget Bureau No. 42-R356.5. LESSEE'S MONTHLY REPORT OF OPERATIONS The followin6~ is. a coy. reet report of operations and production (inelu, din~ drillin~ and producin~ wells) for the ~~ ................. ~-:~ ............... , 19__~L, JEe~t' s address ............. ~__~._~~ .............................. Company ....... ,~~_~_C~~'. ............. ....................................... .................... ...... .... P~one ............................ J~X~.57~ ....................................... ~ent' , titte ___~~.~~_,__~~_.~ , SEC. AND BARRELS OF OIL ~4or ~4 (~RAVITY Cu. F?. OF GAS (In thousands) (}ALLONS OF GASOLINE RECOVERED BARRELS OF WA~ER (If none, so state) REMARKS (If drilling, depth; if shut down, cause; date and result of test for gasoline content of gas) RE ,;E]VE9 /~,1967 .OIVISION~>fCNCHOgAGEMtNES & MINFI~b~ No~E.--There were ............ .~.~ ..................... runs or sales of oil', _ ........... ~ ............................. M cu. ft. of gas sold; ............... ~ .......................... runs or sales of gasoline during the month. (Write "no" where applicable.) No~r.~Report on this form is required for each calendar month, regardless of the s[atus of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9=329 1(';'~25766-9 U. $. GOV~RilbI£NT PRINTING OFFICE ($anuary 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. LAND OFFICE ................. ;~ .............. LEASE NUMBER .... "-- ..... "-'~_';; _.. _~ "'"~2~; ............ LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a eorreet report of operations and prod~etion (ineludin~ drillin~ and prod~cin~ wells) for t~e ~i3g7 ..................~ ......... ';'-~ .......... , ~--~-, - ........................................................................... ..... ~_:_~ .... J~ent' s address ............ t:~_~_~__~}L~'_~-?-"_~-%J-~? ............................... Company 'd '~ ~ ' · ' ........................................ ~_~.._~_- ~a~,_ ~-~;~ ..................... ~,~a_~ ....... Phone ............................. ,~.~';_..~:~-~ ........................................ ~l~ent' s title Cu. FT. OF GAS SEC. AND BARRELS O~~ OIL ~ or ~ (In thousands) GALLONS OF GASOLINE RECOVERED BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; if shut dowa, cause; date and result of test for g,J~oliue content of gas) R' E IV ED ,' ANC~O~ NebR.--There were .............. ~ .................... runs or sales of oil; ............ ~ .............................. M cu. ft. of gas sold; .............. ~ ..........................runs or sales of gasoline during the month. (Write "no" where applicable.) No~.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16...--25766--9 u. 5. GOV£~NM£NT PRIN'rlNO OFflCl/ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY l~orm approved. Budget Bureau No. 42-R356.5. ~.,~o o~,c~ ....... ..~U___C.~~ ......... ms~ ~u~,~ .... _~r~3 ........... u~,~ ................ ~~__~~___ LESSEE'S MONTHLY REPORT OF OPERATIONS The £ollowin~ is a correct report of operations and prodtectio~ (includin.~ tlrillin.~ and producin~ wells)/'or the~___~.~____X___~ ............... , 19__~_ ............................................................................. /l~ent' s address ....... __~..5_.~__~~ .................................... Company .... ~2'_~_h__9~_____0~__~_~_~7 ................ Si~ned ___~ ................................... .......................... ....... ...... Pno,~e ...................... ~-~1.7 ............................................. ~,. ~t's tiUe Cv. F~. o~ O~s SEC. AND BARRELS OF OIL ~ or ~ (In thousands) GALLONS OF GASOLINE RECOVERED BARRELS OF WA'rER (If none, so state) REMARKS (If drilling, depth; if shut down. cause; date aad result of test for gasoline content o[ gas) No~E.--There were ....... ~ .......................... runs or sales of oil; ............. -~O .............................M cu. ft. of gas sold.; ............... 1~ ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~..--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766'-9 u.S. GO¥£RNM£N? PRIWrlHC OF'FleE above Form 9-331 (May 1963) , . FED STATES (Other instruc DEPARTMENT OF THE INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo.~als to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) '~CATE* o~ r~- Form approved. Budget Bure~u ~o. 42~-R1'~. [~. LEASE DESIGNATIO~T ANI) SERIAL NO, IF. INDIAN, ALLOTTEE 0~ TRIBE NAME _. , , 1. 7. UNIT AGREEMENT NA}II~ , 3. ADDRESS OF OPERATOR LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 14. PERRIIT NO. FARM OR LEASE;NAME 16. 9. WELL NO. ~0. FIELD AND POOL, 0!~ WILDCAT 11. SEC., T., R.) M., OR BL~r. AND I15. Eh~VA~IONS (Show whether DF, RT, GR, etc.) · Check Appropriate Box To ~ndicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: z2.~'iCO'NT' O~ P~IS~[. rS..~~.ST~TE TEST WATER SHUT-OFF FRACTURE TREAT ~IULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SURSE~UE~T WATER SHUT-OFF ., ~ :,: REp~IR~N~ ~.L FRACTURE TREATMENT . ALTERI.~G CASII~G SHOOTING 0" ACIDIZINO ',' (Other) (No~E: Report results of multiple comple~oh o~~Well Completion or Recompletton Report and Log fo~m.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated' da[~ of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths 'for all markers a.md zones perti- nent to this work.) * ,.. ,. ,. , !~,,~, ~,~ ..,.,, ~,,,~.~ ,, ~,,,.,: .,,., ~, ~ '. . ~. . , ...... , , . ~ . , . ~, .; . . .; .. ~ , . ..~ ~. .,~. . , . .. 18. I hereby certify that the foregoing is true and correct (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side f)iVI,StON ~.)F MINL'-'.S & M!ix~ERAt.~ .ANCHORAGE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. Anchorage ...... -~::~808:~ ............. LESSEE'S MONTHLY REPORT OF OPERATIONS The followD~ is ~ correct repor~ o£ operations a~d prod~ctio~ (inchedin~ drillb~ and prod~ecin~ wells) for the ~_~____~.~_.~ ............. , 19__~.7, J~ent' s address ............ ~__~__~~ ...............................Company ....... ~~._~..~~~ ............ Si dried ~ ~_~.~ ....................................... ...................................... . ,- ...................... ~___ ~o~ ............................ ~7_~.5~7 ........................................ ~e~t s t~tze __~g,___~_~$_r_,___~e~_$~aa_.~, SEC. AND ~4o~ ~ 3716' W'.0.C with Surve DAYS Pit ODUOltID Insta Te ~ for ° 30 BARRELS OF OIL l~ed casim astalle~ ~ oted BOP,, 15 minute Started ar: GALLONS OF ; sli~s an~ cut off .casi~ ~!~, ~i~u ~ sp~, ~. ~ OK. Testa pip, ~ ~r~~ at ~5'. BARRELS OF WATE~ (If __ none, so states ~. :Last ~te.rs, 12 ]rJ.3~ 3Au Joint ~ REMARKS (If drilling, depth; if shut down, cause; date and result of test for gasoline content of gas) / O~ tVdi'xlt:$ & M!NEI~L,%L~ ANCHORAGE No?~..--There were ......... ~]~O ........................ runs or sales of oil; ........... J~ .............................. M cu. ft. of gas sold; .............................. _N_.o. ........... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTF,.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 ($anuary 1950) 16--25766-9 U. 5. gOVERNMENT PRINI'INC OFFICE U N ITED STATES SVB~i~ z~ TRr~'¢C*~=' (Other Instructions on re- DEPARTMENT O~.'THE INTERIOR verse side) , . GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS , (Do not use this form for proposals to drill or to deepen or plug back to a dl~erent reservoir. ' Ilse "APP/JOATION FOR PERMIT---" for such proposals.) OIL ~_~ CAS ~] WELL WELL OTI:IER NAME OF OPERATOR- Perm approved. Budget ~ureau ~o. 4~R14~. 5. LEASE DESlO~ATION AND ~E~IA~ NO. 6. ~:!r ~vi*~,. ~LL~=~ ca ~aiam 8. FARM OR LEASE NAME. 9, WELL 1~0..'" ~, ,~,, :. · 10.-fIELD AND Poor-~ OR WILDCAT . I'~,rathon Oi~ Company_. Operator ' · ~,DDREIS-~ OF OPERATOR 6~5 G Street,~chorage, Alaska 9~01 LOCATION O~ WgL~ (Report lo~on &e~ly and tn accordance with any S~ requ~emen~.* See also space 17 below.) At surface '~6.9 fr S ~ne & 1338.1' frE ~ne S33-TN-lOW : . z6. Check Appropriate Box To Indicate Nature of Notice~ RepO~, or Ot ara g ~:, ',' :~ . . - . .:.~ '.~ ;': ,z c. ~ ::~ . ~ '~ ,4 .,. ALTERXNG:C~ING FRACTURE T~AT MULTIPLE COMPLETE FRACTURE T~ATMENT '~ ~ ~ BHOOT OR ACID~E ABANDONs SHOOTINO OR ACk.lNG ~, D '~ ABANDONMENT~ REPAIR WELL CH&NOra ~ANa (Other) .... ... !.: ;~ '-. ~J, ' "' r' (~o~: ~eport resul~ of multiple eomDleUon' (Other) Comple~lon or Recompletion. Report and Log 1~. Dssc~ms z,ao~osgp ca co~[~=~=D o~=a~w~s (Clearly state all pertinent details, and give pertlnen~dates, inel~ing estimated date bl a~Ung proposed work. H w~ ~ ~on~y driU~, give a~a~ace l~ons and m~sured and t~e verti~ depths .for ~1 marker~ and ~oneo ~r~- ~ '3 ~' a ~. '~ :" '? *.~ ~.~ . Mechanica~ ~ff~c~ies necessitates cha~es in the cas~ }~ogr~-~rom tha~ ,- :: proposed on the ~i13~_~ pe~t. Because of t~s casing progr~c'~e;; :0t~r pa~s of the ~i~ng program had to be c~nged. Listed bel~ :ib:~the prOPosed casi~ and c~enti~ progr~. Settina dept~ 2209 M.D. 40,43.5 5100 Size. of hole size of casin~_ zsr /s' 13-3/s -26 & 29 10,603 M.D. Refer to attached for specific details in relation to other 18. I hereby certify that the foregoing is true ~ud correct CONDITIONS OF APPROVAI~ l~ ~: Cementzn~' program.' a .-~ 3500 sacks 'c~ment:~ ~6;1 [Surface ,' ', ..,., - .~ :.i ? 2~00 sacks.' cement, to ,s~ace ooO ooo' *See Instructions on Reverse Side ~i -" w. G .L:'~ APR 10,1967 '~ xdoo ~ ~O~3X ~ RECEIVED /~PR 1 O, 1967 · DIVISION' OF MINES & MINERA~ K.O.P. 2250'V. 0. :5482' 4000' 4800' 6000' 71:55' 7177' 8099' 9100' 9700' V.D. RECEIV[D APR 10,1967 , 250' M.D. = MARATHON OIL COMPANY BEAVER CREEK N~ I-A 2°:50'/I00' BUILDUP , :5550 M.D. . UM ANGLE :5:5~ 2752' . :5:5* 7916':_M,.O. 2778' ' -~ $2~ 7966 M.D. · ~ 2°/100' DROP :5151' 2° 8966' M.D, :5364' ~ 9989' M.D. :5491' ~e 12:~ 10603' M.D. N 73°28'E SCALE I"~1000' IgllVlY DIVISION OF MINES & MINERA~ ANCHORAGE + 4- MARATHON A UNION 1¸7 30 A-028120 --' I UNION,,, 6 S E A'028078 18 32 "-~/M~.^'r.o. UN~O.~ i+ ' /4' i A'06~5'62 · "T-'""'--J STANDARD ~ARATHO N STA NDAR D N ' . 3 3 3~ A' 028 9 85 M AR ATH 0 N ST_AN DARD U N I0 N ATL AN~ ICRI CHFI ELD (D. ~ O. Agree~ + STANDARD R A N G ATLANT;CR~C.F~ EgD ~ A- o28.~ A' 02~ II ~ / c MARA "" 8EA.VER CREEK PROSPECT-; WELL N~ I-A T.6N. '" ~ - Scale: t ". 4, 000' ;.~ RECFt~ ~ APR 1 0,1967 _ ~' DIVISION OF MINES I A~ . _ I ,~028,34 : :-,. . UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5o U.,T ............ ~e.~m, _. _C.~te.e~ ...... LESSEE'S MONTHLY REPORT OF OPERATIONS State .... ;m,~'.,~ .................. Coz~t.y ........... ~ ................. Ffeld ....... Wi%d~a~__W~].l ....................................... The followi~ is a correct report of operations and productio'~.~ (inclu, din~ drillin, o~ and producin5 wells) for t he.~~~.-.-Ilg--- ..... !-~--~'~--~- .............. , 19_.~7, ............................................................................ Z~e~t' s address .............. __~__~___G_.__~__._~__._~__~_ .............................. Company ...... [~thogl_DJ~.~___~ ......... ......................................... _...~.~)~ .................................... Si ~ned __(J~-~ .... :_~.~ .... ~_____ Cu. FT. OF GAS SEC. AND BARRELS OF OIL ~ OF ~ (In thousands) (]ALLONS OF GASOLINE RECOVERED BARRELS OF WA~ER (If none, so state) REMARKS (If drilling, depth; if shut down. cause; (late and result o£ test for gasoline content of gas) ' 6,I967 DIVJISIOJxl Of:ANCHORAGEMINES & MINERAL~ NoTE.--There were ...... ~ ........................... runs or sales of oil; .... ~ ....................... ~ .............. M cu. ft. of gas sold.; ........................ _~ ................ runs or sales of gasoline during the month. (Write "no" where applicable.) No~,E.--Report on ~his form is required for each calendar month, regardless of the status of operations, and mus% be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766-9 IJ. S. GOVERNbI£N'~ PRINTING UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form ~pproved. Budget Bureau No. 42-R356.5. LAND OFFICE ___ ~_.e~_._- .~J~g3_~.. ............. LESSEE'$ MONTHLY REPORT OF OPERATIONS The followin~ i.s a cprrect report of operations and production (inch, dinJ drillin~ and prod~cin~ ...... ~ ~r.:.zlg r -** _ ........................................................................... wells) for the ~ ........... }~areh-28~-&ObT--, 19 ...... , /l~ent's address ..... _~._.':;t__~ ...... ~ ..................................... Company ~{~, 0:~. .................. " ..................... 7-' ..... ................................ _.~..:e__.~.._.or~_.,.~..~:'_~__ ........................... Si ~,~ed ....... : ~ ...... : ..... :: ............ .: ,__:_: ............ ~ ....... Phone ................... ~;-t~:-'.~ ................................................ ~16, e~t' s title __.~__J..~::~.~._~:~.--.:-OD~-.-~-.:._~----~--- -~-'~-'- .... . .... Cu. F~. OF GAS. Src. Am) BAREE~.S or Om (In thousands) ]4 or ~4 33 (JrALLONS OF GASOLINE RECOVERED BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; if shut down, cau~s; date and result o£ test for gasoline content o~ gas) No~E.--T!k~r.e were ...................................... runs or sales of oil; M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NO~rF,.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 16---25766-'9 U. $. GOVERNMENT PRINTI~e OFFICE (~an't]ary 1050) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42.-R356.5o LEASE ............. u~,~ ~aver C~ek ............................................ LESSEE'S MONTHLY REPORT OF OPERATIONS The following.is a correct report of operation, s and prod~ction (i~,clu, dinJ drillD~..(,~ and producin6 wells) ]'or the ~ ............ _.~____~_h___~_ .............. , 19_~..7.__, ............................................................................ /l ~ e n t ' s address ............ _~_ ~_ _ _G__ _ _~_ _$ ?_ _~_ _~_ _t_ ................................. Company ......~_t_ _h_ _o_ .~_ _ _ __~__ _~_ _ _ _C_ _ _q :_ ........................ Anchorage, Alaska Si~ned '* "'" '" "* ..... ................................................................................................... ~'- -~ ................ ~- -- ~ .......... /- -- 7~- .................. ............................ ......................................... s title _~_.Y~_a~,.ql~_.~]~J_.~~.r .......... SEC. AND ~ o~ ~ B.~E~LS O~ OIL Ran hole. collar, casimg and spo~ GRAVITY Cu. FT. OF GAS (In thousands) GALLONS OF GASOLINE RECOVERED BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; if shut down, cause; date and result of test for gasoline content of gas) ,ag. Set ~t ~ 2~ker float ~d 9:15 AM head housing. il and 20'" × fr~m. outlets aute~. ~est OK. ~ted, ~}~?dxil Oame~on e~ ~at float No~E.--There were .......... ~ ......................... runs or sales of oil; .............. ~ .............................. M cu. ft. of gas sold; .............. ' ............ ~ .............. runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the ()th of the succeeding month, unless otherwise directed by 'the supervisor. Form 9-329 (January 1950) 16--25766-9 IJ. $. GOVeRNmENT PRINTING orrlcr,' MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA 645 "G" STREET , SUITE 201 ANCHORAGE, ALASKA 99501 March 22, 1967 Department of Natural Resources Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Thomas R. Marshall, Jr. Re: Drilling Permit No. 67-9 Beaver Creek 1-A Section 33 - T7N, RiOW, SM Gentlemen: In accordance with Section 2060.1 of Alaska Oil and Gas Regulation, the only affected operators in connection with the drilling of Beaver Creek well No. 1-A are the following: Standard Oil Company of California P. O. Box 7-839, Anchorage, Alaska 99501 Atlantic Richfield Co. P. O. Box 360, Anchorage, Alaska 99501 Both of these operators were furnished a copy of Application to Drill by registered letter dated March 15, 1967. For your further informmtion, a copy of said letter is attached hereto, wherein said operators signified that they had no objectionto issuance of the permit. Very truly yours, Morris L. Lowman Area L~ndm~n Encls. cc: R. C. Shelton B. L. Walters ANCidC) RAGE: XdO0, ~ o ~:.e x .i MARATHON OIL COMPANY , PRODUCTION - UNITED STATES AND CANADA 64,5 "G" STREET, SUITE 201 ANOHOI=IAI~E, ,~,LASKA SS501 1967 Sts~ud~rd Oil Company of C~lif. P. O. ~o× ?-839_ ___ A~lication to Drill in ~ccor--dsa~ae' ~,~ith Secti~ 2~O.t(c) of tha ~s!~ Oil ~ud Gas f~zh you a cody of 'Z~p~slic~tion for Pen'~it to ~i~, De.eh, or ~ ?lnd no objections to the dovi~tted ~ Drogr~m~, ~,~i~ you ~eame so ~n~c~a o;~ .tho c~r~n a~y of thi~ lattar~ ~d rat~n~ MARATHON OIL COMPANY ANCHORAGE, ALASKA RECEIVED tW [:L _ ML, ,' , DA ,, ~ILE ..... (,.Jk M~i'qbb c,, ANCHORAGE OW.q× Form 9-331 (~Iay 1963) U N ITED STATES su~iT (Other instructions on DSPARTMENT OF IH5 INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use iL:: form for proposals to ~$:' ~: -: ?o deepen or plug back to a different reservoir. Use "APPLICATIO).T [~'C ~'~.[~hYiIT--" for such propo~ls.) OIL ~ GAS ~ WELL VCELL OTttER 2. NAME OF OPERATOR Marathon Oil Company, Ooerator ADDRESS O~ OPERATOR 645 G Street, AnchoraEe_z Alaska LOCATION OF WELL (Report location clear]F and in accordance with any State requirements.* See also space 17 below.) At surface 116.9' fr S line & 1338.1' fr E line Sec 33-T7N-R!OW Proposed sub-surf loc: i523' fr S line & 3400' fr ~,[ line Sec 34-TTN-RlOW 1~z. PER,%IIT 1~0. ':.? r.'.:*:-,::'::~oNs (Show whether DF, RT, OR, etc.) I ~62 Ri' (est) ]Porto approved. Budget ISu~-mm 1~o. 42-R1424. ~. LEASE DESIGNATION AND SEk%!AL NO. A-0250~$ 6. IF INDIAN, ALLOTTEE OR TRIBE NA~IE · 7. UNIT AGREEMENT NAMI~ FARM[ OR LEASE NAME Beaver C_ eek 9, WELL NO. 1-A ~0. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., ~., OR BLK. AND SURVEY OR AREA Sec 34-TTN-R!OW 12. COUNTY OR PARISH~ 13. STATE "-~ KenaiI Alaska 16. Check Appro~ric~¢~ ~o× To Indicate Nature o~ Notice, Report, or Other Data NOTICE 01~ INTENTION TO: TEST WATER SHUT-Oi.'F ...... ' OR A~TER CASINO SHOOT OR AC/DIZE .-JANDONs REPAIa ¥¢ELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT . ALTERING CASING SHOOTING OR ACXDIZING 3) ' ABANDONNIENT* (Other) '; (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED 0PERATZONS (Clearly state all pertineut details, and give pertinent dates, including estimated date of starting any proposed work. If wel~ is directionally drilled; give subsurface locations and measured 'and true vertical depths for all markers and zones perti- nent to this work.) * : . ' "- . . . · .. Commenced drilling 1:00 Pi'4 3-13-67 18. X hereby certify t,]iat the forc:D61ng L: ,_c and correct TITLE Area Exmt, Supervis or . I 3 . %.?¢. ~-~ ,< / (This space for Fedcral or State office use) APPROVED ICY CONDITIONS OF APPROVAL, IF ANY: TITLE *See lns~ruci'ions on Reverse Side ANCHORAGE ~trch 1.0, 1967 Beaver ~thon 011 ~~ ~:1~ ~he ~tal ~,ths of ~r ~;eek. FORM SA- t B 50M 1/67 MEMORANDUM TO:I- State of Alaska DIVISIOH OF ~S Am) ~ FROM: DATE : SUBJECT: MARATHON OIL COMPANY I°RO[DUCTION-UNITED STATES AN[X) CANAERA IB45 "G" STFtF:ET , SUITF= 201 ANC F.IORAGF=, ALASKA 995~01 Narch 7, 1967 Department of Natural Resources Division of Nines and Minerals 3001 Porcupine Drive Anchorage, Alaska Attn: Mr. Tho~zs R. N~rsh~ll, Jr. Gentlemen: N~rathon Oil Company, as operator, submits herewith in triplicate, for your approval, Application for Permit to Drill Beaver Creek No. 1-A well. We also attach our Check No. 367 in the amount of $50 as filing fee. For your information, we are also enclosing a copy of the application submitted to the U. S. G. S. as well as a copy of Sundry Notices and Reports on wells dated Narch 3, 1967. Very truly yours, NARATHON OIL COMPANY ,~?~ Area Landman Encls. RECEIV[D [ ,AR 8 1 67 OF MiNCS & M~NERAL~ ANCHORAGE Form_P--1 STYE OF ALASKA · OIL AND GAS CONSERVATION COMMITTEE ~' 50-133-20006 SUBMIT IN TI~ 3ATE* Ef£ective: July 1, 1964 (Other instructio~ ~ on reverse slde)~ APPLICATION FOR 'PERMIT TO ~DRILL, ~DEEPEN, OR PLUG BACK la. TYPE OF WORK. , DRILL E ~DEEPEN I--I PLUG BACK [-I b. TYPE OF WELL OIL [] OAS ~-~ SINGLE[] MULTIPLE ~_~ WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR ~larathon 0~1 Canpany, Operator 8. ADDRESS OF OPERATOR 645 "G" street, Anchorage, Alaska 99501 A. LOCATION OF WEL~, (Report loeatlon clearly and in accordance with any State requirements? At surface ~6.9' ~ S L.~e 8o 1,338.1' I~ E L.~e, S.3B-TN-IO~ At proposed prod. zone 1.523.4' fr S Line & 3.400' fr W Lines S.~4-7N-10W 14. DISTANCE IN MILES AND DIRECTION FR~OM NEAREST TOWN OR POST OFFICE 15, 21. 23. 11.5 miles northeast from Kenai, Alaska, postoffice. LOCATION TO NEAREST 5 56 PROPERTY OR LEAEE L,NE. FT. 1, 23.4' 2, 0 (Also to nearest drlg. unit line, if any) DISTANCE FROM PROPOSE, LOCATION' 190,.63' ~. PROPOS,~D DEPT,, TO NEAREST WELL, DRILLING, COMPLETED, 2~ OR A,P--E. ,OR, ON T~,S ~E, .. from Well -~1 15,000' VD E'.~VA~ONS (Show whether DF, RT, GR, et,,:.) 162' R. T. (Estimated) 5. LEASE DESIGNATION AND SERIAL NO A-028083 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME Beaver Creek 9. W~LL NO. 10. FIELD AN~ POOL, OR WILDCAT Wildcat 11. sec., T., U., M., OR BLK. AND SURVEY OR AREA1 Sec. 33, T'7N, R.10W, Seward Meridian 12. B.OROUGH SHI 13. STATE Kenai I Alaska 17. NO. OF ACRES ASSIONED TO THIS WELL 16o 20. ROTARY OR CABLE TOOLS Ro~x7 PROPOSED CASING AND CEMENTING PROGRAM 22. APPROX. DATE WORK WILL STARTs March 10, 1967. 1.5" opened to 16" OD -~ _ 1,800' 22" toI 8. '"72 4,800' ~ opened 13-3/ OD '61, 18" 12" 9-5/8" OD 40,43.5 & 47# 8,8OO' ~. OD 26,29, & 32~ lB,300' 6" * )'-~" oD (Liner)' 15. 15,000' QUANTITY OF CEMEN~ 650 sacks cement to surface) 21OO sacks cement to surface ) 3450 sacks (cement t~ surface) 1650 sacks (cement to 4,000' ) 1000 sacks 200 sacks * 4½" Liner and cement wi~l be required only if commercial production is .~ found in the N~.mlock Zone. Refer to attachment for description of blowout prevention equipment and program. IN ABOVE SPACE omscamE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proPosal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depthS. Give blowout preventer program, if any. 24. I hereby certi~y~at the For[~/?g is Tffe /£ and Correct. (This space for Federal or State o~ce use) PERMIT NO. APPROVAL DATE THOMAS R. MARSHA~,.JR. Executive SecreTary ~' O 7 DATE ,. . , · APPROVED BY V-'"~ ', TITLEAlasko Oil & Gas CONDITIONS O~ APPROVAL, IF : cc: Div, ~nes & ~ne~ss ~che~e ~thon, ~cho~e (1) ~ratb~n, ~s ~eles (1) ~ion 0il Co., ~s ~eles ,(1) U~ Qi! Co~.~ ~cho~ge (1) See I.~m~fio.~ DIVISIOiN OF M~.~S & MINi:.RAk~ ATTACI~WENT BEAVER CREEK NO. 1-A. PROGRAM It is proposed to drill a directional hole which will attempt to very nearly intersect the bore hole of Beaver Creek well No. 1 at a vertical depth of approximately 9,100', then continue on with a directional pattern which would allow intersection of the top o£ the Hemlock Zone at a point 3,400' from the west line and 1,523.4' from the south line of Section 34, at an estimated vertical depth of approximately 13,700'. Bottom hole location at top of Hemlock will be 4,942.5' N 73° 28' E of .surface location of well No. 1-A or 2,190.6' from well No. 1. It is planned to re-enter well No. I which blew out on February 10, 1967 and finally bridged for the last time on February 24, 1967, for the purpose of final plugging and abandonment. This re-entry will commence as soon as debris removal and location clean-Up (which has already started) can be accomplished sufficiently to allow proper examination o£ the top of the sur- face casing. If the re-entry is successful and well No. 1 is plugged satis- factorily, well No. 1-A will be drilled in the manner described in the pro- gram described above. However, if well No. 1 cannot be re-entered and prop- erly plugged, well No. 1-A will be deflected at a greater angle in order to intersect the bore hole of well No. 1 at a shallower vertical depth (probably 7,600') and used as a "Kill Well" or "Relief Well"; in such case, a Sundry Notice indicating a change in plans will be filed which will indicate a shallower proposed total depth and the manner of equipping the "Kill Well"' or "Relief Well". A Drilling Plan which represents the horizontal projection of the path to be followed by this directional well is attached. BLOWOUT PREVENTION EQUI P~.NT (1) 20" series 600 single gate plus 20" 600 series Hydril, with two 8" relief lines running from 4" flanged outlets on mud spool while drilling to 1,800' . (2) 16" series 1500 double gate plus 16" series 900 Hydril with 4" flanged series 1500 outlets on mud spool and 4" £1anged series 1500 choke manifold and kill line while drilling to 4,800'. (3) 13-5/8" series 1500 double gate plus 13-5/8" series 1500 Hydri'l with 4" series 1500 flanged outlets on mud spool with 4" flanged series 1500 choke manifold and kill line while drilling to total depth. Marathon Oil Company March 3~ 1967 REC. EIVE9 MAR 8 1967 DIVISION OF MINES & MINERAL8 ANCHORAGE 2O :7 A'-02~149 ~ MARAYHON +t UNION 3O MAR AT,ION UNI OR,,~ F A'028 078 32 18 - /MARATHON uN~ON~ 22 2~ (D.&O. Agrel;)" b ~. 0~28_08__.4/~ , A' 0L~8984 1 MARATHON ' ST~ ~ ' ~ A'02808] .~ ~1 ~"1 A'028985' 1 I~ ~'"~ / STANDARD · .'UNIO~ MARAT~N . ATL AN~ICRI CSFI ELD I . + . STA N DAR D t 17 2O R A N G g 10 + A'~02elle ~._..5 ATLANTICRICHFIELD CD. & o. ~re~e.) MAR~ u. BEAVER CREEK PROSPE£T t '*~ WELL Ne ~[-A T.6N, ~-- ~ - Scale: t". ~, 000' ~ 2t MAR $.1967 DIVISION OF MINES & MINERAbS ._i, SURFACE LOCATION BEAVER CREEK NO.I-A \ \ Ii6.90' 34" W 603.10' N d I$00' SURF/ ~CATION (Original) BEAV ~,.. ~E CREEK. i : NO.I / ~9 e 85° gl' 56"W ~ ,.,~ {-oo~.~o, 1338.10' 4738. I0' TTN T6N, R S.M.,ALASKA 5400' TARGET AREA RECEIVED Tv!AR 8 1967 DIVISION OF MINES & ' '~ ANCHORAGE DRILLING PLAN. BEAVER CREEK WELL I- A SCALE: 1"= 400' DRAWN: G. KOCH MARCH 2, 1967 REFERENCE: SURVEY BY S.S. McLANE, DATED FEB. 24, 1967 BOTTOM-HOLE LOCATION AT TOP OF HEMLOCK -- WELL I - A (TOP OF HEMLOCK ZONE ESTIMATED 13,700' VERTICAL DEPTH)/%o,0,