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Home My WebLink About201-181 Irr-e Project Well History File Cov~Page XHVZE This. page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dOL - 1 e L Well History File Identifier //~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V YES ;J¡vJ DATE: -, / -¡,t/oj 151 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WE~E FOUND: YES Organizing (done) RES CAN ~ Color items: 1111111111111111111 o Two-Sided DIGITAL DATA I o Diskettes, No. o Grayscale items: Other. NofType o o Poor Quality Originals: o Other: NOTES: BY: --Yt.(8.WINDY Project Proofing BY: 8 WINDY Scanning Preparation JX30=31) BY: (Y@INDY Production Scanning Stage 1 /;j PAGE COUNT FROM SCANNED FilE: BY: Stage 2 BY: . -..... (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY , GRAYSCALE OR COLOR IMAGES) Rescan Needed 1111111111111 111111 OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds o Other OATE:Lj J [1/04-/5/ V\lP 1111111111111111111 iMP DATE~/r Jð'F~ r +dl DATEIJ/¡ dOf~ r = TOTAL PAGES \...5/ V11e NO NO 151 1III111111I11111111 ReScanned (Imfividua/¡ug-, {."potì.11 M!ú!HitJlJj M:dlJrJiHfj wHIp/oWl) 1111111111111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (done) III 1111111111111111 12/1 O/02Rev3NOTScanned. wpd e e r~ 1;~"""""' "","< MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFichc\CvrPgs _Inserts\Microfihn _ Marker.doc ~ ~ Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: Susan Dionne lRD Permit # 201-181 Cancelled Permit Action Susan Dionne ¡XX API # 133-10002-02 April 18, 2002 This memo will remain at the front of the subject well file. Our adopted conventions for assigning API numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The API number and in some instances the well name reflect the number of preexisting redrills and or multi laterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the API numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter or email received from the operator requesting the permit canceled. (Memorandum January 23,1997 by Dave Johnston, subject: Canceled and Expired Permits) ~VA-€. MLMJÚ M~ Steve McMains ". v rVj Statistical Technician .~ ,..--.~. Alaska BL ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 8, 2002 Mr. Robert P. Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 337 West 7th Avenue, #100 Anchorage, AK 99501-3539 RE: Marathon Susan Dionne #1 (SD1). #1 RD (SD1 RD), #2 (SD2) and #3 (SD3) Well Permits and Location Exceptions Kenai Peninsula, Alaska Dear Mr. Crandall: Per your request, I am attaching a map that shows the above wells which are a workover (SD1- red), permitted (SD1 RD- blue and SD2 - black) or in the process of being permitted (SD3 - green). This map captures the well locations and paths in addition to the requested or approved Location Exceptions for each well. For clarification purposes, the following work plan is expected in the next year. Continue the workover of the SD1 Drill the SD3 Drill the SD2, based on the results of SD3 Marathon was able to re-enter the SD1 successfully; therefore, we do not expect to be sidetracking out of the SD1 in the near future. Marathon requests that AOGCC remove the permit for the SD1 RD. Any future sidetrack will most likely be to a location that would require a new permit. Please call me if you have any questions. Best regards, 9, j)~,,~ ;-e~ David L. Brimberry , Senior Geologist RECEIVED Attachment cc: Pete Berga. w/o attachment Well File APR 9 2002.- Alaska Oil & Gas ConI. Commission AncItotIge Environmentally aware for the long run. .- .... ~ ~ STATE OF ALASKA ALASKA oa AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Marathon Oil Company ("Marathon") for an order granting an exception to the spacing requirements of 20 AAC 25.055(a)(2) to provide for the drilling & testing of the Susan Dionne #lRD exploratory well to an undefmed gas pool Conservation Order No. 461 ) ) ) ) ) ) Susan Dionne #lRD Exploratory Well December 4, 2001 IT APPEARING THAT: 1. Marathon Oil Company ("Marathon") by letter dated September 6, 2001, requested an exception to the well spacing provisions of 20 AAC 25.055(a)(2). The exception would allow the proposed Susan Dionne #lRD exploratory well to be drilled and test produced for gas at a bottom hole location that is closer than 1,500 feet to a property line where ownership changes. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on September 24,2001, pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1) The Susan Dionne #1 well was fonnerly known as the McCoy Prospect #1 well, and before that it was known as the Ninilchik # 1 well. 2) The surface location of this well is 1,489 feet from the east line (FEL) and 144 feet from the south line (FSL) of Section 6, TIS, R13W, Seward Meridian (SM). Union Oil Company of California ("Unocal") drilled the well to a total depth of 14,940 feet measured depth (14,777 feet true vertical depth), and subsequently plugged and abandoned it in 1962. The bottom hole location of the original well bore is 3,081 feet FEL and 652 FSL of Section 6, T1 S, R13W, Seward Meridian (SM). 3) The history of operations within the well from 1962 through 1993 is presented in Conservation Order No. 211 (issued August 19, 1985) and in Conservation Order No. 309 Revised (issued March 18, 1993). 4) In November of 1985, Far North Oil and Gas, Inc. re-entered and cleaned the well out to 3,890 feet measured depth, which is 1,680 feet FEL and 133 feet FSL of Section 6, TI S, R13W, Seward Meridian (SM). The well was perforated from 3,776 to 3,786 feet measured depth, tubing and a packer were run, a tubing hanger was installed, a production tree was installed and tested, the well was swabbed, and gas was flared. Estimated production rates are presented on the Well Completion or Recomp1etion ì--.. .~ 3) Granting this spacing exception is reasonably necessary to provide Marathon with an opportunity to establish the volume of gas reserves in the general area. 4) Before regular production is permitted from the Susan Dionne #IRD well, the Commission must take such action as will offset any advantage which the person securing the exception may have over other producers by reason of the working over of the well as an exception, and so that drainage to the tract with respect to which the exception is granted will be prevented or minimized. AS 31.05.100(b). NOW, THEREFORE, IT IS ORDERED: Marathon's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(2) for the purpose of drilling and testing the Susan Dionne #lRD well is approved under the following conditions. 1) The operator must obtain the Commission's prior approval of a testing program for the Susan Dionne #lRD well. 2) If the well proves capable of hydrocarbon production, regular production will not be permitted until the Commission establishes a drilling unit for the pool and issues an order integrating the interests of owners within the drilling unit, absent voluntary integration by the owners. . ssion D leI T. Seamount, Jr.,éommissioner Alaska Oil and Gas Conservation Commission d-u-t¡L A/\. ÞH:-é~ Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the fmal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th da after the a lication for rehearin was filed). Conservation Order No. 461 December 4 2001 Page 3 of 3 ..... .... ~~-- J-." ,..-..., Report and Log for the well dated December 30, 1985, and received by the Commission on January 4, 1993. 5) On August 23, 1995, the Commission received an Application for Sundry Approvals, dated August 23, 1995, from Alaskan Crude Corporation ("ACC") requesting approval to flow test the McCoy Prospect # 1 well. Approval was granted by the Commission on August 29, 1995. 6) On August 22, 2000, ACC submitted an application dated August 18, 2000 for sundry approval to flow test the McCoy Prospect # 1 well. The Commission approved the application on September 15,2000. 7) On December 15,2000, the Alaska Department of Natural Resources (DNR) approved James W. White's assignment of 100 percent working interest in the tract containing Section 6, TIS, R13W, SM to Unocal. The effective date of the assignment is December 1,2000. On March 9,2001, DNR approved Unocal's assignment of 40 percent working interest in the tract to Marathon, effective February 1,2001. 8) On September 6,2001, Marathon submitted an application for a pennit to drill the Susan Dionne #lRD sidetrack well. The Commission subsequently infonned Marathon that a spacing exception would be required. 9) On September 13, 2001, Marathon requested, by letter dated September 6, 2001, an exception to the well spacing provisions of20 AAC 25.055(a)(2). 10) The Susan Dionne #lRD well would be open for test production at an interval located less than 1,500 feet from a lease boundary where ownership changes. 11) Marathon presented a structure map of the top of the Tyonek T2 sand in the Susan Dionne #IRD vicinity. Marathon's structural interpretation of the subject area indicates the target interval within the Susan Dionne #IRD is located near the top of the geologic structure. 12) Testing of the Susan Dionne #lRD well is necessary to detennine the presence of productive gas reservoir(s). 13) Marathon has made reasonable and diligent efforts to identify, locate, and contact all offset owners, landowners, and operators of all wells within 3,000 feet of the proposed target interval in the Susan Dionne #IRD well. CONCLUSIONS: 1) An exception to 20 AAC 25.055(a)(2) is necessary to allow drilling and testing production of the Susan Dionne #lRD exploratory gas well. 2) Granting a spacing exception to allow reasonable test production of the Susan Dionne #IRD well will not result in waste or jeopardize the correlative rights of adjoining or nearby owners. Conservation Order No. 461 December 4 2001 . Page 2 of 3 .~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICA nON OF Marathon Oil ) Company ("Marathon") for an order granting ) an exception to the spacing requirements of ) 20 AAC 25.055(a)(2) to provide for the ) work over and testing of the Susan Dionne # 1 ) exploratory well in an undefmed gas pool ) Conservation Order No. 460 Susan Dionne # 1 W orkover and Testing December 4, 2001 IT APPEARING THAT: 1. Marathon Oil Company ("Marathon") by letter dated September 6, 2001, requested an exception to the well spacing provisions of 20 AAC 25.055(a)(2). The exception would allow the proposed Susan Dionne # 1 exploratory well to be re-entered and test produced for gas at a location that is within 1,500 feet of a property line where both owners and landowners change. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on September 24,2001, pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1) The Susan Dionne # 1 well was fonnerly known as the McCoy Prospect # 1 well, and before that it was known as the Ninilchik #1 well. 2) The surface location of this well is 1,489 feet from the east line (FEL) and 144 feet from the south line (FSL) of Section 6, T1 S, R13W, Seward Meridian (SM). Union Oil Company of California ("Unocal") drilled the well to a total depth of 14,940 feet measured depth (14,777 feet true vertical depth), and subsequently plugged and abandoned it in 1962. The bottom hole location of the original well bore is 3,081 feet FEL and 652 FSL of Section 6, T1 S, R13W, Seward Meridian (SM). 3) The history of operations within the well from 1962 through 1993 is presented in Conservation Order No. 211 (issued August 19, 1985) and in Conservation Order No. 309 Revised (issued March 18, 1993). 4) In November of 1985, Far North Oil and Gas, Inc. re-entered and cleaned the well out to 3,890 feet measured depth, which is 1,680 feet FEL and 133 feet FSL of Section 6, T1 S, R13W, Seward Meridian (SM). The well was perforated from 3,776 to 3,786 feet Conservation Order No. 460 December 4,2001 Page 1 of 3 ,,;-.... -... measured depth, tubing and a packer were run, a tubing hanger was installed, a production tree was installed and tested, the well was swabbed, and gas was flared. Estimated production rates are presented on the Well Completion or Recompletion Report and Log for the well dated December 30, 1985, and received by the Commission on January 4, 1993. 5) On August 23, 1995, the Commission received an Application for Sundry Approvals, dated August 23, 1995, from Alaskan Crude Corporation ("ACC") requesting approval to flow test the McCoy Prospect # 1 well. Approval was granted by the Commission on August 29, 1995. 6) On August 22, 2000, ACC submitted an application dated August 18, 2000 for sundry approval to flow test the McCoy Prospect # 1 well. The Commission approved the application on September 15,2000. 7) On December 15,2000, the Alaska Department of Natural Resources (DNR) approved James W. White's assignment of 100 percent working interest in the tract containing Section 6, TIS, R13W, SM to Unocal. The effective date of the assignment is December 1,2000. On March 9,2001, DNR approved Unocal's assignment of 40 percent working interest in the tract to Marathon, effective February 1,2001. 8) On September 13, 2001, Marathon requested, by letter dated September 6, 2001, an exception to the well spacing provisions of 20 AAC 25.055(a)(2) in order to work over and test produce for gas the existing Susan Dionne #1 well at a location that is within 1,500 feet of a property line where both owners and landowners change. 9) Marathon presented a structure map of the top of the Tyonek T2 sand in the Susan Dionne #1 vicinity. Marathon's structural interpretation of the subject area indicates the proposed work over target zone for testing in Susan Dionne # 1 is located near the top of the geologic structure. 10) Testing of the Susan Dionne #1 well is necessary to determine the presence of productive gas reservoir(s). 11) On October 19,2001, by letter dated October 18,2001, Marathon submitted a request for sundry approval of the work over and testing for the Susan Dionne # 1 well with supporting proposed testing procedures. 12) Marathon has made reasonable and diligent efforts to identify, locate, and contact all offset owners, landowners, and operators of all wells within 3,000 feet of the proposed work over target in the Susan Dionne # 1 well. CONCLUSIONS: 1) An exception to 20 AAC 25.055(a)(2) is necessary to allow testing gas production of the Susan Dionne # 1 well. Conservation Order No. 460 December 4, 2001 Page 2 of 3 ..- ~ 2) Granting a spacing exception to allow reasonable test production of the Susan Dionne # 1 well will not result in waste or jeopardize the correlative rights of adjoining or nearby owners. 3) Granting this spacing exception is reasonably necessary to provide Marathon with an opportunity to establish the volume of gas reserves in the general area. 4) Before regular production is permitted from the Susan Dionne #1 well, the Commission must take such action as will offset any advantage which the person securing the exception may have over other producers by reason of the working over of the well as an exception, and so that drainage to the tract with respect to which the exception is granted will be prevented or minimized. AS 31.05.100(b). NOW, THEREFORE, IT IS ORDERED: Marathon's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(2) for the purpose of working over and testing the Susan Dionne # 1 well is approved. If the well proves capable of hydrocarbon production, regular production will not be permitted until the Commission establishes a drilling unit for the pool and issues an order integrating the interests of owners within the drilling unit, absent voluntary integration by the owners. DONE at Anchorage, Alaska and dated December 4th, 2001. Cammy Oechsli Taylor, Chair laska Oil and Ga Co ervation Commission Daniel T. eamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission du~ .M, Þk-(A./~Ý Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the fmal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). Conservation Order No. 460 December 4, 2001 Page 3 of3 ,;--... ~ ~1fffi\1fŒ mJ~ ffi\~~~[\~ AlASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR P.K. Berga Drilling Superintendent Marathon Oil Company PO Box 196168 Anchorage AK. 99519 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Susan Dionne #lrd Marathon Oil Company Permit No: 201-181 Sur. Loc. 144' FSL, & 1489' FEL, Sec. 6, TIN, R13W, SM Btmho1e Loc. 1544' FSL & 4988' FEL, Sec 6, TIS, R13W, SM Dear Mr.Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are fIrst caught and 10' sample intervals through target zones. Annular disposal has not been requested as part of the Permit to Drill application for Susan Dionne #lrd. Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Marathon,will assume the liability of any protest to the spacing exception that may occur. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. SuffIcient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum fIeld inspector on the North Slope pager at 659-3607. Sincerely, C~~y~ Chair BY ORDER OF THE COMMISSION DATED this 4th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. g:\cmn\drlg'sterling'su44-10\AOGCCPTD.XLW /""' STATE OF ALASKA ~ ALA~,.r\ OIL AND GAS CONSERVATION COMfv"-JSION PERMIT TO DRILL 210 MC 25.005 1a. Type of Work DrillD Re-Drill[8] 1b. Type of well. Explorato{2J þÞ Stratigraphic TesD Development aiD Re-EntryD DeepenD ServiceD Development Ga{l Single ZonG Multiple Zoneß] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 153' Tyonek 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 ADL 359242 4. Location of Well at Surface 'rlS 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 144' FSL&,!.4~FEL See 6,~R13W, S.M Blanket Surety At top of Pro~ctive Interval ...-r1.Þ 8. Well Number Number 948' FSL & 3614' FEL See 6,J.H<f, R13W, S.M Susan Dionne #1 rd 5194234 At Total Depth ~/? J..þ 9. Approximate Spud Date Amount 1544' FSL & 4988' FEL See 6,~, R13W. S.M 11/12/2001 $200000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Line(unit boundary 1100 feet 15000 feet 2433 9470'md/7990' tvd feet 16. To be Completed for Deviated Well: 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2») Kickoff Depth 3540 feet Maximum Hole Angle 530 Maximum Surface 2820 pslg at Total Depth (TVD) 7990' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 26" 20" 59/79 H-20 welded 193' 0' 0' 193' 193' In Place, w/600 sacks 185/8" 133/8" 54.5/61 J-55 STC 2046' 0' 0' 2046' 2046' In Place w/1800 sacks 12 1/4" 95/8" 40/47 N-80 ? 7430' 0' 0' 7430' 7316' In Place, w/ 2800 sacks 63/4" 41/2" 12.6 L-80 LTC 9470' 0' 0' 9470' 7990' 875 sx r:i(, I, 16 Idt:A The Susan Dionne #1 (formerly Union Ninilchik #1 aka McCoy Prospect #1) will be plugged back according to AOGCC regulations to 3540' MD and sidetracked. SD #1 rd will be directionally drilled to an estimated total depth of 9470' MD/7990' TVD from the existing well location. The production interval will be cased with 41/2" casing and cemented back up into the 9 5/8" casing.. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Surface use plan, Directional Maps, Mud pit drawing, Blowout Prevention Equipment drawings and location map. 20. Attachments Filing Fee[KI Property PlaD BOP Sketch[8] Diverter SketcO Drilling prograrr(8] Drilling Fluid Prograrr0 Time vs Depth PloD Refraction AnalysiU Seabed Repor[] 20 AAC 25.050 Requirementu 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ <t -f Phone: 564-6319 Signed P. K. Berga - Title Drilling Superintendent Date: 9/5/2001 " Commission Use Only Permit Number IAPI Number. Approval Date ¡,::), I eJ LJ I Isee Cover Letter 2-D / .- I SJ 50-/33-1 co6z-02 For fUrYL..Regu!:~ments Conditions of Approval Samples Required IEJYes ONo Mud Log Required 5~'-Yes ONo ' \ c: \.'I'~ /I'--~ D ~ß .~ \l ',,",., . ¡¿_ Hydrogen Sulfide Measures [JYes ~No Directional Survey Required [6JYes ONo Required Working Pressure for BOPE D2M D3M 1Z]5M D 10M 5115M , SEP li 6 If) Other: wC¡~ Te'1t 'ßPE tv 5000 PY\.) - 1,01 Ill" o{ . Alaska Oil & Ga,. Ce. (r.. I Original Signed BV by order o~ . A}'-!:1~Új ~ISSlr Approved by .... n_ _L . Commissioner the CommIssion Date Form 10-401 Rev. 12-1-85 '" U t~! (...! 1"",jl\ I Submit/in Triplicate 1 U! i L.. (llcd( r---- ~ Marathon Oil Compan~ Alaska Region Þ_¿pared By: P. K. Berga Approved By: Date: 09/05/01 Drilling Program Well: Susan Dionne #1 RD AFE: 8700801 Area: Ninilchik Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No. 1 Geologic Program Depth Target Locations FSL FEL Block MD TVD Tolerance Surface 144' J,Mfs , Sec. 6,~ R13W, S.M. 21' 21' NePr "/15,gþ 14'OKB 14'OKB Tyonek 127' 1606' Sec. 6, ~, R13W, S.M. 3535' 3528' Tyonek T-2 184' 1817' Sec. 6, ~ R13W, S.M. 4210' 4143' Tyonek T-3 948' 3614' Sec. 6, T..11If, R13W, S.M. 6608' 5727' Bottom Hole 1544' 4988' Sec. 6, ~, R13W, S.M. 9470' 7990' OKB=Original Kelly Bushing --r!~1> RKB Elevation: RKB to MSL=153' GL-MSL=132' Max. Angle 53 Course 292 Total Depth: TVD 7990' MD 9470' Abnormal Pressures: N/A Subnormal pressures:N/A coring and DST's: N/A Mud Logging: Contractor: Services: Epoch Start Depth: Below KOP Basic with GCA, shale density, temperature in and out, sample collection. 30' samples to TD Logging Program: Contractor To be determined LWD Wireline Logs Surface NA Production NA GR/AIT/DSI/NGT, CMR, RFT's FC #lrd Drilling Program Page 1 of 8 · ".-.-. ~ Drilling Program Summary Production: The existing wellbore will have been plugged back to <= 3540' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at ±3540' MD. Test plug and casing to 1500 psi. TIH with bottom trip whipstock and gyro MWD(Gyro Data's surface read out gyro may be used in place of the gyro MWD). Set whipstock for proper azimuth orientation for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (12.5 PPG anticipated). Drill a 6 3/4" hole to 9470' MD/ 7990' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 4 1/2" production casing and cement per the attached program. Proceed with completion program. Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (psi) (psi) (K ~bs) (MD) 9 5/8" 0' 3540' 40.0 N-80 BTC 12 1/4" 5750 3090 9H 4 1/2" 0' 9470' 12.6 L-80 BTC 6 3/4" 7780 6350 267 Note: The 9-5/8" casing is already installed. All of the 4 %" is new. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8" 40 N-80 3533' 12.5 9.0 873 2.17 1. 83 NA 4 1/2" 12.6 L-80 7990' 9.0 2820 2.87 1. 81 1. 63 FC #lrd Drilling Program Page 2 of 8 ~ ~. Directional Program Directional Co: Baker Hughes Inteq KOP: 3540' Direction: 292 Gyro Co: Gyro Data Build Rate: 3.0 To: 53 deg @ 4740' TVD Drop Rate: 1.5 ave. To: 15 deg @ 7990' TVD Drop Depth: 7000' MD/ 5966' TVD Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below KOP past interference. General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 9 5/8" Intermediate Casing @ 3533' TVD MASP [(PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)] MASP [(9.0 * 0.052 * 3533) - (0.3 * 0.052 * 9.0 * 3533) - (0.7 * 0.115 * 3533)] MASP 873 psi 4 1/2" production Casing @ 7990' TVD* MASP [PP * 0.052 * TVDf - (GG * TVDf)] MASP [9.0 * 0.052 * 7990' - (0.115 * 7990')] MASP 2820 psi FC #lrd Drilling Program Page 3 of 8 Cementing Program Production Casing Size: 4 1/2" Lead Slurry: Top of Cement: Specifications: Compress Strgth: Tail Slurry: Top of Cement: Specifications: Compress Strgth: Total Volume: /""""" ..,~ Contractor: BJ Services Setting Depth: 9470' MO/ 7990' TVD Annular Volume to 3000' with 6 3/4" gauge hole: 964 ft3 Density:~ ppg, Yield:~ ft3/sx, Sx: 425 sx, cf 884ft3 3000'MO/ 3000' TVD Class G + additives Mixed w/ fresh water 500 psi in 10 psi in 16 hrs hrs, 2000 Density:~ ppg, Yield: 1.15 ft3/sx, Sx: 450 sx, cf: 518 ft3 7000'MD/ 5709' TVD Class G + additives Mixed w/ fresh water 500 psi in 6 hrs, 3600 psi in 24 hrs 1402 ft3, *50% Open Hole Excess, wac Time: 6 hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions. FC #lrd Drilling Program Page 4 of 8 .~ Diverter and BOP Program The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) 873 1500 (1) 13-5/8" 5M Annular 250/3000 Intermediate 9 5/8" (9.0 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 3000 (1) 13-5/8" 5M Annular 250/3000 production 4 1/2" 2820 (10.0 (1) 13-5/8" Blind ram 5M 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted, or (3) 1500 psi. 9 5/8" Intermediate Casing at 2157' TVD CTPMASP 873 psi CTPBurst = 5750 * 0.7 - ((9.0-8.3) * 0.052 * 3533) Test to 1500 psi 3896 psi 4 1/2" Production Casing at 8007' TVD / CTPMASP = 2820 psi Test to 3000 psi CTPBurst = 7780 * 0.7 - ((10.0-8.3) * 0.052 * 7990) 4740 psi FC #lrd Drilling Program Page 5 of 8 ~ /~..\ Mud Program Contractor: MI Drilling Fluids Interval (TVD) Mud Weight From I To (ppg) Water Loss Mud Type 3533' I 7990' 9.0 - 9.5 <8 Flo Pro/KCI Wellhead Program Manufacturer FMC Model Tubing Head 11/1 5M top x 13 3/8/1 3M Casing Head 13 3/8/1 3M top x 9 5/8/1 SOW Detailed Drilling Procedure Formation Leakoff Test ~ntermediate casing shoe will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume shou~d be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Bit Program The following guidelines are recommended for use on this well. Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 3540' - 9470' 6 3/4/1 Smith-To be determined FC #lrd Drilling Program Page 6 of 8 .~ ~. Drill String Item Ppf Makeup Torque Max Pull -Premium. 3 1,6" HWDP/3 1,611 IF 24.4 12000-13200 248/000 Ibs ft.-lbs. 4"1 8-1351 HT 38 15.53 13/500-19/800 403/500 Ibs. ft.-lbs. 511 HWDPI 41,611 IF 49.3/53.6 29/000 543/000 Ibs. ft.-lbs. Hydraulics Program Rig mud pumps available are shown below. Install 4 1/2 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oìlwell A 600 PT 4 %" 8" 3207 1. 6005 135 Oìlwell A 600 PT 5.0 8" 2597 1. 9788 135 Oìlwell A 600 PT 5 %" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (psi) (fpm) (ppg) (32"s) Remarks 9470' 6 3/4" 280-320 2200 - 175 9.5 14,14,14 Motor Drilling 2900 Note: 4 1/2" liners are recommended. FC #lrd Drilling Program Page 7 of 8 ~, ~. OPERATIONAL PROCEDURE 1. Abandon existing perforations according to program filed with AOGCC. 2. RIH and set CIBP at +/- 3540' md. Test plug and casing to 1500 psi.~ 3. MU and RIH with bottom trip whipstock and MWD. Set whipstock for proper azimuth for casing exit. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 12~5 ppg anticipated) . 4. Drill a 6 3/4" hole to 9470' MD/ 7990' TVD per the attached directional program. Backream each stand. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. 5. At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH. Run logs as per geology requirements. Make wiper trip. POOH laying down drill pipe. Pull wear bushing. 6. Install and test casing rams (if variable bore rams are not installed). 7. Locate pump in sub and safety valve. Function safety valve and place on rig floor. Record function test in IADC book. RU and run 4 1/2" casing. ,/' 8. Cement casing as per the attached cementing program. Displace cement with KCL. Test casing to 3000 psi. 9. Test hanger. Set BPV. N/D BOPE and N/U and test tree. FC #lrd Drilling Program Page 8 of 8 r--- ~, POTENTIAL HAZARDS Well: Susan Dionne #1 rd To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 2200' tvd/2200'md to total depth of the well. These sands will be normal pressured so lost circulation and differential sticking are not potential hazards. There are no well interference hazards. T ¡ 2000 4000 ....... 6000 s:: ~ 0 0 0 N ........ o:S g. 8000 0 ta (,) '-8 Q) ;:> Q) 2 Eo-; 10000 12000 14000 Azimuths to True North Magnetic North: 20.96° Magnetic Field Strength: 55030nT Dip Angle: 73.14° Date: 8/612001 Model: Wmm _95 a-T""- I ¡ ?",,-. ..----." Field: Ninilchik Site: Susan Dionne #1 Prospect Location Well: Susan Dionne #1 Wellpath: Lower Sidetrack (for future lateral) _~..__u.._._....~..~..u.. n_n.. _ _.__.~___ .. ___. n_.'. _ ____._..~--.__ o Name Top Target Bottom Target 2000 4000 6000 Vertical Section at 291.80° [2000ftlin] ~ .m.·.. .._....._m·_._ . .........__.........u·._._ _,.__._.' ___ LEGEND Susan Dionne #1,Lower Sidetrack (for future lateral),INTEQ Plan Susan Dionne #1 (Original Wellbore) Lower Sidetrack (for future lateral) WELLPATHDETAILS Lower Sidetrack (for future lateral) Hit lower target, future lateral in upper target Parent Wellpath: Tie on :MD: Originat Wellbore 3157.10 Rig: Ref. Datum: Glacier Rig No, 1 Current Drilling 153.00ft V.Section Angle 291.80° Origin Origin +N/-S +E/-W Starting From TVD 0.00 0.00 0.00 TARGET DETAILS TVD +N/-S +E/-W Shape 3515.50 1000.00 -3000.00 Circle (Radius: 200) 7990.50 1400.00 -3500.00 Circle (Radius: 200) 8000 10000 1200 T Azimuths to True North Field: Ninilchik l ~ Magnetic North: 20.96° Site: Susan Dionne #1 Prospect Location Magnetic Field Well: Susan Dionne #1 Strength: 55030nT Wellpath: Lower Sidetrack (for future lateral) Dip Angle: 73.14° Date: 8/6/2001 Model: Wmm _95 - - LEGEND - Susan Dionne # 1,Lower Sidetrack (for future lateral),INTEQ Plan - Susan Dionne #1 (Original Wellbore) - Lower Sidetrack (for future lateral) 2000 WELLPAlliDETAll,S Lower Sidetrack (for future lateral) Hit lower target, future lateral in upper target Parent Wellpath: Original Wellbore j Tie on MD: 3157.10 1500 Rig: Glacier Rig No.1 Ref. Datum: ClUTent Drilling 1 53.00ft ....., ] V.Section Origin Origin Starting ¡:: ~ ~ Angle +N/-S +E/-W From TVD 0 C ~ 291.80° 0.00 0.00 0.00 0 V) ........ +' 1000 TARGET DETAll,S '-" '€ JopT Name TVD +N/-S +E/-W Shape ~ Top Target 3515.50 1000.00 -3000.00 Circle (Radius: 200) -. Bottom Target 7990.50 1400.00 -3500.00 Circle (Radius: 200) I '-" -,.-- ~ o:S , ::s , 0 500 - ¡ r/). "h.. ') -' / ""1"'"-<....,.., ~ i ì- 0 -1. I i i I ¡ -500 ¡-¡- ,......, ,...,--,. I I I ¡ -r --r -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 W est( - )Æast( +) [500ft/in] ~ ~. MARATHON Oil Company Ninilchik #1 SD#l slot #1 Exploration Kenai Peninsula, A1aska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License Susan Dionne#l Ver. #2 prop4851 Date printed Date created Last revised 5-Sep-2001 31-Aug-2001 5-Sep-2001 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 214436.499,2236359.987,999.00000,N Slot location is n60 6 46.676,w151 34 24.834 Slot Grid coordinates are N 2236630.999, E 212945.001 Slot local coordinates are 235.61 N 1497.51 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North i.s True North r--. ,------. MARATHON Oil Company PROPOSAL LISTING Page 1 Ninilchik #l,SD#l Your ref Susan Dionne#l Ver. #2 Exploration,Kenai Peninsula, Alaska Last revised : 5-Sep-200l Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORDS Depth Degrees Degrees Depth COORD INATES Deg/100ft Sect Easting Northing 3540.50 9.99 273.21 3533.19 17.55S 11 7. 70W 0.00 102.77 212826.92 2236616.25 3600.00 11.65 276.76 3591.63 16.55S 128.82W 3.00 113.46 212815.83 2236617.50 3700.00 14.50 280.88 3689.03 13.00S 151.15W 3.00 135.51 212793.59 2236621.58 3800.00 17.40 283.66 3785.17 7.10S 177.98W 3.00 162.62 212766.90 2236628.12 3900.00 20.33 285.67 3879.78 1.13N 209.25W 3.00 194.70 212735.84 2236637.08 4000.00 23.28 287.19 3972 . 62 11 . 66N 244 .87W 3.00 231.68 212700.48 2236648.46 4100.00 26.24 288.38 4063.41 24.48N 284.73W 3.00 273.46 212660.93 2236662.21 4200.00 29.20 289.35 4151.93 39.53N 328.74W 3.00 319.91 212617.29 2236678.31 4300.00 32.18 290.15 4237.91 56.79N 376.77W 3.00 370.91 212569.69 2236696.70 4400.00 35.15 290.83 4321.13 76.20N 428.68W 3.00 426.32 212518.25 2236717.34 4500.00 38.13 291 . 42 4401.36 97.72N 484.34W 3.00 485.99 212463.11 2236740.16 4600.00 41.11 291 . 93 4478.38 121.28N 543.60W 3.00 549.76 212404.43 2236765.12 4700.00 44.10 292.38 4551.97 146.81N 606.29W 3.00 617.45 212342.37 2236792.13 4800.00 47.08 292.79 4621.94 174.25N 672.23W 3.00 688.87 212277.09 2236821.13 4900.00 50.07 293.16 4688.09 203.53N 741.26W 3.00 763.83 212208.78 2236852.03 4983.23 52.56 293.45 4740.11 229.23N 800.92W 3.00 828.77 212149.74 2236879.14 5000.00 52.56 293.45 4750.30 234.53N 813.14W 0.00 842.08 212137.65 2236884.73 5500.00 52.56 293.45 5054.28 392.51N 1177.34W 0.00 1238.91 211777.30 2237051.28 6000.00 52.56 293.45 5358.25 550.49N 1541.54W 0.00 1635.73 211416.94 2237217.84 6500.00 52.56 293.45 5662.23 708.46N 1905.74W 0.00 2032.55 211056.59 2237384.40 6966.53 52.56 293.45 5945.85 855.86N 2245.56W 0.00 2402.81 210720.36 2237539.80 7000.00 52.06 293.45 5966.32 866.40N 2269.86W 1.50 2429.29 210696.31 2237550.92 7100.00 50.56 293.45 6028.83 897.46N 2341. 46W 1.50 2507.30 210625.47 2237583.66 7200.00 49.06 293.45 6093.37 927.86N 2411.54W 1.50 2583.66 210556.13 2237615.71 7300.00 47.56 293.45 6159.88 957.57N 2480.04W 1.50 2658.29 210488.35 2237647.04 7400.00 46.06 293.45 6228.32 986.58N 2546.92W 1.50 2731.17 210422.18 2237677.63 7500.00 44.56 293.45 6298.65 1014 .87N 2612.14W 1.50 2802.22 210357.65 2237707.45 7558.29 43.68 293.45 6340.50 1031.02N 2649.37W 1.50 2842.79 210320.82 2237724.48 7600.00 43.06 293.45 6370.82 1042.42N 2675.64W 1.50 2871.42 210294.82 2237736.49 7700.00 41. 56 293.45 6444.77 1069.20N 2737.39W 1.50 2938.70 210233.72 2237764.73 7800.00 40.06 293.45 6520.46 1095.21N 2797.34W 1.50 3004.02 210174.40 2237792.15 7900.00 38.56 293.45 6597.84 1120.41N 2855.46W 1.50 3067.34 210116.90 2237818.73 8000.00 37.06 293.45 6676.84 1144.81N 2911.69W 1.50 3128.61 210061.26 2237844.44 8100.00 35.56 293.45 6757.43 1168.37N 2966.01W 1.50 3187.79 210007.52 2237869.28 8200.00 34.06 293.45 6839.53 1191.08N 3018.38W 1.50 3244.85 209955.71 2237893.23 8300.00 32.56 293.45 6923.10 1212.93N 3068.75W 1.50 3299.74 209905.86 2237916.27 8400.00 31.06 293.45 7008.09 1233.91N 3117.10W 1.50 3352.42 209858.02 2237938.38 8500.00 29.56 293.45 7094.42 1253.99N 3163.40W 1.50 3402.86 209812.22 2237959.56 8600.00 28.06 293.45 7182.04 1273.16N 3207.60W 1.50 3451.02 209768.48 2237979.77 8700.00 26.56 293.45 7270.89 1291.42N 3249.69W 1.50 3496.88 209726.84 2237999.02 8800.00 25.06 293.45 7360.92 1308.74N 3289.62W 1.50 3540.39 209687.32 2238017.28 8900.00 23.56 293.45 7452.05 1325.12N 3327.38W 1.50 3581.54 209649.96 2238034.55 9000.00 22.06 293.45 7544.23 1340.55N 3362.94W 1.50 3620.28 209614.78 2238050.82 9100.00 20.56 293.45 7637.39 1355.01N 3396.28W 1.50 3656.60 209581.80 2238066.06 9200.00 19.06 293.45 7731.47 1368.49N 3427.36W 1.50 3690.47 209551.04 2238080.28 9300.00 17.56 293.45 7826.41 1380.99N 3456.18W 1. 50 3721.87 209522.53 2238093.46 9400.00 16.06 293.45 7922.14 1392.50N 3482.70W 1.50 3750.77 209496.28 2238105.59 9470.44 15.00 293.45 7990.00 1400.00N 3500.00W 1.50 3769.62 209479.17 2238113.50 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Glacier #1) (153.00 Ft above mean sea level). Bottom hole distance is 3769.62 on azimuth 291.80 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 291.80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ r---. -~. MARATHON Oil Company Ninilchik #l,SD#l Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref Susan Dionne#l Ver. #2 Last revised: 5-Sep-2001 Comments in wellpath ----------- ------------ MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 7558.29 9470.44 6340.50 7990.00 1031.02N 1400.00N 2649.37W 3500.00W Interpolated Tgt Ninilchik TD/Tgt Rvsd 31-Aug-Ol Targets associated with this wellpath ----------------------- ----------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- Ninilchik TD/Tgt Rvs 7990.00 1400.00N 3500.00W 31-Aug-2001 o I Flow Nipple I 13 5/8" 5M Annular Preventer 135/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves ".-..... Marathon Oil Well SD-1rd BOP Stack -. I Flow Line I ~ I Pipe Ram I ----. I Blind Ram I ~~ ~~ ŒITD IChoke 11351B"5MCross I ~ 135/8" 5M Single Ram Preventer I Pipe Ram I ~ ~ 3 1/8" 5M Hydraulically Operated Valve JI [lI0J]][]I0]] t 31/8" 5M Manually Operated Valve ~ ,~ Marathon Oil Well SD-1rd Choke Manifold Bleed off Line to Shakers ITO Gas Buster I t 1311 5M Valves î 31/8" 5M Manually Adjustable Choke 29/16" 10M Swaco Hydraulically Operated Choke I From BOP Stack I GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT 14·...... 'v )' nr~ DITA I I I I I 1 I I I I I I I -46'-CI" 8"-G" JIo( 1.&.1. I- er IA :I: t:i >- ::I: I J ~v 9l A-60D PT SV 9L A-600 PT 12* x 3' K[]]HY I I 1 I œ ) i .:r:.1 I 1 r-----ì I I I L________ I I I CENTRlfUGEI j 1 UNIT I I 14' X UI" I I I I I 1 I I J I f I I I J DlI4P I I - I I _ t ,\ I I ,- ..., I ....~ I II' ~ r'POIRB[]Y' 1 L.....____J 'OJEGASSER¡ I, / I, ... --.... ~ .. ... PILL. iPtT I ':.':. I I~ . I~:"I tul11DIIiH 1 I 1 I 1 1 1 I I ¡., L_____ I , f 1 ....--, 11 I I j IJ ; I nl U I Œ I .1 Œ " t !:i! t I tI II 2 4: I I i II 1 Q I I M 11 111: I I I u 1 ø: I I 1/ . A I I II L_____J L_____JI r---------, I .... r, ...r, I \J ".... i ~- ----~t L__.J U .~ .-...., SURFACE USE PLAN FOR Susan Dionne #1 rd WELL Surface Location: SW 1/4 of SE 1/4, Sec. 6, T1S, R13W, S.M. 1. Existing Roads The Sterling Highway will be used for access to the SD #1 rd well and is shown on the attached map. Ninilchik, Alaska, is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed A new road will be constructed on the Dionne property from the Sterling Highway for access to the pad. 3. Location of Existing Wells Well SD #1 was (formerly called the Union Ninilchik #1 or the McCoy well) is the only existing well on the pad and the SD #1 rd will be drilled out of this wellbore. The nearest well is the Mobil Ninilchik well which is approximately 15000 feet away. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply A new water well will be drilled and the water used to make and maintain the drilling mud. 6. Construction Materials Gravel will be sourced locally for the construction of the access road and resurfacing of the existing drilling pad. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). N :\DRLG\W ELLS\U N 1 \SU RFUSE.doc .~ ,....--...., Surface Use Plan Susan Dionne #1 rd Well Page 2 b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. S & R will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of SO #1 rd. 10. Surface Ownership Paul Dionne is the surface owner of the land at the Susan Dionne #1 rd well. 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed N:\D RLG\W ELLS\U N 1 \SU RFUSE.doc .~ ~ Surface Use Plan Susan Dionne #1 rd Well Page 3 herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: September 4, 2001 Name & Title: a:~--- Drilling Superintendent Mara on I Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 N:\DRLG\W ELLS\UN 1 \SU RFUSE.doc /""""", ~ . . I- I ... IIIASE LINE I , ..,._ _~____ -----r-. _..l. q . I , . ~ <: ~ * ..-L I ':) 6t 151°3C KENAI (A-5) QUADRANGLE ALASKA-KENAI PENINSULA BOROUGH 1:63 360 SERIES (TOPOGRAPHIC) SCALE 163360 -"""" ".._---"_._~~-_."~---- 1 . "2 0 ç:.:::.~.>==< ~ 0;;;- 3OCO Ü Ei~~._t.=r:...--'===:::' 1 .5 2 -;:=:"'.-. 3 u__ _~._ 4 MilES 3000 6000 9000 :2000 1S000 18000 21000 FEEl .~~'::~~:~':::::¡"-""-""~-=i ~-..t:=:3 I 2 3 4 5 KIlOMETERS _...!::=~;_ ...... ~~:J ~ o ~-1.-.t=1-L. Qct-25-01 04:07pm From-MARATHON OIL r--.. +9155646489 7"', T-560 P.02/02 F-288 -0 ~~W\O\ \' Jth{, ~\\/~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS , . Type of Request; Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well 2!.. Alter casing _ Rapair welllL Plugging _ Time extension _ $timulata_ Changa approved program _ Pull tu)ing lL VarianCa _ Perforate -1L Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevatíon (OF or KB) Marathon Oil Company Development lL Exploratory 153 r~et -- 3. AddrQss Stratigraphic _ 7. Unit or Property name PO Box 196168 Anohorage AK 99519-6168 Service . Susan Dionne - 4, Location of well at surfaoe ... v '" 8. Well number 144' FSL & 1488' FEL See 6, T1N, R13 W, S.M. Susan Dionne #1 rd At top of produotive interval 9, Permit n~r 948' FSL & 3614' FEL Sec 6, T1N, R13W, S.M. 85-208 At effective depth 10. API number ./ 1544' FSL & 4988' FEL See 6, T1 N, R13W, S.M. 50-133·10002-01 - 11. Field/Pool Tyonek 12_ Present well condition summary Total Depth: measured drilling 14940 feet PIU($ (measured) 7450'-7400' (50 sKs) c..\~~~~~~ ~ (approx) true vertical feet 10,350'-10,450' (45 sks) 12,600'-12,700' (45 sks) Effective depth: mea$urød 7400' feet Junk (measured) (appl'O¡() true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 193' 20" In place, w1600 sk$ 193' 193' Surface 2046' 18-5/8" In plaoe, w/1800 sks 2046' 2046' Intermedìate Production 7430' 9-5/S' In plaoe, wf2800 eks 7430' 7316' Liner Perforation depth: 3776'-3786' measured Tubing (sio:e, grade, and measured depth) 2-7/8",6.5#, N-aO 3661' Packers and $$$V (type and measured depth) 9·518" Otis triple 3661' 13. Attachmen1s Q!;)$cription summary of proposal _ De!allee! operation program -L. BOP sketçh _ Contact Ken Walsh at 564-6305 or Gary Eller at 564-6315 with any questions. LOT test, surfacÐ cement details and casing detail sheets 14. Estimated date for commencing operation 15. Status of well classification as; 11 (29f01 - Oil_ Gas - Suspended -L- 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify 111at the foregoing is true and correct to the best of my knowledge. Signed 1<en D. Walsh \ Ú»- ~. v.J~Title Advanc;ed Petroleum Engineer Date 10/25/01 FOR COMMISSION use ONLY --- Conditions at approval: Notify commission so repr~ntatiV$ may witness ?>o<:::J:::> ~ '> '\ ß C) \?~ -s\- IAP~t)1 N\ Ö{) Plug integrity _ BOP Test l.ocation clearance _ I \ - Mechanicallntegrityiest_ Subseql.lentform require 10-~ o~'-\C)"'\ o""(,)..~~~~ D." //Ia:fbl Origina' Signed By Approved bv the order of the CommissiDn - I\. ..&...1: Commissioner ~ ." SUBMIT n/TRIPL.léATF. . 3 Rev 06/15/88 Form 10 40 ORIGINAL RECEIVED OCT 25 2001 Alaska Oil & Gas Cons. Comffi\8810fi . Anchorage .~ /------ Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 October 18, 2001 Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Re: Susan Dionne #1 Workover Permit ~SCSll/s" OCr U 4~.t 19, aOi/&G. <OO¡ as COn. AI/Chon ~ C% . Clge 'fIJ/Ssion Dear Mr. Maunder: Attached please find a request for sundry approval of the workover for the Susan Dionne #1 well. Also attached are copies of the anticipated workover procedure and wellbore diagrams for the current and proposed configurations. This well has been shut in since it was re-entered by Jim White in 1985. Marathon's plan is to pull the packer and tubing in the well and drill out a cast iron bridge plug and cement in the 9-5/8" casing to a total measured depth of 7,415 feet. A cased hole RST and bond log will be run across the gross target interval of 6,750' to 7,342'. A 4-1/2" production casing string will be run from the new TD to surface and then cemented to 3,000' MD. Each of the anticipated four Tyonek targets will be perforated with modular guns on slickline, flow tested, and then isolated before moving uphole to the next target interval. Following the completion of this workover, the well will be shut in and secured awaiting a pipeline connection. A permit to sidetrack this weHbore has also been submitted to the AOGCC for approval. The sidetrack is planned as a contingency should mechanical difficulties or reservoir reanalysis identified during the workover indicate the necessity for a sidetrack. If you have any questions concerning this matter, please contact me at 564-6305. Sincerely, I~)) .W~ Ken D. Walsh Advance Production Engineer OR\G\NAL ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Perforation depth: 3776'-3786' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended ell)i. Alter casing _ Repair welllL Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing lL Variance Perforate -1L 2. Name of Operator Marathon Oil Company 5. Type of Well: Development L Exploratory _ Stratigraphic _ Service feet 3. Address PO Box 196168 Anchorage AK 99519-6168 4. Location of well at surface 144' FSL & 1488' FEL Sec 6, T1N, R13 W, S.M. At top of productive interval 948' FSL & 3614' FEL Sec 6, T1 N, R13W, S.M. At effective depth 1544' FSL & 4988' FEL Sec 6, T1 N, R13W, S.M. . Well number Susan Dionne #1 rd 9. Permit number 85-208 10. API number 50-133-10002-01 11. Field/Pool Tyonek 12. Present well condition summary Total Depth: measured drilling (approx) true vertical 14940 feet ed) 7450'-7400' (50 sks) 10,350'-10,450' (45 sks) 12,600'-12,700' (45 sks) unk (measured) Effective depth: (approx) measured true vertical 7400' Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured depth True vertical depth In place, w/600 sks 193' 193' In place, w/1800 sks 2046' 2046' In place, w/2800 sks 7430' 7316' 193' 2046' 7430' measured s ~ Ç'Q. R«:~ Ç!. 2-7/8",6.5#, N-80 3661' \ f:J / f7.. 'S:' Tubing (size, grade, and measured depth) 9-5/8" Otis triple 3661' Alaska Oil & Gas Cons. Com Anchorage 13. Attachments Description s mmary of proposal _ Detailed operation program -1L BOP sketch Contact Paul Mazzolini at 263-4603 r Tom Brassfield @ 265-6377with any questions. LOT test, surface cement details and casing detail sheets 14. Estimated date for commencing 11/29/01 16. If proposal was verbally appr 15. Status of well classification as: Oil Gas Suspended ..2L..- Name of approver Date approved Signed Ken D. Walsh 17. I hereby certify that the f regoing is true and correct to the best of my knowledge. ú..M..~. v.J~ Title Advanced Petroleum Engineer Date 10/16/01 FOR COMMISSION USE ONLY Conditions of appr al: Notify Commission so representative may witness Plug in grity _ BOP Test Location clearance Mech nicallntegrity Test _ Subsequent form require 10-_ ¡APproval N~ _ 3cX) Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ORJG'f~A\L ~, /'. MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Susan Dionne #1 Workover Procedure AFE # 8700701 Tvonek Completion Procedure (08-29-2001) ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. 1. Grade/gravel well location and build lease road to accommodate Glacier Drilling Rig #1. Q>"t¡s'1 ~~, ~(t.\..", 2. Pump 40 bbls. fresh water do n 3-1/2" t 'ng to kill Beluga perforated interval at 3,776'- 3,786'. Note fluid injection rat . s for potential cement squeeze. Have ABB Vetco install 2-1/2" BPV in tubing hanger through Christmas tree (dual 2-9/16" 5K valves). Make arrangements to have 2-7/8" thread protectors (pin and collar) on location for about 125 joints of tubing. 3. MIRU Glacier Drilling Rig #1. Ensure that top pipe rams are VBR's (2-7/8" x 5") and bottom pipe rams contain 4" rams. NU and test BOP stack to 3000/250psi rams and 1500/250 psi annular. Pressure test tubing/casing annulus to 1000 psi with fresh water. 4. RU lubricator and remove BPV. Make up 2-718" tubing to top of tubing. Back out lock down screws on tubing head. Pull and remove tubing hanger. 5. Release 9-5/8" 0.0. Otis triple string hydraulically-set packer located set at 3,661' MD. Conventionally circulate fresh water to remove KCL-cut drilling mud from tubing/casing annulus. Consider pumping 30-bbl. Safe-Kleen (surfactant) sweep(s) to clean out casing. 6. POOH and LD 2-7/8" tubing and packer. Send tubing in to Tuboscope for inspection, repair, and storage. Note and report condition of packer elements (any missing portions of the elements). 7. PU and RIH with 8-1/2" junk mill, string mill, two boot baskets, bumper sub, oil jars, 9 joints of 6-1/4" drill collars, and 4" drill pipe cleaning out 13.6 ppg mud to 9-5/8" Baker Model "C" CIBP at 3,890' MD. Tag up on CIBP and line up to circulate fresh water with polymer sweeps. Mill over CIBP and circulate bottoms up with polymer sweeps as necessary. NOTE: Convert to light LSND mud system should the Beluga perfs at 3,776'-3,786' take too much fluid. 8. Continue running in hole cleaning out 13.6 ppg mud to top of cement plug at 7,400'. Drill out cement plug to 7,415' MD (RST tool length is 33.3' and CBUUSIT tool length is 66.7'). Circulate bottoms up with fresh water until returns are clean. POOH. 9. MIRU Schlumberger logging service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Have on location the appropriate centralizers and roller stem dependent upon slickline operations. Hold safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig using 50:50 mixture of 6% KCI water and methanol. ~ /'---~' Page 2 of 10 Dump methanol mixture down well. Run cased hole logging suite of USIT/RST/CBT from 7,415' to 3,500'. Correlate depth to Schlumberger Open hole Logs dated Sept 10,1962. DECISION POINT BASED ON CASED HOLE LOGS: . Run and cement 4-1/2" liner from 7,415' TD to surface. Omit Steps #10-12 and proceed directly to Step 13 below. .:. If acceptable cement bond and casing integrity across proposed gross perforated interval 6,750'-7,345' MD and .:. Acceptable structural position for proposed Tyonek test interval and .:. Acceptable target intervals identified from RST and .:. Workover costs support continuing workover without sidetrack. . Abandon existing production perforations and plug back wellbore for sidetrack. Perform only Steps #10-12 below. .:. If unacceptable cement bond across proposed gross perforated interval 6,750'-7,345' MD or .:. Unacceptable structural position for proposed Tyonek test interval or .:. Unacceptable target intervals identified from RST or .:. Problem costs on workover warrant initiating sidetrack. \~\~(,.~'t.,..,. ~r 'A ~ca.'t.." 1 O. PU and RIH with Halliburton EZ Drill 9-5/8" cement retainer on 4" drill pipe. Set cement retainer at 3,750' MD (11' above top squeeze perf at 3,761' MD and 26' above top production perf at 3,776' MD). RU chicksan and hardline from drill pipe to squeeze manifold. RU line from manifold to choke line. Partially unsting from retainer and pressure test drill pipe to 1000 . I n pre annulus to 1000 psi. Fully sting back into retainer. stablish circulation through cement reta ner with fresh water without exceeding 800 maxI' sting from retainer. 11. RU BJ Services cementers to pump down drill string through cement manifold. Mix and pump 50 sks of Class "G" cement w/0.4% FL-33, 0.2% SMS, 0.25% CD-32, and 1 gps FP-6L. Cement volume from bottom of retainer to base of perforations at 3786' is 13.3 sacks. Spot cement to stinger and sting back into retainer. Slow rate and clear drill string squeezing the perfs to 500 psig attempting a running squeeze. Casing volume below the cement retainer to the top perf is 9.6 sks. If necessary shut down pumping for 5 minutes and then resume pumping for up to 2.0 bbls. Do not pump more than three (3) sequential pump-ins as squeeze may be rendered ineffective. Unsting from retainer, spot 1 bbl. of cement on top of retainer, PUH at least 15 feet, and reverse circulate two bottoms up. TOOH with drill pipe and stinger. 12. PU and RIH with Halliburton EZ Drill 9-5/8" cement retainer on 4" drill pipe. Set cement retainer at about 3,565' MD for whipstock base. POOH. Proceed to separate sidetrack '"~. operations as outlined by sidetrack drilling permit plan of operations. 'II!' Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM ~, .~ Page 3 of 10 13. Change lower pipe rams to 4-1/2". Inspect sealing surface for ram blocks. Test door seals at 250 psi low and 3000 psi high. Hold pre-job safety meeting. Change out to long bails. RU Weatherford to run 4-1/2" casing below. 14. PU and RIH with 4-1/2" Float Shoe, one (1) shoe joint 4-1/2",12.6 ppf L-80 Mod Buttress tubing, 4-1/2" Float Collar, one (1) joint 4-1/2",12.6 ppf L-80 Mod Buttress tubing, Landing Collar, and approximately 7,300' of 4-1/2",12.6 ppf L-80 Mod Buttress tubing installing injection mandrel and control line at about 2,500' MD. Hold pressure on control line while TIH. Continue running in hole strapping control line to 4-1/2" Mod Buttress tubing. Place centralizers one per joint from TO to 6,700' MD and every third joint to surface. Circulate and condition hole. PU and makeup cement head. 15. MIRU BJ Services to cement 4-1/2" production casing. Hold pre-job safety meeting. Mix and pump 20 bbls. weighted spacer (MCS-4 w/KCl), 485 sks. Class "G" wladditives @ 12.5 ppg (2.08 cf/sk yield) lead cement, and 326 sks. Class "G" w/additives @ 15.7 ppg (1.18 cf/sk yield) tail cement. Displace cement with approximately 111 bbls. fresh water. Estimated mix water required for the cement work is 7,400 gals (176 bbls). 16. Break BOP stack at 11", 5K casing head. Lift BOP stack. Vetco representative to set 4-1/2" segmented slips with slot for control line. Install packoff and tubing head adaptor. Thread control line through tubing head adaptor and packoff. 17. NO BOP and NU and test tree. leave BPV in tubing head. RDMO Glacier Drilling Rig #1. 18. RU Halliburton test equipment to well. System must have methanol injection downhole and surface capability. Halliburton will control the SSV during testing. 19. MIRU 1-3/4" 0.0. coil tubing unit with nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. Make up coil tubing connector to coil tubing. Make up check valve, hydraulic disconnect, circulation sub, 2.13" Baker mud motor, and 3-3/4" junk mill. RIH with BHA on coil tubing and drill out landing collar, float collar, and cement to new PBTD of 7,400' MD with fresh water. PUH with CT replacing fresh water with 6% KCl water from PBTD to 6,150' MD. Drop ball and open circulation sub. Jet well dry with nitrogen from 6,150' to surface. lD drilling assembly and RO coil tubing unit. 20. RU Schlumberger logging service with full lubricator (pump-in sub and flow tubes), and pressure control equipment. Have on location the appropriate centralizers and roller stem to allow passage of tools to TO. Hold safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig using 50:50 mixture of fresh water and methanol. Dump methanol mixture down well. PU and run 3.81" gauge ring to 7,400'. Baker Oil Tools is providing the junk basket and associated gauge ring. (Maximum tool 00 will be 3.81" 00). Correlate depth to Schlumberger cased hole logs run in Step #9. PU Halliburton 4-1/2" 1 OK CIBP w/Baker #10 setting tool and GR/CCl tool. RIH, correlate depth and set CIBP at 7,358' (13' below bottom of Test #1 perforation interval). RO Schlumberger wireline. Note the time it takes to get out of the hole from 7,358' to surface. Tyonek Interval #1 7260 Sand Total 7.260-7.345' 85' NOTE: The SBHP of this Tyonek sand is approximately 2,220 psia (0.304 psi/ft gradient) Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10AM -- .~ Page 4 of 10 21. RU crane with 70' of boom. RU Pollard Slickline equipment and 0.125" wire. Perform wire twist test. Install full lubricator. Hold Safety and environmental awareness meeting. Pressure test surface equipment to 3,000 psig. Fluid level is at approximately 6,150' MD yielding an estimated 1720 psig underbalance. PU space out bar w/2.313" fishing neck and RIH landing on CIBP at 7,358'. Note the time it takes to get out of the hole from 7,358' to surface. 22. Prepare to perforate with 2.75" modular StimGuns loaded 6 SPF 60 degree phased with 12.5 gram Super DP charges. Radio silence is not necessary. Pick up Modular StimGun perforating equipment as follows: a. Gun space-out rod thirteen (13) feet in length b. 2.75" OD, Modular 6 SPF, 60 degree phased, 12.5 gram, DP charges loaded to perforate the Tyonek from 7,260-7,345' (85 feet of Tyonek perforations) w/24' of propellant (18' on lower gun and 6' on the base of the upper gun). c. Pyrotechnic Delay Firing Device with 4 delays (will allow 16-19 minutes prior to firing). The number of delays may vary based upon actual time out of the hole from earlier tests. 23. RIH w/slickline firing head and activate detonation sequence. Pull out of hole above swab valve and wait for guns to fire. Monitor surface pressure. RIH and retrieve guns and gun space out rod. RD slickline service. 24. Flow test well to unload liquid. Approximately 17.3 bbls of fluid should be resident in wellbore from fluid level to mid perf. Following liquid recovery care should be taken to flow well at a 50% to 60% drawdown, 1110 psig to 890 psig FTP respectively. Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. The unloading rate up 4-1/2" tubing is attached but is 4.5 MMCFGPD @ 1,000 psig FTP. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with questions B. Schoffmann 907-564-6471. NO FLOW CONTINGENCY (Steps #25 & 26) If wellbore does not flow, proceed to Step #25. If well flows, proceed to Step #27. 25. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 7,302' mid perf. COH making same gradient stops. RD slickline equipment. 26. RU CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at later time, if necessary. 27. Resume flow test of well as outlined above. Test is expected to consist of a 24-48 hour stabilized flow period. . A short (24-48 hour) PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. . If a PBU is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges set to land on CIBP at 7,358' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM ,~ ~, Page 5 of 10 · Perform transient tests as per reservoir engineering direction. · RU Slickline company. Pressure test lubricator to 3,000 psi. RIH and retrieve gauges making same gradient stops as when RIH. RD Slickline Unit. 28. Plug back Test #1 as follows: RU Schlumberger logging service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig. Dump bail 1 0' (3/4 sk) of cement onto top of CIBP at 7,358' MD. PU Halliburton 4-1/2" 10K Composite FAS-DRILL bridge plug w/Baker 10 setting tool and GR tool. RIH, correlate depth and set Composite BP at 7,121' (13' below depth of Test #2 bottom perf). Depth may vary based upon CCL. RD SLB. Note fluid level while setting plug. Must have 500 psig of fluid over top of perforation interval. If necessary, lubricate in necessary 6% KCL water to yield 500 psig of liquid hydrostatic. Thus the fluid level must be at 5,950' MD in this well to perforate the 7,065' Sand. 29. Resume operation of Halliburton test equipment. Bleed well down to 575 psig tubing pressure. This will provide approximately a 50% draw down while perforating or a 1075 psig BHP. This step will vary depending upon fluid level observed in previous step. TEST #2 7.065' Sand Total 7.065'-7.108' 43' NOTE: The SBHP of this Tyonek sand is approximately 2,154 psia (0.304 psi/ft gradient) 30. RU crane with 70' of boom. RU Pollard Slickline equipment and 0.125" wire. Perform wire twist test. Install full lubricator. Hold Safety and environmental awareness meeting. Pressure test surface equipment to 3,000 psig. 31. Prepare to perforate with 2.75" modular StimGuns loaded 6 SPF 60 degree phased with 12.5 gram Super DP charges. Radio silence is not necessary. Pick up Modular StimGun perforating equipment as follows: a. Gun space-out rod thirteen (13) feet in length. b. 2.75" OD, Modular 6 SPF, 60 degree phased, 12.5 gram, DP charges loaded to perforate the Tyonek from 7,065-7,108' (43 feet of Tyonek perforations) w/21' of propellant. c. Pyrotechnic Delay Firing Device with 4 delays (will allow 16-19 minutes prior to firing). The number of delays may vary based upon actual time out of the hole from earlier tests. 32. RIH w/slickline firing head and activate detonation sequence. Pull out of hole above swab valve and wait for guns to fire. Monitor surface pressure. RIH and retrieve guns and gun space out rod. RD slickline service. 33. Flow test well to unload liquid. Approximately 17.3 bbls of fluid should be resident in wellbore from fluid level to mid perf. Following liquid recovery care should be taken to flow well at a 50% to 60% drawdown, 1075 psig to 860 psig FTP, respectively. Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. The unloading rate up 4-1/2" tubing is Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM ,~ ,----.. Page 6 of 10 attached but is 4.5 MMCFGPD @ 1,000 psig FTP. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with questions B. Schoffmann 907-564-6471. NO FLOW CONTINGENCY (Steps #34 & 35) If wellbore does not flow, proceed to Step #34. If well flows, proceed to Step #36. 34. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 7,086' mid perf. COH making same gradient stops. RD slickline equipment. 35. RU CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at later time, if necessary. 36. Resume flow test of well as outlined above. Test is expected to consist of a 24-48 hour stabilized flow period. · A short (24-48 hour) PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. · If a PBU is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges set to land on Composite BP at 7,121' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. · Perform transient tests as per reservoir engineering direction. · RU Slickline company. Pressure test lubricator to 3,000 psi. RIH and retrieve gauges making same gradient stops as when RIH. RD Slickline Unit. 37. Plug back Test #2 as follows: RU Schlumberger logging service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig. PU Halliburton 4-1/2" 1 OK Composite FAS-DRILL bridge plug w/Baker 10 setting tool and GR tool. RIH, correlate depth and set Composite BP at 6,888' (13' below depth of Test #3 bottom perf). Depth may vary based upon CCL. RD SLB. Note fluid level while setting plug. Must have 500 psig of fluid over top of perforation interval. If necessary, lubricate in necessary 6% KCL water to yield 500 psig of liquid hydrostatic. Thus the fluid level must be at 5,733' MD in this well to perforate the 6,843' Sand. 38. Resume operation of Halliburton test equipment. Bleed well down to 540 psig tubing pressure. This will provide approximately a 50% draw down while perforating or a 1040 psig BHP. This step will vary depending upon fluid level observed in previous step. TEST #3 6.843' Sand Total 6,843'· 6.875' 32' NOTE: The SBHP of this Tyonek sand is approximately 2,080 psia (0.304 psilft gradient) Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM , .---... . ,---- , Page 7 of 10 39. RU crane with 70' of boom. RU Pollard Slickline equipment and 0.125" wire. Perform wire twist test. Install full lubricator. Hold Safety and environmental awareness meeting. Pressure test surface equipment to 3,000 psig. 40. Prepare to perforate with 2.75" modular StimGuns loaded 6 SPF 60 degree phased with 12.5 gram Super DP charges. Radio silence is not necessary. Pick up Modular StimGun perforating equipment as follows: a. Gun space-out rod thirteen (13) feet in length. b. 2.75" aD, Modular 6 SPF, 60 degree phased, 12.5 gram, DP charges loaded to perforate the Tyonek from 6,843'-6,875' (32 feet of Tyonek perforations) w/16' of propellant. c. Pyrotechnic Delay Firing Device with 4 delays (will allow 16-19 minutes prior to firing). The number of delays may vary based upon actual time out of the hole from earlier tests. 41. RIH w/slickline firing head and activate detonation sequence. Pull out of hole above swab valve and wait for guns to fire. Monitor surface pressure. RIH and retrieve guns and gun space out rod. RD slickline service. 42. Flow test well to unload liquid. Approximately 17.3 bbls of fluid should be resident in wellbore from fluid level to mid perf. Following liquid recovery care should be taken to flow well at a 50% to 60% drawdown, 1040 psig to 830 psig FTP, respectively. Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. The unloading rate up 4-1/2" tubing is attached but is 4.5 MMCFGPD @ 1,000 psig FTP. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with questions B. Schoffmann 907-564-6471. NO FLOW CONTINGENCY (Steps #43 & 44) If wellbore does not flow, proceed to Step #43. If well flows, proceed to Step #45. 43. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 6,859' mid perf. COH making same gradient stops. RD slickline equipment. 44. RU CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at a later time, if necessary. 45. Resume flow test of well as outlined above. Test is expected to consist of a 24-48 hour stabilized flow period. . A short (24-48 hour) PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. . If a PBU is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges set to land on Composite BP at 6,888' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM '----', ,~ Page 8 of 10 . Perform transient tests as per reservoir engineering direction. . RU Slickline company. Pressure test lubricator to 3,000 psi. RIH and retrieve gauges making same gradient stops as when RIH. RD Slickline Unit. 46. Plug back Test #3 as follows: RU Schlumberger logging service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig. PU Halliburton 4-1/2" 10K Composite FAS-DRILL bridge plug w/Baker 10 setting tool and GR tool. RIH, correlate depth and set Composite BP at 6,788' (13' below depth of Test #3 bottom perf). Depth may vary based upon CCL. RD SLB. Note fluid level while setting plug. Must have 500 psig of fluid over top of perforation interval. If necessary, lubricate in necessary 6% KCL water to yield 500 psig of liquid hydrostatic. Thus the fluid level must be at 5,640' MD in this well to perforate the 6,750' Sand. 47. Resume operation of Halliburton test equipment. Bleed well down to 525 psig tubing pressure. This will provide approximately a 50% draw down while perforating or a 1025 psig BHP. This step will vary depending upon fluid level observed in previous step. TEST #4 6.750' Sand Total 6.750'· 6.775' 25' NOTE: The SBHP of this Tyonek sand is approximately 2,050 psia (0.304 psilft gradient) 48. RU crane with 70' of boom. RU Pollard Slickline equipment and 0.125" wire. Perform wire twist test. Install full lubricator. Hold Safety and environmental awareness meeting. Pressure test surface equipment to 3,000 psig. 49. Prepare to perforate with 2.75" modular StimGuns loaded 6 SPF 60 degree phased with 12.5 gram Super DP charges. Radio silence is not necessary. Pick up Modular StimGun perforating equipment as follows: a. Gun space-out rod thirteen (13) feet in length. b. 2.75" 00, Modular 6 SPF, 60 degree phased, 12.5 gram, DP charges loaded to perforate the Tyonek from 6,750'-6,775' (25 feet of Tyonek perforations) w/12' of propellant. c. Pyrotechnic Delay Firing Device with 4 delays (will allow 16-19 minutes prior to firing). The number of delays may vary based upon actual time out of the hole from earlier tests. 50. RIH w/slickline firing head and activate detonation sequence. Pull out of hole above swab valve and wait for guns to fire. Monitor surface pressure. RIH and retrieve guns and gun space out rod. RD slickline service. 51. Flow test well to unload liquid. Approximately 17.3 bbls of fluid should be resident in wellbore from fluid level to mid perf. Following liquid recovery care should be taken to flow well at a 50% to 60% drawdown, 1025 psig to 820 psig FTP, respectively. Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. The unloading rate up 4-1/2" tubing is Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM ~ ,..---..., Page 9 of 10 attached but is 4.5 MMCFGPD @ 1,000 psig FTP. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with questions B. Schoffmann 907-564-6471. NO FLOW CONTINGENCY (Steps #52 & 53) If wellbore does not flow, proceed to Step #52. If well flows, proceed to Step #54. 52. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 6,763' mid perf. COH making same gradient stops. RD slickline equipment. 53. RU CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at a later time, if necessary. 54. Resume flow test of well as outlined above. Test is expected to consist of a 24-48 hour stabilized flow period. · A short (24-48 hour) PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. · If a PBU is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH w/tandem quartz electronic gauges set to land on Composite BP at 6,788' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. · Perform transient tests as per reservoir engineering direction. · RU Slickline company. Pressure test lubricator to 3,000 psi. RIH and retrieve gauges making same gradient stops as when RIH. RD Slickline Unit. 55. Following completion of testing. Lubricate in BPV's and winterize tree. Chain closed the master valves and secure location. CONTACTS Ken Walsh: 907 -564-6305 (w) 907-268-5660 (p) Gary Eller: 907-564-6315 (w) 907 -268-0411 (p) David Brimberry: 907-564-6402 (w) 907 -231-0630 (p) Weich un Chu: 303-794-3863 (w) Wayne Cissell: 907-283-1308 (w) 907-262-3620 (p) John Gilbert: 713-296-2981 (w) Ben Schoffmann: 907-564-6471 (w) Susan Dionne #1 Tyonek Workover Procedure KDW - 10/18/2001 9:10 AM ~ . " '1usan Dionne #1 144' FSL, 1488' FEL (Surface Location) Sec 6, T1 N-R13W, S.M. Pre-Workover Wellbore Diagram 20" 59 & 78.6ppf H-2J @193' *cut off at surf 13 5/8" 54.5 & 78.6ppf J-55 @ 2046' *cut off at surface Beluga Perfs 3776'-3786' (ELM) Isolation squeeze perfs 3761' and 3824' Plug #3 7,400'-7,450' Plug #2 10,350'-10,450' Plug #1 10,600'-10,700' (~) ~ ~ :i:'¡ I '~~ 2-7/8",6.5 ppf N-80 tubing 9-5/8" Otis Triple Retrievable Packer set at 3,661' MD CIBP at 3,890' MD 9-5/8" 40&47ppf N-80 at )' MD 7430' MD ''-''''. ~usan Dionne #1 144' F",_, 1488' FEL (Surface Location) Sec 6, T1 N-R13W, S.M. Post Workover Wellbore Diagram :;:: ~:u~:~:t ~~~o I 13 5/8" 54.5 & 78.6ppf J-55 @ 2046' *cut off at surface Isolated Beluga Perfs 3776'-3786' (ELM) Isolation squeeze perfs 3761' and 3824' Proposed Tvonek Perfs: 6750'-6775' (25') 6843'-6875' (32') 7065'-7108' (43') 7260'-7345' (85') Plug #3 7,400'-7,450' Plug #2 10,350'-10,450' Plug #1 10,600'-10,700' -...:¡ , ,.~ , :;;t ~ œ .., li~ Ii ~ ~ ;~ .. tic' New Casing to 7415' 4-1/2" 12.6, N-80 mod. butt Original Casing to 7430' 9-5/8" 40&47ppf N-80 (IJ!!) ~ .~ ~~~~æ (ID~ ~~~~[K(~ AIASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 26, 2001 Mr. Ken D. Walsh Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Re: Susan Dionne #1 Marathon Oil Company Permit No: 185-208 Sundry Approval No: 301-300 Sur Loc: 144' FSL, 1488' FEL, Sec. 6, TIN, R13W, SM Dear Mr. Walsh: Enclosed is the approved sundry application to re-enter and workover or abandon the above referenced well. Under separate cover, you have applied for approval to sidetrack the well if this reentry and workover is not successful. That application will be approved separately. This permit approval does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting operations until all other required permitting determinations are made. A spacing exception is required to test this well. Such exception will be considered by the Commission separately. Waste fluids generated from this testing operation must be disposed of in an approved manner. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.285 or 25.035 as appropriate. Sufficient notice (approximately 24 hours) of the CTU BOPE tests, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, b=o~ Chair BY ORDER OF THE COMMISSION DATED thisJ26îay of November 2001 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ..-...., ~ Marathon Oil Company C' Alaska Region Domestic Production v P.O. Bcax 196168 Anchor-age, AK 99519-6168 Telephc:me 907/561-5311 Fax 907/564-6489 September 6, 2001 1&5 - ~oi ';)0 1 - I ~ } lÎ9~Olo I ~1-0)3 Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Re: Well re-naming Dear Mr. Maunder: Marathon Oil Company, as operator, requests the Union Oil Company Ninilchik Unit No. 1 (A. K.A. The McCoy Prospect No.1), Lease No A-648, be re-named as Susan Dionne #1 (SO #1). If it is sidetracked, it will be re-named SO #.... RD. If you have any questions concerning this matter, please contact me at 564-6319. Sincerely, at~ Peter K. Berga Drilling Superintendent bjv N:\DRLG\Susan Dlonne\Name chg.doc I?E:" CE"IV¿:;: S[p 0 D -4¡asÆ-a 01/ Ô ¿ 0 0 ! & Go~ GuC -4l7ch Ons. Co orage '0f17iSS . 10/) .. ~ Marathon Oil Company August 31,2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 West ih Ave. Suite 100 Anchorage, Alaska 99501 Reference: Well Susan Dionne #1 Dear Mr. Maunder: ~ Alaska Ret Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 VJ6A IZ.. ¡C-l- / 0 l Jí¡tH.. r-v/úLf/ò¡ Enclosed is the application for permit to drill the referenced well and a check for $100.00. Please advise if additional information is required. Sincerely, rJ(~ P. K. Berga Drilling Superintendent PKB:bjv N: Drlg/union-NinilchiklsSusandionneaogcccvlet.doc Enclosure ORIGINAL A subsidiary of USX Corporation RECEIVED S£p 0 6 2001 AlaSka 0" & G as Cons. C . Anchorage ornrrnSSiO/ì Environmentally aware for the long run. ~ ~ THIS DOCUMENT IS VOID IF RED COLOR BACKGROUND IS ABSENT ........ ......... ....... . ,___,.n. .___. :.:.,:.,-.,- '..,....... .,.--,-,'---" ".:.',-.'-;-.-'-,,""':.:<.-.;:'- '.'-:----',' ',' ....:-......_..': .>,.-'-.', '.,..---.:....-.-. ._...-....,-,........-.--. \\?RM~~? RE)\\(~(i. ..... .!1;;¡yJºJh~..Q[i::!€Wºf:. ... .. .,,' " ._._'·0 Marathon Oil Comoany ANCHORAGE ALASKÂ 015.8\ 57 1252 ,-.;';'..'" j\ì.ä.i$k,å. OH&Gas Conservation j3.~.jWe~t:7thAve,Suite 100 ..:;;A@~hc>ragE:, AK99501 Commission 08/3J/01 MO DY YR $ 100.00 .::...:- .. . . "':" :'~..:,. ....'C~..... ·.::?;~:¡~::A::::· .... \P?y: VOID . .' .................... ..... THE AMOUNTI~~UMB~RSMUSTMATj~!H0i0~UNTl~\0'ºRD~. .. .. .pOLLARS i . . .................. ..... .·..C>r1.~h~tl~rëdialld .. 00/00..................-...................-..........................................................---------------- . . NÂ110~~Š~AN~OF ALASKA B ~ ____~()[¡Oil Company ANGHOFIAGE ALASKA ..y__.:.~_S~_:::L._ · nu'_"''-' Ii \i,: I =I ;1~~~ :c:.];f..: I ¡.-} II. Iii ij~'¡:i ~ í.:.!.] ~ ~ ;,~ I ~ ¡.~ ~ W":t 11:i [t:lT:.' .w~~ I ~;1 M:.';1:~: ['].I~~:~~'J ~t~~;;'~'ll ~'¡! ~~. III 0 0 ~ 5 ~ 5 III I: ~ 2 5 2 0 0 OS? I : 0 ~ III 0 ? 8 5 b g III I" . A.F. . I AécT. CODE NON-REPORTING 100% REi'ORTABLE INTf:REST IF _____- -T - REPORTABLE I RENTS ___ _ ¡__ INDICATE SERVICES . TYPE OF NON.EMPLOYFE COMP i- PAYMEN r -' Filing Fee for Permit to Drill Union-Ninilchik 111 RD -7 .5ú.>/I-"J J), ~ """"'/I(.i) ,"'-'-' .----", TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ~ ' -:If WELL NAME~ v5Cl-1-L --f)-r&-J1 11..6 I CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wellbore segment of existing well -' Permit No, API No. (If api number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. ---- DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and REDRILL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from / records, data and logs acquired for well (name on permit). I EXPLORAT7 ANNULWSPOSAL Annular disposal has not been requested. . . NO INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L-J YES , INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . RED RILL THIS WELL , DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-J YES + SP ACIN7EPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates ) "ì. c o z o -t ~ ::u - -t m - z -t :t: - en » ::u m » redrll-L serv _ wellbore seg _ann. disposal para req _ UNIT# ,A/A ON/OFF SHORE ðn. ~. ., ;;J,L,b'"h. g~.~ 1/ot<ß ~c: A.n-~ ~7U~ 07L- ? Zl ' ~; N¿!rþ / ' ~ ~¡.ef'\i- ~ '! . 6Ç(~L-I tod, 6 C!... hõ4 ~ z;, A...bnO"Y~ r'"' -e::,cI-t:3/1 Commentsllnstructions: exp WELL PERMIT CHECKLIST FIELD & POOL _ Nil ADMINISTRA nON Permit fee attached. . . . . . . Lease number appropriate. .. Unique well name and number. . Well located in a defined pool. . . . . . . . . . . . . . . . Well located proper distance from drilling unit bounda~ Well located proper distance from other wells.. . . . Suffident acreage available in drilling unit.. . . . . . If deviated, is wellbore plat included.. . . . . . . . . Operator only affected party.. . . . . . . . . . . . . Operator has appropriate bond in force. . . . . . . . Permit can be issued without conservation order. . . Permit can·be issued without administrative approval Can permit be approved before 15-day wait. . COMPANY 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. sig. Conductor string provided .... . . . ... . Suñace casing protects all known USDWs. . .. . . CMT vol adequate to drculate on conductor & suñ csg. CMT vol adequate toüe-in long string to suñ csg. . . . CMT will cover all known productive horizons. . . . .. Casing designs adequate for C. T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved. Adequate weilbore separation proposed.. . . . . . . If diverter required, does it meet regulations . . . . . Drilling .fluid program schematic & equip list adequate BOPEs, do they meet regulation . . . . . . . . . BOPE press rating appropriate; test to '~DOO Choke manifold complies w/API RP-53 (May 84) . Work will occur without operation shutdbwn. . Is presence of H25 gas probable.. . ., . Permit can be issued wlo hydrogen sulfide measures. Data presented on potential overpressure zones Seismic analysis of shallow gas zones. . Seabed condition survey (if off-shore). . Contact name/phone for weekly progress 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. A~~. . DATE 9-2/)·0/ ENGINEERING f2~. .DHT p-' :? GEOLOGY DATE '·/Z·6/ AIl'PR Y N Y N Y N Y N. Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause drilling waste to suñace; . (C) will not impair mechanical integrity of the well used for disposal (D) will not damage produdng formation or impair recovery from a pool; and E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: UIC/Annular COMMISSION: DATE APPR WM 'v.i;A./[¿j'f/o ( il' 11/01/100) GEOLOGY: ~þ~ c:\msoffice\wordian\diana\checklist (rev. \,