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Home My WebLink About198-042THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Sterling Field, Beluga Undefined Gas Pool, SU 32-09 Permit to Drill Number: 198-042 Sundry Number: 319-173 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogc c.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ( �� J sie�elowski Commissioner DATED this ID day of April, 2019. RBDMSiLt! APR 1 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 0 4019 �r J �/cl/ Anrrr_ 9 1. Type of Request: Abandon Q ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Atter Casing ❑ Venting Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stmtigraphic ❑ Service ❑ 198-042 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20485-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Sterling Unit (SU) 32-09 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028063 Sterling Unit / Beluga Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): fish 6,858' 6,336' 6,072' (Fill) 5,635' 2,164 psi N/A 3.661'& 3,698' Casing Length Size MD ND Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# / N-80 5,909 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Halliburton PHL & Baker Model F 5,573' MD & 5,877' MD 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 10 Exploratory ❑ Stratigraphic ❑ Development 10 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title, Operations Manager Contact Email, tkramerCdhilcoru com Lt Contact Phone: 777-8420 Authorized Si nature: Date: 1 4 r Z O\ COMMIS ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3��I- I13 � Plug Integrity Z/ BOP Test Mechanical Integrity Test ❑ Location Clearance ElOther: > 2 5700 Si" /9 o/ -T'51— Atli X iok -yP/t] J Z�- AAc� ,�— Post Initial Injection MIT Yes ❑❑ No [:]- Spacing Exception Required?ired? Yes No � �/ Sf�Subsequent Form Required:/ Q Ll o — 7 T `�`' APR 11200 RIMMS;�— 9 APPROVED BY Approved by: j COMMISSIONER THE COMMISSION Date: I/ / Form 10 3 Revised 4/2017 Approved appl a " ialGol 1 o srom the date of approval. Attachments in Duplicate R ullrora Alaska, M Well Prognosis Well: SU 32-09 Date: 03/27/2019 Well Name: SU 32-09 API Number: 50-133-20485-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 198-042 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary: — 2,744 psi @ 5,801' TVD — 2,744 psi @ 5,801' TVD — 2,164 psi (Based upon a 0.473 psi/ft gradient to the deepest open perforation) (Based upon a normal gradient) (Based upon max. expected BHP and a 0.10 psi/ft gas gradient to surface) Sterling Unit 32-09 was drilled and completed in October 1998. SU 32-09 was initially completed in the Sterling B4 sand, as a gas producer. In December 2004, the Sterling B4 perforations were isolated with an Owen tubing patch, between packers. The well was successfully re -completed lower in the wellbore, in the Upper Beluga formation. Additional Beluga perforations were added in July and August 2013, without much success. SU 32- 09 was shut-in, in May 2014, and has remained shut-in through the present date. The purpose of this Sundry is to permanently P&A SU 32-09. Hilcorp asks for a Variance from 20 AAC 25.112 (c) (1) (E) and 43 CFR 3160 G 2. To isolate the Beluga perforations below the Baker Model F permanent packer, Hilcorp proposes to set a CIBP on top of the packer (following removal of the 3-1/2" tubing string). This request is a result of "Fish" in the tubing string which prevents isolating the Beluga perforations with an expandable thru-tubing type plug. The proposed CIBP placement will result in the bridge plug being set approximately 210' above the top Beluga perforation. 35' of cement will be dump bailed on top of the CIBP, in accordance with 20 AAC 25.112 (c) (1) (E) and 43 CFR 3160 G 2. Note that a second CIBP will be set directly above the Sterling B4 perforations, in accordance with abandonment regulations. Pre - Rig Work: 1. Provide 24 hour notice to the AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 25.112 (h). Notify the ELM of P&A as per 43 CFR 3160 G. 2. RU Pump Truck. RU on tubing and casing and conduct an IA pressure test to 2,500 psi on chart for 30 min. Bleed down pressure. 3. MIRU Pine. 4. PU & RIH w/ tubing punch to "'3,660'. Punch holes from "'3,660' to -3,656'. POOH. a. Note: Fish (BL Tool String) in tubing string @ 3,661'. 5. RU Pump Truck and circulate well with a 9.8 ppg kill weight fluid. H Hilcarp Alaska, LU Workover Rig 401: Well Prognosis Well: SU 32-09 Date:03/27/2019 6. MIRU workover rig 401. 7. Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. 8. Set back pressure valve. 9. NDwellhead, NU BOP and test to 250 psi low & 2,600 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Test VBR rams on 3-1/2" test joint. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. Copy to BLM. 10. PU and POOH w/ 3-1/2" tubing string, laying down chemical injection line & bottom hole assembly and racking back pipe. a. Pull Halliburton PHL retrievable packer @ 5,573'. Zb. Pull seal bore ouT—of Baker Model F permanent packer @ 5,877' 11. Make certain that the wellbore remains dead when pulling the tubing string. 12. MIRU E -line. Pressure test lubricator to 3,000 psi. 13. PU & RIH w/ 1117" CIBP to 5,875' (just above Baker Model F packer). Set same depth. POOH. 14. PU & RIH w/ Dump Bailer. Dump bail 35' of Cement on top of the CIBP @ —5,875'. $,V a. TOC @ —5,840'. 15. PU & RIH w/ 2 7" CIBP to —5,675'. Set same depth. POOH. 16. PU & RIH w/ Dump Bailer. Dump bail 3 of Cement on top of the CIBP @ —5,675'. 1' © a. TOC @ `5 640'. 'r4 W.» e 5e 'a Note: Drilling records indicate that both the Surface Casing and Production Casing strings were cemented to surface. Cementing records show —20 bbls of returns to surface for the surface casing and —30 bbls of returns to surface for the production casing. Thus the surface casing shoe is isolated on the 7" annulus. In compliance with abandonment regulations, Hilcorp will place cement inside the 7" casing, extending at least 100' above and below the surface casing shoe depth. P3 17 re) 18 19 20 21. 22. l 23. 24. 25. 26. 27. 28. PU 3`d 7" CIBP and RIH on 3-1/2" tubing. Set 7" CIBP @ —2,236' ('"125' below the surface casing shoe). Unlatch from CIBP and PU tubing 5'. RU cementers and place a 250' balanced plug of 15.8 ppg cement on top of the CIBP. a. Top of Cement (TOC) should be at "'1,986' MD (125' above surface casing shoe). POOH w/ 3-1/2" tubing, racking back pipe. WOC. PU 41h 7" CIBP and RIH on 3-1/2" tubing. Set CIBP @"'160'. Unlatch from CIBP and PU tubing 5'. RU cementers and place a 160' balanced plug of 15.8 ppg cement on top of the CIBP. a. TOC @ surface POOH w/ 3-1/2" tubing, laying down pipe. WOC. Place dry hole tree on well. RDMO Rig 401. Well Prognosis Well: SU 32-09 Hilcara Alaska, LU Date: 03/27/2019 Post - Rig Abandonment Procedures: 29. Excavate cellar, cut off casing 3' below natural GL. 30. Notify AOGCC` and BLM 48hrs in advance. 31. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 198-042 c. Well Name: SU 32-09 d. API: 50-133-20485-00 32. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 33. Photo document casing cut-off and Welded Plate install. 34. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Permit#: 198-042 API #: 50-133-20485-00-00 Prop. Des' BLM: A - 028063 DNR: ADL -02497 KB elevation: 265' (28' AGL) Latitude: Longitude: Spud: 10/18/1998 TD: 10/28/1998 Rig Released: 11/8/1998 Carrico KBUG-LTS Chemical Injection Mandrelw/ 1/4" (.049 wall) Chemical injection line @ 998'(1" chemical injection valve installed 2/12/99) McMurry SMO-1Gas Lift Mandrel @ 5,521' (1" dummy valve installed 2/15/99) Halliburton PHL Retrievable Packer @ 5,573' Halliburton XU sliding Sleeve @ 5,630' w/X-Profile (ID 2.813", Closed 4/22/04) Owen tubing patch (ID -2,25") @ 5,662'- 5,694' `Locator sub @ 5,677' 'Baker Model F Permanent Packer w/ 10'seal bore @ 5,877' X -NSI glg (ID 2.813") @ 5;896' V�reline re-entry guide @ 5,909' Tag fill @ 6,072' SLM (4/25/14) 2.00" Drive Down Bailer Fish (27' of 2" HC, spangs, CCL) @ 6,443' MD IRKS (7/26/13) SU 32-9 Pad SU 43-9 2,312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. lot - Fish (BL Tool String) 3,661' SLM (5/14114) Fish (SL Tool String) 3,698' SLM (4/26/14) ACTUAL SCHEMATIC Conductor 13-3/8" K-55 68 ppf Top Top Bottom MD Surf 80' TVD Surf 80' Surface Casino 9-5/8" P-110 47 ppf BTC Top Bottom MD 0' 2,111' TVD 0' 2,072' 12-1/4" hole Cmt w/ 620 sks of Class G, -20bbl of returns to surface Production Casina Perforations: 7" L-80 29 ppf BTC Top Bottom MD 0' 6,858' TVD 0' 6,336' 8-1/2" hole Cmt w/ 690 sks of class G' -30 bible of returns to surface Production Tubing Perforations: 3-112" N-80 9.3 ppf AS -Mod 10' 5,279' - 5,288' 2-1/2", 6 spf, 60° (11/5/98) Top Bottom 8rd MD Surf 5,909' TVD Surf 5,487' Isolated Sterlina Perforations: MD Ft TVD Gun Date 34 5,679' - 5,689' 10' 5,279' - 5,288' 2-1/2", 6 spf, 60° (11/5/98) Isolated with Owen Special 226" ID Clearance Patch (1218104) Upper Beluga Perforations: 6,086' -6,098' 12' 5,64T - 5,658' 2.1/8" Strip Guns (7/06/13) 6,098' -6,113' 15' 5,658' .5,671' 1.11/16" Owen Swg Jet (12/12104) 6,113' -6,128' 15' 5,671' -5,685' 141/16" Owen Swg Jet (12/12/04) :i • . TD PBTD 6,858' MD 6,820' MD 6,336'TVD 6,302'7VD 6,180' 10' 5,722' - 5,731' 2-118" Strip 6 spf (8/17113) 6,180' 10' 6,722'.6,731- 1.11/16" Strip 6 spf (8117113) 6,258' 12' 5,790'-5,801- 2" HC Big Hole 6 spf (7/26/13) Fish (10' of 2-1/8" spiral strip gun) Unknown depth (7/06/13) Well Name & Number: Sterling Unit SU 32-09 Lease: A - 028083 /ADL - 02497 County or Parish: Kenai Peninsula BoroughState/Prov: Alaska Country: USA Angle @KOP and Depth: 1.5-110 0 ft 900' Angle/Perfs: 26° Maximum Deviation: 29° @ 2,996' Date Completed: 11/05/98 Ground Level (above MSL): 237' RKB (above GL): 28' Revised By: Stan Porhola Downhole Revision Date: 5/15/2014 Schematic Ren Date: 7/19/2014 visio Il il"rp Alaska, LLC 198-042 50-133-20485-00-00 BLM: A-028063 DNR: ADL .02497 1 elevation: 265' (28'AGL) Longitude: Spud: 10/18/1998 TD: 10/28/1998 Rip Released: 1118/1998 CIBP @ 160'w/ Cement to Surface CIBP @ -2,236' w/ 250' of Cement across csg shoe (TOC @ -1,986') CIBP @ -5,675' w/ 35' of Cement on top (TOC @ -5,640') CIBP @ -5,875' w/ 35' of Cement on top (TOC @ -5,840') SU 32-9 Pad SU 43-9 2,312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. �C� C - IFS 9 C f%p 9 a= PROPOSED SCHEMATIC Conductor 13,3/8" K55 68 ppf Top Top Bottom MD Surf 80' TVD Surf 80' Surface Casing 9-5/8" P-110 47 ppf BTC Top Bottom MD 0' 2,111' TVD 0' 2,072' 12-1/4" hole Cant w/ 620 sks of Class G, -20bb1 of returns to surface Production Casing Sterling Unit SU 32.09 7" L-80 29 ppf BTC Top Bottom MD 0' 6,858' TVD 0' 6,336' 8412" hole Cmt w/ 690 sks of class G' -30 We of returns to surface Well Name & Number: Sterling Unit SU 32.09 D A - 028083 / ADL - 02497 County or Parish: Kenai Peninsula Borough 'Locator sub @ 5,877' Alaska Count7F USA Angle @KOP and Depth: ' Maximum Deviation: 29° @ 2,996' 'Baker Model F Permanent Packer 11105/98 Ground Level (above MSL): 237' RKB (above GL): 28' Revised By: Paul Winslow Downhole Revision Date: 5115120141 Isolated Sterling Perforations: w/ 10' seal bore @ 5,877' p MD Ft TVD Gun Date B4 5,679' -5,689' 10' 5,279' -5,288' 2-112", 6 spf, 60° (11/5/98) Isolated with Owen Special 2.25" 10 Clearance Patch (12/8104) 896- XX-N�� (ID 2.813") @ 5,696' Upper Beluga Perforations: Wireline re-entry guide @ 6,066' -6,098' 12' 6,647' -5,658' 24/8" Strip Guns (7/06113) Tag fill @ 6,072' SLM (4/25/14) 6,098' -6,113' 15' 5,658'- 5,671' 1-11/16" Owen Swg Jet (12/12(04) 2.00" Drive Down Bailer 8,113'.6,128' 15' 5,671' - 5,685' 1-11116" Owen Swg Jet (12/12104) i•4•i:y?' • 1.1.1.7• 6,170'.6,180' 10' 6,72T .5,731' 2-1/8" Strip 6 apt (8/17/13) $:}}j;p, 6,170'-6,180' 10' 5,72T -5,731' 1-11/i6"Strip 6spf (8/17/13) a�itS�iti^'a>= 4i�i1i�i• 6,246' -6,258' 12' 5,790' -5,801' 2" HC Big Hole 6 apt (7/28113) ~lili%:1. 4.1j1f1j• 4f1l�lil• Fish (2T of 2" HC, spangs, CCL) ~l: ~ ..... �.. Fish (10' of 2-118" spire/ strip gun) @ 6,443' MD RKB (7/26113) {`•'• Unknown depth (7/06113) TD 1j1f4�tij• `fes -4•.• PBTD 6,85-87111113 0' MD 6,336' TVD±+- 0' TVD Well Name & Number: Sterling Unit SU 32.09 Lease: A - 028083 / ADL - 02497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Count7F USA Angle @KOP and Depth: I.S. 1100 ft @ 900' Angle/Perfs: 26' Maximum Deviation: 29° @ 2,996' Date Completed: 11105/98 Ground Level (above MSL): 237' RKB (above GL): 28' Revised By: Paul Winslow Downhole Revision Date: 5115120141 Schematic Revision Date: 312 612 01 9 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" SM HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" SM LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM FLANGE TO FLANGE 7-1/16" SM DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE —77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate -1.18 gallons to open per gate - 5.45:1 closing ratio - 1.93:1 opening ratio UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SU 32-09 (PTD 198-042) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials -HA K Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date 10,000,000 1,000,000 L Y 0 C� L a 100,000 If LL U O N to 10,000 atM L O w 0 u LL C 1,000 u Z 3 u v M 100 0 O L H 10 HILCORP ALASKA LLC, STERLING UNIT 32-09 (198-042) STERLING, UP BELUGA UNDEF GAS Monthly Production Rates 1Cum. Prod Water�119,091,778 IIIIII� 1 i17.�i MI1.�Imurr Yi- C7�11� S. Jan -2005 Jan -2010 Jan -2015 —•— Produced Gas (MCFM) a GOR - e - Produced Water (BOPM) @ Produced Oil (BOPM) 10,000,000 W m 1,000,000 In O M O 100,000 rD0 O 7 T 10,000 0 s W a 1,000 N 0 m 0 100 M O 3 10 S 1 Jan -2020 SPREADSH EET_1980420_SU_32-09_Prod -Inject_Curves_W ell_Gas_V 120_20190405.xlsx 4/5/2019 • • eV United States Department of the Interior QP �•°° �«°,..�u°° IN owe fir ,�, is al BUREAU OF LAND MANAGEMENT = Alaska State Office „ yqRc� g,� 222 West Seventh Avenue,#13 �l L1 ("•' Anchorage,Alaska 99513-7504 �� ' `� http://www.blm.gov/ak APR 1 2 2018 DIVISION OF In Reply Refer To: HJUN 2 0 1.01.014.U1OIL AND GAS NQ 3180 (AK930) APR 1 0 201 ,.1 Sterling Unit, AA0508871 CERTIFIED MAIL 7003 0500 0005 3216 1072 RETURN RECEIPT REQUESTED DECISION Hilcorp Alaska, LLC. . Dave Wilkins, Senior Vice President . 3800 Centerpoint Drive, Suite 1400 . Anchorage,Alaska 99503-5826 Federal Oil and Gas Unit Terminated Leases Extended The Sterling Unit, located in Kenai, Alaska, was approved as a Federal oil and gas unit, effective July 7, 1961 and currently contains 2,760 acres. There are Federal, State, private, and fee lease ownerships located within the unit boundary and three (3) development wells. Hilcorp Alaska, LLC. (Hilcorp)has been the designated operator for this field since February 2013. Per 43 CFR 3183.4(b), a unit agreement shall remain in effect as long as the public interest requirement is satisfied. Since April 2015,Hilcorp has not produced any unitized substance from this unit in paying quantity. In October 2017, the Bureau of Land Management(BLM) sent a 60-day Notice for Unit Termination to Hilcorp, allowing 60 days from receipt of the letter to commence reworking or drilling operations in the unit. Hilcorp did not respond to the Notice. Therefore,the BLM Authorized Officer has determined the public interest requirement for this unit has not been met. The Federal Sterling Unit Agreement,AA050887,is hereby terminated by the BLM, effective December 15, 2017. The Sterling Unit leases are extended for an additional two (2) years from the unit agreement termination date. S Hilcorp will continue to be bound by all lease terms, Federal, State, and private. Upon termination or relinquishment of said leases,Hilcorp will assume the responsibility to plug and abandon all wells, reclaim the lease site including pad(s),pipelines and roads, and remediate any environmental concerns to the satisfaction of the surface estate owner, Salamatof Native Association, Inc, and per terms of any Surface Use Agreement between Hilcorp and Salamatof. The existing Federal lease,A028135, will convert to annual rental status, with payment due to the Office of Natural Resources Revenue(ONRR) October 1st Hilcorp will no longer report any production or royalty to the Office of Natural Resources Revenue(ONRR)unless production occurs from the Federal lease A028135. This decision may be appealed to the Interior Board of Land Appeals, Office of the Secretary,in accordance with the regulations contained in the enclosed 43 CFR,Part 4, and Form 1842-1. If an appeal is taken,the notice of appeal must be filed in this office (at the above address)within 30 days from receipt of this decision. The appellant has the burden of showing that the decision appealed from is in error. Failure to file the notice of appeal with the Bureau of Land Management within the time allowed will result in dismissal of the appeal. In order to avoid dismissal of the appeal, there must be strict compliance with the regulations. W yne . Svejnoha Br Chief of Energy and Minerals Division of Resources Enclosures: 43 CFR,Part 4 and Form 1842-1 cc w/o enclosures: Hilcorp Alaska, LLC Kevin Tabler, Land Manager 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Department of Natural Resources Division of Oil and Gas Chantal Walsh,Director 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3563 • • cc w/o enclosures: Cook Inlet Region, Inc. Colleen Miller 725 E. Fireweed Lane, Suite 800 Anchorage,AK 99503 Salamatof Native Association, Inc Chris Monfor, President/CEO PO Box 2682 Kenai, AK 99611 Office of Natural Resources Revenue Diane Germain, Minerals Revenue Specialist MS 63300B PO Box 25165 Denver, CO 80225-0627 1A028063, A028135, AA050887A/B/C XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED COMMENTS: .Logs of various kinds Other, Scanned by: Beverly Mildred D'aretha ~Lowell Complete [3 TO RE-SCAN Notes: Re-Scan ned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ F O T I%%i ■ THE STATE Al, Ski Oil and Gas OfA LAsKA conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF ++rtrr " Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola scottEri NO I 0 3 2013 Operations Engineer 1 � Hilcorp Alaska, LLC 1°0 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Sterling Field, Beluga Undefined Gas Pool, Sterling Unit 32-09 Sundry Number: 313-390 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this�- day of August, 2013. Encl. •C J,'it- RECEIVED STATE OF ALASKA D JUL 1 8 n i3 � ALASKA OIL AND GAS CONSERVATION COMMISSION 81(11 APPLICATION FOR SUNDRY APPROVALS . GC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Wefl ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate el A Pull Tubing ❑ lime Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Orin Number. Hilcorp Alaska,LLC Exploratory ❑ Development ig 198-042 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: 50-133-20485-00 . Anchorage,Alaska 99503 8.Weil Name and Number: 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? CO 426 Sterling Unit(SU)32-09 Will planned perforations require a spacing exception? Yes ❑ No E l 9.Property Designation(Lease Number): 10.Field/Pool(s): a"((Jeti,y rc� o FEDA028063 Sterling Unit/Beluga A Pool 17) 7 `,/s 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 6,858' • 6,336' • 6,820' 6,302' N/A 6,686' Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/N-80 5,909' Packers and SSSV Type: Halliburton PHL;Baker Model F;N/A Packers and SSSV MD(ft)and ND(ft): 5,573'MD;5,877'MD;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development U Service U 14.Estimated Date for 15.Well Status after proposed work: 07/24/13 Commencing Operations: Oil ❑ Gas 0 - WDSPL ii Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola a,hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature id pea w ✓f. Phone 907-777-8412 Da te 7/g/ 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3130 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS AUG - 2 20<13\.' Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /D—y 011 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S ,!-/3 7 Si-/3 Submit Form and t Form 10-403(Revised 10/2012) ApprotaRcit6iivMfAltonths from the d e of approval. Attachment p v" 0 ,/, • Well Prognosis Well: SU 32-09 Hilcorp Alaska,LL Date:7/18/2013 Well Name: SU 32-09 API Number: 50-133-20485-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: July 24th, 2013 • Rig: N/A Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: July 24th, 2013 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 198-042 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(M) AFE Number: 1322183 Current Bottom Hole Pressure: —620 psi @ 5,685' ND (Static survey June 2013 below bottom zone 6,128' MD) Maximum Expected BHP: —2,700 psi @ 6,142'ND (Non-depleted Upper Beluga zone bottom at 6,640' MD) Max.Allowable Surface Pressure: —2,134 psi (Based on possible reservoir conditions and gas gradient to surface(0.10psi/ft) OBJECTIVE OF WIRELINE Add perforations to the Upper Beluga below the current perforated intervals. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU 2" 6 spf Hollow Carrier Big-Hole Guns. 3. RIH and perforate Upper Beluga interval from 6,640'-6,650' (1 run). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. 4. RU 2" 6 spf Hollow Carrier Deep Penetrating Guns. 5. RIH and perforate Upper Beluga interval from 6,640'-6,650' (1 run). 6. RU 2" 6 spf Hollow Carrier Big-Hole Guns. 7. RIH and perforate Upper Beluga interval from 6,540'-6,548' (1 run). 8. RU 2" 6 spf Hollow Carrier Deep Penetrating Guns. 9. RIH and perforate Upper Beluga interval from 6,540'-6,548' (1 run). 10. RU 2" 6 spf Hollow Carrier Big-Hole Guns. 11. RIH and perforate Upper Beluga interval from 6,246'-6,258' (1 run). 12. RU 2" 6 spf Hollow Carrier Deep Penetrating Guns. 13. RIH and perforate Upper Beluga interval from 6,246'-6,258' (1 run). 14. RU 2" 6 spf Hollow Carrier Big-Hole Guns. 15. RIH and perforate Upper Beluga interval from 6,170'-6,180' (1 run). 16. RU 2" 6 spf Hollow Carrier Deep Penetrating Guns. 17. RIH and perforate Upper Beluga interval from 6,170'-6,180' (1 run). 18. RD E-line. 19. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • • • IISU 32-9 ACTUAL na \k ,.„„„ uis.. l l t' 2,312'PaSSU449' FEL, SCHEMATIC Permit#: 198-042 Sec. 9, T5N, R10W, S.M. API#: 50-133-20485-00-00 , Prop.Des: ADL 028063 Conductor KB elevation: 265' (28'AGL) 13-3/8" K-55 68 ppf WBS#: - - Top Bottom Latitude: MD Surf 80' Longitude: ND Surf 80' Spud: 10/18/1998 TD: 10/28/1998 J A Rig Released: 11/8/1998 Surface Casing 9-5/8" P-110 47 ppf BTC r Top Bottom MD ND 0' 0' 2,111' Camco KBUG-LTS Chemical Injection 2,072' Mandrelw/1/4"(.049 wall)Chemical injection 12-1/4"hole Cmt w/620 sks of Class G, line @ 998'(1"chemical injection valve -20bbl of returns to surface installed 2/12/99) Production Casing 7" L-80 29 ppf BTC McMurry SMO-1Gas Lift Mandrel @ 5,521' Top Bottom (1"dummy valve installed 2/15/99) MD 0' 6,858' ND 0' 6,336' 8-1/2"hole Cmt w/690 sks of class G' r I -30 bbls of returns to surface ` Halliburton PHL Retrievable Packer @ 5,573' I i I Production Tubing I, 'I 3-1/2" N-80 9.3 ppf AB-Mod Halliburton XU sliding Sleeve @ 5,630' i Top Bottom 8rd w/X-Profile(ID 2.813",Closed 4/22/04) MD Surf 5,909' II..1 TVD Surf 5,487' a r� Owen tubing patch(ID-2,25") a @ 5,662'-5,694' Isolated Sterling Perforations: *Locator sub @ 5,877' " 1 MD Ft ND Gun Date *Baker Model F Permanent Packer B4 5,679'-5,689' 10' 5,279'-5,288' 2-1/2",6 spf,60° (11/5/98) w/10'seal bore @ 5,877' ft Isolated with Owen Special 2.25"ID Clearance Patch (12/8/04) I1 Upper Beluga Perforations: 6,086'-6,098' 12' 5,647'-5,658' 2-1/8"Strip Guns(7/06/13) X-Nipple(ID 2.813")@ 5,896' , 6,098 -6,113' 15' 5,658'-5,671' 1-11/16"Owen Swg Jet (12/12/04) Wreline re-entry guide @ 5,909' 6,113'-6,128' 15' 5,671'-5,685' 1-11/16"Owen Swg Jet (12/12/04) Tagged w/2.0"Bailer on(6/16/13) _ @ 6,686'MD RKB SLM o= a I Fish(10'of 2-1/8"spiral strip gun) i Unknown depth(7/06/13) TD PBTD 6,858'MD 6,820'MD 6,336'ND 6,302'ND Well Name&Number: Sterling Unit 32-9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska I Country:1 USA Perforations(MD): 5,679' -6,128' Perf(TVD): 5,279' -5,685' Angle A KOP&Depth: 1.5°/100' ft 900' MD Angle as Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28'(AGL) Revised by: Stan Porhola Revision Date: 7/06/2013 ." • • i IISU 32-9 PROPOSED llilcorp Alaska.UM 2,312'Pad L, 4449' FEL, SCH E M ATI C Permit#: 198-042 Sec. 9, T5N, R10W, S.M. API#: 50-133-20485-00-00 Prop.Des: ADL 028063 Conductor KB elevation: 265' (28'AGL) 13-3/8" K-55 68 ppf WBS#: - - Top Bottom 1 Latitude: MD Surf 80' Longitude: TVD Surf 80' Spud: 10/18/1998 TD: 10/28/1998 J Rig Released: 11/8/1998 Surface Casing 9-5/8" P-110 47 ppf BTC Top Bottom MD 0' 2,111' Camco KBUG-LTS Chemical Injection TVD 0' 2,072' hole Cmt w/620 sks of Class G, Mandrelw/1/4"(.049 wall)Chemical injection 20bb1 of returns to surface line @ 998'(1"chemical injection valve installed 2/12/99) • Production Casing 7" L-80 29 ppf BTC • McMurry SMO-1 Gas Lift Mandrel @ 5,521' Top Bottom (1"dummy valve installed 2/15/99) MD 0' 6,858' TVD 0' 6,336' 8-1/2"hole Cmt w/690 sks of class G' r -30 bbls of returns to surface Halliburton PHL Retrievable Packer @ 5,573' r; a I r Production Tubing li 3-1/2" N-80 9.3 ppf AB-Mod Halliburton XU sliding Sleeve @ 5,630' Top Bottom 8rd w/X-Profile(ID 2.813",Closed 4/22/04) MD Surf 5,909' 1 ... TVD Surf 5,487' =zii I iit= Owen tubing patch(ID-2,25") @ 5,662'-5,694' Isolated Sterling Perforations: 'Locator sub @ 5,877' 1 MD Ft TVD Gun Date *Baker Model F Permanent Packer ` #7 B4 5,679'-5,689' 10' 5,279'-5,288' 2-1/2",6 spf,60° (11/5/98) w/10'seal bore @ 5,877' :: d': Isolated with Owen Special 2.25"ID Clearance Patch (12/8/04) Upper Beluga Perforations: X-Nipple(ID 2.813")@ 5,896' 6,086'-6,098' 12' 5,647'-5,658' 2-1/8"Strip Guns(7/06/13) 098'-6,113' 15' 5,658'-5,671' 1.11/16"Owen Swg Jet (12/12/04) Wreline re-entry guide @ 5,909' /6:113'-6,128' 15' 5,671'-5,685' 1-11/16"Owen Swg Jet (12/12/04) 6,170'-6,180' 10' 5,722'-5,731' 2"HC 12 spf(Proposed) .a 6,246'-6,258' 12' 5,790'-5,801' 2"HC 12 spf(Proposed) II= 6,540'-6,548' 8' 6,053'-6,060' 2"HC 12 spf(Proposed) 6,640'-6,650' 10' 6,142'-6,151' 2"HC 12 spf(Proposed) f1 2 Tagged w/2.0"Bailer on(6/16/13) @ 6,686'MD RKB SLM Fish(10'of 2-1/8"spiral strip gun) I E Unknown depth(7/06/13) f TD I ` ^ PBTD 6,858'6,858'MD 6,820'MD 6,336'TVD 6,302'TVD Well Name&Number: Sterling Unit 32-9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska I Country: USA Perforations (MD): 5,679' -6,128' Perf(TVD): 5,279' -5,685' Angle KOP& Depth: 1.50/100' [cD_ 900' MD Angle A Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28'(AGL) Revised by: Stan Porhola Revision Date: Proposed :. C • STATE OF ALASKA JUL X 8 2013 • ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS O 1.Operations Abandon L] Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 198-042 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic p Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20485-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028063 Sterling Unit(SU)32-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Sterling Unit/Upper Beluga Undefined Gas 11.Present Well Condition Summary: Total Depth measured 6,858 feet Plugs measured N/A feet true vertical 6,336 feet Junk measured 6,686 feet Effective Depth measured 6,820 feet Packer measured 5,573;5,877 feet true vertical 6,302 feet true vertical 5,183;5,459 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,868' 6,336' 8,160 psi 7,020 psi Liner `+ r� Perforation depth Measured depth See Attached Schematic SCANNED NO u True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 5,909'MD 5,488'ND Halliburton PHL 5,573'MD;5,183'ND Packers and SSSV(type,measured and true vertical depth) Baker Model F 5,877'MD;5,459'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 140 554 Subsequent to operation: 0 948 8 160 341 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exe pt: 313-348 Contact Stan Porhola Email sporhola athilcorp.com Printed Name C Stan Porhola Title Operations Engineer Signature r� .Wfk.„ Phone 907-777-8412 Date--W/3 RBDMS JUL 2 4 24 Form 10-404 Revised 10/2012 /1?' 'r3 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SU 32-09 50-133-20485-00 198-042 7/6/13 7/10/13 Daily Operations: 07/06/2013-Saturday Pressure test lubricator to 250 psi low and 2500 psi high. RIH with 2-1/8" x 12', 4 spf, 60 degree phase strip gun and tie into Expro GR-CCL-GR log dated 12-8-04. Spot shot from 6,086'to 6,098'. Tubing had 650 psi. Fired shot and saw no change in pressure. POOH. All shots fired. Left 10' of the spiral strip in the tubing patch close to top. Rig down lubricator,turn well over to production and clean work area. Tubing pressure is 660 psi. 07/10/2013 -Wednesday PIT LIB &WLV 2,000 psi,good. RIH w/ 1.9" overshot baited w/2" RB to 5,688' KB w/tool, POOH. RIH w/2.7" LIB to 5,688' KB. Sit down 2 times, POOH. Impression of fishing neck of patch. RIH w/ 1.9" overshot baited w/2" RB to same w/tool, wouldnt pass, POOH. Rolled edges on overshot. RIH w/same w/2.20" centralizer to 5,909' KB w/re-entry guide, no obstruction, POOH. Rig Down SL moved to 41-15. SU 32-9 ACTUAL I Iileorp Alaska,LL(: 2,312' FSL, 449'9EL, SCHEMATIC Permit#: 198-042 Sec. 9, T5N, R10W, S.M. API#: 50-133-20485-00-00 Prop.Des: ADL 028063 Conductor KB elevation: 265' (28'AGL) 13-318" K-55 68 ppf WBS#: I - - L Top Bottom Latitude: MD Surf 80' Longitude: ND Surf 80' Spud: 10/18/1998 TD: 10/28/1998 Rig Released: 11/8/1998 Surface Casing 9-5/8" P-110 47 ppf BTC Top Bottom l ■ MD 0' 2,111' Camco KBUG-LTS Chemical Injection Ilk TVD 0' 2,072' Mandrelw/1/4"(.049 wall)Chemical injection 12-1/4"hole Cmt w/620 sks of Class G, line @ 998'(1"chemical injection valve -20bbl of returns to surface installed 2/12/99) Production Casing 7" L-80 29 ppf BTC McMurry SMO-1Gas Lift Mandrel @ 5,521' Top Bottom (1"dummy valve installed 2/15/99) MD 0' 6,858' ND 0' 6,336' 8-1/2"hole Cmt w/690 sks of class G' r -30 bbls of returns to surface Halliburton PHL Retrievable Packer @ 5,573' f Production Tubing rt `i 3-1/2" N-80 9.3 ppf AB-Mod Halliburton XU sliding Sleeve @ 5,630' Top Bottom 8rd w/X-Profile(ID 2.813",Closed 4/22/04) MD Surf 5,909' Ir', TVD Surf 5,487' Owen tubing patch(ID-2,25") a @ 5,662'-5,694' Isolated Sterling Perforations: *Locator sub @ 5,877' E MD Ft ND Gun Date *Baker Model F Permanent Packer t B4 5,679'-5,689' 10' 5,279'-5,288' 2-1/2",6 spf,60° (11/5/98) w/10'seal bore @ 5,877' Isolated with Owen Special 2.25"ID Clearance Patch (12/8/04) Upper Beluga Perforations: 6,086'-6,098' 12' 5,647'-5,658' 2-1/8"Strip Guns(7/06/13) X-Nioole(ID 2.813")@ 5,896' 6,098'-6,113' 15' 5,658'-5,671' 1-11/16"Owen Swg Jet (12/12/04) Wreline re-entry guide @ 5,909' 6,113'-6,128' 15' 5,671'-5,685' 1-11/16"Owen Swg Jet (12/12/04) Tagged w12.0"Bailer on(6/16/13) ° @ 6,686'MD RKB SLM Fish(10'of 2-1/8"spiral strip gun) ' Unknown depth(7/06/13) L TD PBTD 6,858'MD 6,820'MD 6,336'ND 6,302'TVD Well Name&Number: Sterling Unit 32-9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska I Country:I USA Perforations(MD): 5,679'-6,128' Perf(TVD): 5,279' -5,685' Angle A KOP& Depth: 1.5°/100' 0 900' MD Angle(a, Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28' (AGL) Revised by: Stan Porhola Revision Date: 7/06/2013 RECEIVED STATE OF ALASKA JUL 1 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 1.Operations Abandon U Repair Well U Plug Perforations Li Perforate U Other(,:d Capstring Removal Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El , Exploratory ❑ 198-042 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20485-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028063 Sterling Unit(SU)32-09 r 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Sterling Unit/Upper Beluga Undefined Gas 11.Present Well Condition Summary: Total Depth measured 6,858 feet ' Plugs measured N/A feet true vertical 6,336 feet Junk measured 6,686 feet Effective Depth measured 6,820 feet Packer measured 5,573;5,877 feet true vertical 6,302 feet true vertical 5,183;5,459 feet Casing Length Size MD ND Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,868' 6,336' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED NOV 0 6 2013 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 5,909'MD 5,488'ND Halliburton PHL 5,573'MD;5,183'ND Packers and SSSV(type,measured and true vertical depth) Baker Model F 5,877'MD;5,459'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 187 217 Subsequent to operation:, 0 13 2 0 389 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development IS • Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 • WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Stan Porhola Email Sporhola( hilcorp.com Printed Name ®Stan Porhola Title Operations Engineer Signature021�(1,\._ Phone 907-777-8412 Date 7 (4 /3 _.".4.4..' 7.- 7.'J Form 10-404 Revised 10/2012 .A/' y1:1 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SU 32-09 50-133-20485-00 198-042 6/10/13 6/10/13 Daily Operations: 06/10/2013 - Monday Rig Up Cap String Truck. Rig up lubricator and adapter.Test to 3,000 psi. POOH w/3/8" capillary string. Full recovery of capillary string from 6,098'. RD cap string wellhead adapter. RDMO Cap String Truck. 9 • II SU 32-9 ACTUAL Pad 43-9 SCHEMATIC flilcorp Alaska.um: 2,312' FSL, FEL,EL, Permit#: 198-042 Sec. 9, T5N, R1OW, S.M. API#: 50-133-20485-00-00 Prop.Des: ADL 028063 Conductor KB elevation: 265' (28'AGL) 13-3/8" K-55 68 ppf WBS#: j - - Top Bottom Latitude: MD Surf 80' Longitude: TVD Surf 80' Spud: 10/18/1998 TD: 10/28/1998 Rig Released: 11/8/1998 Surface Casing 9-5/8" P-110 47 ppf BTC Top Bottom MD 0' 2,111' Ai 1 ilk Camco KBUG-LTS Chemical Injection ND 0' 2,072' Mandrelw/1/4"(.049 wall)Chemical injection 12-1/4"hole Cmt w/620 sks of Class G, line @ 998'(1"chemical injection valve -20bbl of returns to surface installed 2/12/99) Production Casing 7" L-80 29 ppf BTC McMurry SMO-1 Gas Lift Mandrel @ 5,521' Top Bottom MD 0' 6,858' (1"dummy valve installed 2/15/99) TVD 0' 6,336' 8-1/2"hole Cmt w/690 sks of class G' ' -30 bbls of returns to surface Halliburton PHL Retrievable Packer @ 5,573' I f Production Tubing E I 3-1/2" N-80 9.3 ppf AB-Mod Halliburton XU sliding Sleeve @ 5,630' Top Bottom 8rd w/X-Profile(ID 2.813",Closed 4/22/04) MD Surf 5,909' I b.! TVD Surf 5,487' L-*-- Owen tubing patch(ID-2,25") @ 5,662'-5,694' IN`Locator sub @ 5,877' ; Isolated Sterling Perforations: "Baker Model F Permanent Packer \ w/10'seal bore @ 5,877' c MD Ft ND Gun Date B4 5,679'-5,689' 10' 5,279'-5,288' 2-1/2",6 spf,60° (11/5/98) Isolated with Owen Special 2.25"ID Clearance Patch (1218/04) X-Nipple(ID 2.813")@ 5,896' #', Upper Beluga Perforations: Wreline re-entry guide @ 5,909' 6,098'-6,113' 15' 5,658'•5,671' 1-11/16"Owen Swg Jet (12/12/04) I ( 6,113'-6,128' 15' 5,671'-5,685' 1-11/16"Owen Swg Jet (12/12/04) Tagged w/2.0"Bailer on(6/16/13) @ 6,686'MD RKB SLM ==. acx- a if= Capillary String (Removed 06/12/13) TD PBTD 6,858'MD 6,820'MD 6,336'ND 6,302'ND Well Name&Number: Sterling Unit 32-9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska J Country:I USA Perforations (MD): 5,679'-6,128' Perf(TVD): 5,279'-5,685' Angle A KOP&Depth: 1.5°1 100' a 900' MD Angle A Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28'(AGL) Revised by: Stan Porhola Revision Date: 6/16/13 • � THE STATE h it Gas 49, OfA LA sKA Conservation Coission owl GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALASY' Main: 907.279.1433 Fax: 907.276.7542 Jeff Allen Reservoir Engineer jaC! " 0 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Sterling Field, Undefined Gas Pool, Sterling Unit 32 -09 S NEt) Sundry Number: 313 -348 Dear Mr. Allen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 4 0e4IP r No an Co: • - loner DATED this °// day of July, 2013. Encl. ' f • 0 .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS , . 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair We/ ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 115 . Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Ot1er. ❑ 2. Operator Name: y N Hilcorp Alaska, LLC Number. 4. Current We Class: 5. Permit to Drill Exploratory ❑ Development p • 198 -042 ` 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, Alaska 99503 50-133-20485-00 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 426 Sterling Unit (SU) 32-09 • Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): 10"-e sa, tc G� /,� �� i2 , / FEDA028063' Sterling Unit / Beluga- Peel+ .�, 4.4., 11. PRESENT WELL CONDITION SUMMARY P2. L f5 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,858' • 6,336' • 6,820' 6,302' N/A 6,686' Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13 -3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9 -5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2" 9.3# / N -80 5,909' Packers and SSSV Type: Halliburton PHL; Baker Model F; N/A Packers and SSSV MD (ft) and TVD (ft): 5,573' MD; 5,877' MD; N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 07/05/13 Commencing Operations: Oil ❑ Gas 0 . WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907 - 777 -8412 Email sporhola Printed Name Jeff Allen Title Reservoir Engineer Signature � ... Phone 907 - 777 -8440 Date 7 fZ /2d 13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: sJ ' 31 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ®�I� Other: RBDMS JUL - 3 201a'J Spacing Exception Required? Yes ❑ 0 it • bsequent Form Required: /0 --Li 0 "l APPROVED BY 1 Approved by: COMMISSIONER THE COMMISSION Date: 1 r , ^) ,. A 1_ 7.z.-t? Submit Form and V �� Form 10 -403 (Revised 10/2012) • p (pi • i _ i k 1p n r�2 months from the date of approval. Attachments in Dupl' to � ', `` L • • • Well Prognosis Well: SU 32 -09 Hilcoru Alaska, LL Date: 7/02/2013 Well Name: SU 32 -09 API Number: 50- 133 - 20485 -00 . Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: July 5 2013 Rig: N/A Reg. Approval Req'd? None Date Reg. Approval Rec'vd: None Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 198 -042 First Call Engineer: Stan Porhola (907) 777 -8412 (0) (907) 331 -8228 (M) Second Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) AFE Number: 1322026 Current Bottom Hole Pressure: — 620 psi @ 5,685' TVD (Static survey June 2013 below bottom zone 6,128' MD) Maximum Expected BHP: — 2,700 psi @ 5,658' TVD (Non- depleted Upper Beluga zone bottom at 6,098' MD) Max. Allowable Surface Pressure: — 2,134 psi (Based on possible reservoir conditions and gas gradient to surface (0.10psi /ft) OBJECTIVE OF WIRELINE Add perforations to the Upper Beluga immediately above the current perforated interval. E -line Procedure: 1. MIRU E -line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU 2 -1/8" 6 spf Owen strip guns. 3. RIH and perforate Upper Beluga interval from 6,086' - 6,096' (1 run). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie -in sheet will be provided in the field for exact perf intervals. 4. RD E -line. 5. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic ..: • • .♦ II 1 SU 32 -9 ACTUAL I lilcorp Alaska, Mk 2,312' Pad L, 4 FEL, SCHEMATIC Permit #: 198 - 042 Sec. 9, T5N, R10W, S.M. API #: 50 -133- 20485 -00 -00 Prop. Des: ADL 028063 Conductor KB elevation: 265' (28' AGL) 13 -3/8" K -55 68 ppf WBS #: - LL Top Bottom 1 Latitude: MD Surf 80' Longitude: TVD Surf 80' Spud: 10/18/1998 TD: 10/28/1998 J Rig Released: 11/8/1998 Surface Casing 9 -5/8" P -110 47 ppf BTC Top Bottom MD 0' 2,111' J Cameo KBUG -LTS Chemical Injection TVD 0' 2,072' Mandrelw/ 1/4" (.049 wall) Chemical injection 12 - 1/4" hole Cmt w/ 620 sks of Class G, line @ 998' (1" chemical injection valve - -20bbI of returns to surface installed 2/12/99) Production Casing 7" L -80 29 ppf BTC McMurry SMO - 1 Gas Lift Mandrel @ 5,521' Top Bottom (1" dummy valve installed 2/15/99) MD 0' 6,858' TVD 0' 6,336' 8 -112" hole Cmt w/ 690 sks of class G' ' -30 bbls of returns to surface Halliburton PHL Retrievable Packer @ 5,573' t Production Tubing r F 3 - 1/2" N - 80 9.3 ppf AB - Mod Halliburton XU sliding Sleeve @ 5,630' Top Bottom 8rd w/ X- Profile (ID 2.813 ", Closed 4/22/04) MD Surf 5,909' I 1`TVD Surf 5,487' =II ICC Owen tubing patch (ID- 2,25 ") @ 5,662'- 5,694' , ► 1 *Locator sub @ 5,877'. j 1 I solated Sterling Perforations: *Baker Model F Permanent Packer ► w/ 10' seal bore @ 5,877' ; ; MD Ft TVD Gun Date B4 5,679' - 5,689' 10' 5,279' - 5,288' 2 -1/2 ", 6 spf, 60° (11/5/98) Isolated with Owen Special 2.25" ID Clearance Patch (12/8/04) X- Nipple (ID 2.813 ") @ 5,896' jl Upper Beluga Perforations: Wireline re -entry guide @ 5,909' 6,098' - 6,113' 15' 5,658' - 5,671' 1- 11/16" Owen Swg Jet (12/12/04) 6,113' - 6,128' 15' 5,671' - 5,685' 1- 11/16" Owen Swg Jet (12/12/04) Tagged w /2.0" Bailer on (6/16/13) @ 6,686' MD RKB SLM licr_ - r-a a Capillary String (Removed 06/12/13) mow:" TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Well Name & Number: Sterling Unit 32 -9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country:1 USA Perforations (MD): 5,679' - 6,128' Perf (TVD): 5,279' - 5,685' Angle a KOP & Depth: 1.5 100' Ca? 900' MD _ Angle A Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28' (AGL) Revised by:_ Stan Porhola Revision Date: 6/16/13 • • II SU 32 -9 PROPOSED SU 43-9 !liken) Alaska, 1.LA: 2,312' Pad L, 449' FEL, SCHEMATIC Permit #: 198 - 042 Sec. 9, T5N, R10W, S.M. API #: 50- 133 - 20485 -00 -00 Prop. Des: ADL 028063 Conductor KB elevation: 265' (28' AGL) 13 -3/8" K -55 68 ppf WBS #: - Top Bottom Latitude: MD Surf 80' Longitude: TVD Surf 80' Spud: 10/18/1998 L J TD: 10/28/1998 Rig Released: 11/8/1998 Surface Casing 9 -5/8" P -110 47 ppf BTC Top Bottom MD 0' 2,111' Camco KBUG -LTS Chemical Injection • TVD 0' 2,072' Mandrelw/ 1/4" (.049 wall) Chemical injection 12 -1/4" hole Cmt w/ 620 sks of Class G, line @ 998' (1" chemical injection valve -20bbI of returns to surface installed 2/12/99) Production Casing 7" L -80 29 ppf BTC Bottom McMurry SMO -1 Gas Lift Mandrel @ 5,521' Top m 6,858' 0' (1" dummy valve installed 2/15/99) MD Top otto TVD 0' 6,336' 8 -1/2" hole Cmt w/ 690 sks of class G' -30 bbls of returns to surface r' Halliburton PHL Retrievable Packer @ 5,573' a e Production Tubing 3 -1/2" N -80 9.3 ppf AB -Mod Halliburton XU sliding Sleeve @ 5,630' Top Bottom 8rd w/ X- Profile (ID 2.813 ", Closed 4/22/04) MD Surf 5,909' II 1 _ TVD Surf 5,487' Owen tubing patch (ID- 2,25 ") a r v @ 5,662'- 5,694' Isolated Sterling Perforations: `Locator sub @ 5,877' �' MD Ft TVD Gun Date `Baker Model F Permanent Packer 84 5,679' - 5,689' 10' 5,279' - 5,288' 2 -1/2 ", 6 spf, 60° (11/5/98) . Isolated with Owen Special 2.25" ID Clearance Patch (12/8/04) w/ 10' seal bore @ 5,877' Upper Beluga Perforations: /6,086' - 6,098' 12' 5,647' - 5,658' 2 -1 /8" Strip Guns (Proposed) ✓. X - Nipple (ID 2.813 ") @ 5,896' 1' 7 - 6,098' - 6,113' 15' 5,658' - 5,671' 1- 11/16" Owen Swg Jet (12/12/04) Wireline re - entry guide @ 5,909' 6,113' - 6,128' 15' 5,671' - 5,685' 1- 11/16" Owen Swg Jet (12/12/04) Tagged w/2.0" Bailer on (6/16/13) _ V @6,686'MDRKBSLM yy TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Well Name & Number: Sterling Unit 32 -9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country: USA Perforations (MD): 5,679' - 6,128' Perf (TVD): 5,279' - 5,685' Angle A KOP & Depth: 1.5° 1 100' (u. 900' MD - Angle A Perfs: 26 Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28' (AGL) Revised by: Stan Porhola Revision Date: PROPOSED Marathon Alaska Production LLC O Alaska Asset Team Marathon tail P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 July 12, 2012 Mr. Daniel T. Seamount RECEIVED Alaska Oil & Gas Conservation Commission JUL 18 2012 333 W 7 Ave Anchorage, Alaska 99501 AOGCC Reference: 10 -404 Report of Sundry Well Operations Field: Sterling Unit _ Well: Sterling Unit 32 -9 LLD JUL 2012 Dear Mr. Seamount, Submitted for your approval is the10 -404 Report of Sundry Well Operations for SU 32 -9 well. Marathon re- installed the 3/8" capillary string, to the same setting depth as the previous string was set at (6,098' MD). Please contact Tara Vicente at (907) 351 -4690 if you have any questions or need additional information. Sincerely, usan B. Miller Regulatory Compliance Manager Enclosures: 10 -404 Report of Sundry Well Operations cc: AOGCC Current Well Schematic STATE OF ALASKA RECEIVED ALIIL OIL AND GAS CONSERVATION COMWSION JUL 1 8 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon (J Repair Well U Plug Perforations 11 Perforate U Other Lij Reinstall capillary string Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number Name: Marathon Alaska Production LLC Development p Exploratory ❑ ` 198 -042 3. Address: PO Box 1949 Stratigraphic❑ Service ❑ 6. API Number. Kenai, AK 99611-1949 - 50- 133 - 20485 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . A028063 Sterling Unit 32 -09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Fleld/Pool(s): NA Sterlin • Unit/Beluga Pool 11. Present Well Condition Summary: Total Depth measured 6,858 feet Plugs measured NA feet true vertical 6,336 feet Junk measured NA feet Effective Depth measured 6,820 feet Packer measured 5,573 feet true vertical 6,302 feet true vertical 5,182 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13 -318" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation depth Measured depth Beluga = 6,098' - 6,128' feet True Vertical depth Beluga = 5,658' - 5,685' feet Tubing (size, grade, measured and true vertical depth) Production: 3-112" N-80 5,909' MD 5,487' TVD Cap String: 318" 2205 SS 6,098' MD 5,657' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Halliburton PHL - 5,573' MD (5,182' TVD); SSSV: NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NQ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,200 5 0 psi 319 psi Subsequent to operation: 0 2,000 5 0 psi 320 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory❑ Development IS - Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 16. Well Status after work: 011 ❑ Gas [ J WDSPL ❑ Also attached updated Well Bore Diagram GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.Q. Exempt: 312 -055 Contact: Mike Marini, Production Engineer Phone: 907 - 283 -1370 Printed Name: Michael Ellis Title: Production Engineering Supervisor Signature ''�L� Phone: 907-283-1337 Date 12- Jul -12 RBDMS JUL 19 2017 4 �,J , 7 Fi 1 — Farm 10-404 Revised 11/2011 / 7 / 7/ l Submit Original Only /IT Daily Operations (Onshore) Input Report Marathon Oil Well Name: STERLING UNIT 32-9 Jab caleguy Primary Jon Type OttecV;e Sir Class StrtDale Condi: on Dale On Ran Date End Date R&M R&M MAINTENANCE 6/12/2012 MAINTENANCE Ob41tr, Stock. Sec, Tatum, Range Meld Name Wen °Cleave Carty StatePrmnrce Cacrts 6009005N010W01 STERLING FIELD DRY GAS KENAI ALASKA USA PENINSULA EC ROUGH 'Vas `5,. -rve- Culgtrtat %P Beaton ft!) GGtlti Ette,'a:7• '. ._ .. 9 -.3 "2 T.._ _ _.. .' "' _ >.t] Dale W0.1226'.306.EYP.001 265.00 227.2 ti 10 ;1811998 Phases ese CtM &IOC Me =. fipute Stan Dade AdOze End D3> Rigs / Other Equipment (Cod, Frac, W refine, etc.) equar fT }a'+.' Cs':t n ,.. r'a_' R'g Sti'7 Dale q.3 ke Safety Checks Date Tape 3:'y r<.5 De6a9p6a9n =:a 3 c.. Na . O'?n"Te^: Safety Incidents Dale Tyre 5_L T [_ =en'Y ' T2 t: Tett: Daily Operations R 1Sied Date R 'End Da* Rg :`ares .,r Uet >' 31 . 6/12/2012 06:00 6/13/2012 06:00 1.3' 24 t Smlrttar Re- Install Cap String for Foamer At6098ft. 24 Nr Forecast Continue on Production. On Site Supervisor Jab carsact Company -.. .1.. C:ma t Mike Marini Marathon Time Log SD AMITY OPS _ -PTT? 'Y3 -_ Opu Code Coca $14'16 Trofile Code EtetpumanteParty Corn SAFETY b"TG Safety Meeting 10.73 RURD COIL Rig Up Cap String truck. set fo am er foots alv a to 300ps i crack pressure. Rig up long adapterand packoffonwellhead, Ares sure test with Methanol to 3000ps i against swab valve. 10:30 2 2:2;: RUNPUL COIL FCV pull test 6001b's. RU-Iwith 3/8" Capillary String, Land at6098MB. Straight sinker barand DAD fluid control valve on bottom. (n o centralizer) Max tool 00 0.75in. FCV Serial # 40800082 String Spec: 3/8` x0.049 volume: 3.13 gal /1000ft .. ID0.2Tr 3212IbYeld 44161bTensile 12:30 2 _u 14:30 PUPS. COIL Rig Down Coil Unit, setspoolnextto wellhead, total length of spool is - 7020ft Personnel Log C3 •; r Peg Won Tat i's'ak T`T.e CT dart ;' T<ue ET ..3., 7., Y_ Cum; 77e ;v) ;'r NaN Yes MARATHON OIL CORP. 1 9.00 9.00 Yes BAKER PETROLITE 2 9.00 13.010 • Permit #: 198 -042 i �a API #: 50- 133 - 20485 -00 -00 SU 32-9 ( (�"�'� Prop. Des: ADL 028063 Marathon Oil KB elevation: 265' (28' AGL) �� !! 4 WBS #: Pad SU 43 -9 Alaska Production LLC.. Latitude: 2,312' FSL, 449' FEL, Longitude: Sec. 9, T5N, R1OW, S.M. Spud: 10/18/1998 TD: 10/28/1998 Rig Released: 11/8/1998 Conductor 13 -3/8" K -55 68 ppf - - Top Bottom j : 1 ' ': [ MD Surf 80' TVD Surf 80' Surface Casing 9 -5/8" P -110 47 ppf BTC Top Bottom MD 0' 2,111' A ilk Camco KBUG -LTS Chemical Injection TVD 0' 2,072' Mandrelw/ 1/4' (.049 wall) Chemical 12 -1/4" hole Cmt w/ 620 sks of Class G, injection line @ 998' (1" chemical injection -20bb1 of returns to surface valve installed 2/12/99) Production Casing 7" L -80 29 ppf BTC McMurry SMO -1Gas Lift Mandrel © 5,521' Top Bottom (1" dummy valve installed 2/15/99) MD 0' 6,858' TVD 0 6,336' � �° 8 -1/2" hole Cmt w/ 690 sks of class G' 0 , �-1 , -30 bbls of returns to surface � r Halliburton PI-IL Retrievable Packer @ 5,573' 1 fir° Production Tubing ' 3 -1/2" N -80 9.3 ppf AB -Mod Halliburton XU sliding Sleeve @ 5,630' 1 , Top Bottom 8rd w /X- Profile (ID 2.813 ", Closed 4/22/04) ( MD Surf 5,909' TVD Surf 5,487' t CC Owen tubing patch (ID- 2,25 ") = I= @ 5,662'- 5,694' a I *Locator sub @ 5,877 ' Is olated Sterling Perforations: *Baker Model F Permanent Packer ' \ w/ 10' seal bore © 5,877' t 1I = MD Ft TVD Gun Date f B4 5,679' - 5,689' 10' 5,279' - 5,288' 2 -1/2 ", 6 spf, 60° (11/5/98) L Isolated with Owen Special 2.25" ID Clearance Patch (12/8/04) X Nipple ( ID 2.813 ") @ 5,896' «,r Upper Beluga Perforations: Wireline re - entry guide @ 5,909' , ' 6,098' - 6,113' 15' 5,658' - 5,671' 1- 11/16" Owen Swg Jet (12/12/04) t I 6,113' - 6,128' 15' 5,671' -5,6 -11/16" wen Swg Jet_ (12112/04) Y Tagged w /2.125" GR on (9/1110) @6,757' MD RKB ELM r-. li= capillary String (Installed06 /12/12) =y IL ° 3/8" 2205 Stainless Steel DIE Bottom MD 0' 6098' TVD 0' 5657' ! ) 4 ,,,,: t 1 - TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Well Name & Number: Sterling Unit 32 -9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country: USA Perforations (MD): 5,679' - 6,128' Perf (TVD): 5,279' - 5,685' Angle Un, KOP & Depth: 1.5° / 100' A 900' MD Angle lt+: Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28' (AGL) Revised by: Kevin Skiba /Mike Marini Revision Date: 6/12/12 • co SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC Ir)4 P.O. Box 1949 n Q Kenai, AK 99611 -1949 Re: Sterling Unit, Beluga Pool, Sterling Unit 32 -9 Sundry Number: 312 -055 AMED FE 1 3 ZOl Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9 / 1 Daniel T. Seamount, Jr. Chair DATED this IL day of February, 2012. Encl. Marathon Alaska Production LLC • /®s/ Alaska Asset Team M Coil P.O. Box 1949 �/ Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 February 3, 2012 Mr. Daniel T. Seamount Alaska Oil & Gas Conservation Commission 333 W 7 Ave RECEIVED Anchorage, Alaska 99501 FEB 0 6 2012 Alaska Oil & Gas Cons. Commission Reference: 10 -403 Application for Sundry Approvals Anchorage Field: Sterling Unit Well: Sterling Unit 32 -9 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals for SU 32 -9 well. The original SU 32 -9 cap- string was removed to see if it could flow unassisted. Unfortunately, SU 32 -9 is again struggling with wellbore loading. The current rate of 1.2 MM /day is insufficient to lift out all of the infiltrating fluids. Marathon proposes to re- install the 3/8" capillary string, to the same setting depth as the previous string was set at (6,098' MD), to help mitigate SU 32 -9's loading situation. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 4c . . „.. a .1:10i LPN. Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File (2) KJS STATE OF ALASKA dr ' ,/deft ALASKA OIL AND GAS CONSERVATION COMMISSIC410 ,IO' o?-,? /� APPLICATION FOR SUNDRY APPROVALS a 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Re- install capillary string _ is 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ea , Exploratory ❑ 4 198 -042 - 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 • 50- 133 - 20485 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes El No Ell o Sterlin Unit 32 -9 9. Property Designation (Lease Number): 10. Field / Pool(s): A - 028063 Streling Unit / Beluga Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,858' - 6,336' . 6,820' - 6,302'- NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13 -3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9 -5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Beluga = 6,098'- 6,128' Beluga = 5,658'- 5,685' Production 3 -1/2" N -80 5,909' Capillary NA - - Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): - _ Packers: Halliburton PHL 5,573' MD 5,182' TVD 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: February 23, 2012 Commencing Operations: Oil ❑ Gas 11- WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone (907) 283 -1371 Date February 3, 2012 , �' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sund Number � �� RECEIVED Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: FEB 0 6 7012 ,q-- 3.;,! ni; & Gas Cot's, C - ,!mission Subsequent Form Required: / U - . 1-/01( i =s( l 4 r .i,n , _,__ O APPROVED BY Approved by: A COMMISSIONER THE COMMISSION Date: 2-4 LC) 1 i RBDMS FEB 13 1Z 3 Z • i • I '` Form 10 -403 R o RIGINAL. d 1/2010 Submit in Duplicate • • Marathon Oil Alaska Production LLC.. MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM SU 32 -9 Capillary String Install Procedure Sterling Unit Sterling Pad 43 -9 WBS # WO.12.23606.EXP.001 APPROVALS: Mike Marini 2 -01 -2012 Program Writer Mike Sullev 2 -03 -2012 Mike Sulley Mike Ellis Well Status: Currently the well is producing 1.2 MMCFD at 319 psi and 5 bbl of water per day. Foamer is required to maintain unload rate. Objective: Re- install cap string and bring foamer CICM back online to keep well unloaded. Justification: This well is capable of 2 MMCFD at 320 psi and 5 bbl of water per day. We believe the well to be suffering from a liquid loading issue. A cap string is required for unloading. Previous cap string was set at 6,098 ft. Procedure: Cap string Set Depth: 6,098' (5,658' TVD) Max OD of BHA: 0.75" Min ID of 3.5" tubing: 2.992" Coil Length: (Replacement String, to be determined) Re -Run Cap String: 1. Hold PJSM and obtain SW Permit. 2. MIRU BJ DynaCoil unit. Place liner around wellhead /truck. Set outriggers & ground to well head. Flag off location. 3. P/U spool and mount on truck. 4. Split injector head and insert 3/8 "coil into injector chains. 5. Install OTIS Tree Cap adapter. 6. P/U DynaCoil injector with crane. 7. MU DynaCoil pack -off assembly onto 3/8" cap string and hang off below injector. 1 • , /mil Marathon Oil Alaska Production LLC 8. Check Fluid Control Valve using hand pump. Set new Fluid Control Valve pressure such that CICM surface line pressure equals BHP 9. Install valve on the end of coil string. Pull test to 500 lbs. • 10. P/U DynaCoil injector with crane. 11. Carry injector head up to the well head. MU pack -off (line up slot with the pack -off's 1 /4 " x 4" nipple). Carefully lower injector onto pack -off. 12.Attach hydraulic hoses to hydraulic rams. 13. Pressure hydraulic rams (top seal, 1 % nipple) on pack -off to WH pressurd. 14.Open Rattiguns all the way. Watch for pressure leaks. 15.Insert snubbing guides. 16. Wrap wellhead and pack -off with absorbents to catch drips. Clear wellhead. 17. Pressure test Pack off to 2000 psi. 18.Open swab valve. Watch for leaks at pack -off. 19. Set depth counter to approximate RKB 20. Begin pumping foamer into cap string. 21. RIH at 100 fpm 22. PUH to set depth of 6098 feet (5658' TVD) 23. Set slips. Set Rattiguns. Release pressure on upper hydraulic seal (to protect operator). Watch for leaks. 24. Lift injector head off and away from well. 25. Pressure hydraulic rams (top seal) on pack -off to 2500 psi. Close needle valve and insert hydraulic plug. 26. Pull tubing excess through injector, or split injector head to remove tubing if over 500' of excess coil. 27. Connect tubing to Swagelok injection manifold (valve, gauge, filter, gauge, valve) to CICM line. 28. Lockout Swab, Upper Master, and Lower Master as per Cap- string Lockout Procedure. 29. Hookup injection line to CICM. 30. Replace well house. Be careful of the tubing "bend" as it goes back inside if it extends through the roof. 31. RDMO. Cleanup site. Sign -out. Fill out Well Ops Transfer Sheet and GH gas Report. 2 r, t 0 • Permit #: 198 -042 (1, 4.41 API #: 50- 133- 20485 -00 -00 C U 3 2- 9 Prop. Des: ADL 028063 SU Marathon oil KB elevation: 265' (28' AGL) WBS #: Pad SU 43 -9 Alaska Production LLC,.. Latitude: L 2,312' FSL, 449' FEL, Longitude: Sec. 9, T5N, R10W, S.M. Spud: 10/18/1998 TD: 10/28/1998 Rig Released: 11/8/1998 Conductor 13 -3/8" K -55 68 ppf i 1 Top Bottom MD Surf 80' TVD Surf 80' I IL Surface Casing 9 -5/8" P -110 47 ppf BTC Top Bottom MD 0' 2,111' Camco KBUG -LTS Chemical Injection TVD 0' 2,072' Mandrelw/ 1/4" (.049 wall) Chemical injection line © 998' (1" chemical injection valve 12 -1 /4" Cmt -20bbI of hole returns wl to 620 surface sks of Class G, installed 2/12/99) I 111 Production Casing 7" L -80 29 ppf BTC McMurry SMO -1 Gas Lift Mandrel @ 5,521' Top Bottom (1" dummy valve installed 2/15/99) MD 0' 6,858' TVD 0' 6,336' 8 -1/2" hole Cmt w/ 690 sks of class G' -30 bbls of returns to surface Halliburton PHL Retrievable Packer @ 5,573' ` 6 T r i . Production Tubing a 3 -1/2" N -80 Halliburton XU sliding Sleeve @ 5,630' Top Bottom 9,3 ppf 8rd AB -Mod w/ X- Profile (ID 2.813 ", Closed 4/22/04) + MD Surf 5,909' ' I l TVD Surf 5,487' so I rtrz= Owen tubing patch (I0- 2,25 ") @ 5,662'- 5,694' - *Locator sub © 5,877' 1 ll, Isolated Sterling Perforations: "Baker Model F Permanent Packer w/ 10' seal bore © 5,877' , ‘ MD Ft TVD Gun Date a B4 5,679' - 5,689' 10' 5,279' - 5,288' 2 -1/2 ", 6 spf, 60° (11/5/98) Isolated with Owen Special 2.25" ID Clearance Patch (12/8/04) X- Nipple (ID 2.813 ") @ 5,896' per Beluga Perforations: Wireline re -entry guide © 5,909 6,098' - 6,113' 15' 5,658' - 5,671' 1 - 11/16" Owen Swg Jet (12/12/04) 6,113' - 6,128' 15' 5,671' - 5,685' 1 11/16" Owen Swg Jet (12/12/04) Tagged w/2.125" GR on (9/1/10) @ 6,757' MD RKB ELM a � z TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Well Name & Number: Sterling Unit 32 -9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska I Country: USA Perforations (MD): 5,679' - 6,128' Perf (TVD): 5,279' - 5,685' Angle A KOP & Depth: 1.5° / 100' Cud 900' MD Angle A Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) I RKB:I 28' (AGL) Revised by: Kevin Skiba Revision Date: 2/1/12 • Marathon HIlIRAiHON Alaska Production LLC July 20, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Mar~iFion Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~ ~V~ 1~ . _ ~~ ... ~ 2.~ ss`0° ,,1~~.. ~~C~. 'L~ `~ Reference: 10-404 Report of Sundry Well Operations t ~~ t Field: Sterling Unit Well: Sterling Unit 32-9 Dear Mr. Aubert: ~'~'° Attached for your records is the10-404 Report of Sundry Well Operations for SU 32-9 well. This report covers the work performed to remove the SU 32-9 capillary string. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ `~ Kevin J. Skiba Regulatory Compliance Representative xc:~, Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS ~~~v~u STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ ~~~~~- ~ ~ Zd~U REPORT OF SUNDRY WELL OPERATION~Mask~i~l~Ga>;Cq~,~~C~tt~rnission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other emoved Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Capillary String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: .Permit to Drill Number: Name: Marathon Alaska Production LLC Development 0 Exploratory^ 198-042 3. Address: PO BOx 1949 Stratigraphic ^ Service ^ 6ti API Number: Kenai Alaska, 99611-1949 50-133-20485-00-00 7. Property Designation (Lease Number): ~ ' 8. Well Name and Number: A - 028063 ~. Sterlin Unit 32-9 9. Field/Pool(s): Streling Unit/ e~xga-P~ol . ~ ~ of 11. Present Well Condition Summary: Total Depth measured 6,$5$' feet Plugs (measured) NA feet true vertical 6,336' feet Junk (measured) NA feet Effective Depth measured 6,$20' feet Packer (measured) 5,573' feet true vertical 6,302' feet (true vertical) 5,182' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: Beluga = 6,098'- 6,128' True Vertical depth: Beluga = 5,658'- 5,685' Tubing (size, grade, MD &TVD): 3-1/2" N-80 5,909' MD 5,487' TVD SSSV: - - MD - T~/D Packers and SSSV (type, MD &TVD): Packers: Halliburton PHL 5,573' MD 5,182' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): This well has been shut-in due to the reduced seasonal gas demand. The capillary string was pulled out of the hole to prevent it from Treatment descriptions including volumes used and final pressure: potential damage. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 429 125 Subsequent to operation: 0 0 0 429 125 13. Attachments: 14. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 15. Well Status after work: Oil ~; Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature S ~ Phone (907) 283-1371 Date July 20, 2010 V Form 10-404 Revised 7/2009 ~~7 p~ ~~~ Submit Original Only Marathon eratians Summary Report by Jab N~aTM~ , ~~~ COmp~Y Well Name: STERLING UNIT 32-9 QtrlQtr, block, Sec, Town, Range Field Name Lice rise No. State/Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ftj Ke -Casiny Flange Distafio~ (it) K&Grnund Distance (ft) Spud Date Rig Release Date 0.00 237.25 265.00 27.75 10/18/1998 Daily Operations Re ort Date: 7rl2D70 Job Cate o R&M MAINTE NANCE 24 Hr Summary MIRU UOSS crane truck and BJ DynaCoil to rem ove the well house and pull capillary string. Displace string wl MEOH. Install OTIS tree cap. SITP 1000 psi. Ops Trouble Start Time End Time Dur hrs 0 s Code flctivi Code Status Code Comment 07:30 08:30 1.00 SAFETY MTG Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss UOSS J5A and specifc job hazards. Obtain SWP. 08:30 09:00 0.50 PREP LOC MIRU crane truck. Disconnect power to well house. PU well house and set aside. Remove LO/TO from tree. Spot DynaCoil truck. 09:00 09:30 0.50 SAFETY MTG All DynaCoil personel pressent Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ J5A and specific job hazards. 09:30 10:45 1.25 RURD COIL Spot equipment. Lay liner down. RU Dynacoil unit. PU spool. Stab coil thru side of injector. Carry injector to WH while "walking" injector up coil. Set injector on WH. Install) hydraulic line on packoffto check pressure. Set pressure to 1000 psi. Back off Ratigun. Release mechanical slips. 10:45 11:30 0.75 PREP LOC Mean while, RD 3" flow lines out door of 41-15rd well house. Disconnect and cap MEOH lines. Disconnect electrical power. PU well house an set aside. RD UO55. TRansfer SW Permit to DynaCoil. 11:30 12:30 1.00 RUNPUL COIL PU on cap string. Pulls free from 6098'. POOH 200'to insure it's free. RIH to 6200'.. No tag. (Perfs 6098' - 6115). POOH. 12:30 13:45 1.25 RURD EQIP OOH. Close swab valve and upper master. Bleeed pressure on pack off. Break out pack-off assembly. Bleed cap string pressure. Cut off BHA and plug string. 13:45 1d:45 1.00 RURD EQIP Unbolt old Donovan Style packoff assembly. Install Otis Tree Cap. PT to 1000 psi. 14:45 15:15 0.50 RURD COIL RD DynaCoil Unit. 15:15 15:45 0.50 SECURE WELL Close all valves on tree. Gauges and all plugs in place. Secure well and location. Turn in Permit. Siign out. Leave loc. Close and lock bath gates. www.peloton.com Page 1!1 Report Printed: 7/192010 S U 32-9 50-133-20485-00-00 ADL 028063 is 265' (28' AGL) 1 011 8/1 9 9 8 10/28/1998 used: 11/8/1998 Camco KBUG-LTS Chemical Injection Mandrelw/ 1/4" (.049 wall) Chemical injection line @ 998' (1"chemical injection valve installed 2/12/99) McMurry SMO-1 Gas Lift Mandrel @ 5,521' (1"dummy valve installed 2/15/99) Halliburton PHL Retrievable Packer @ 5,573' Halliburton XU sliding Sleeve @ 5,630' w/ X-Profile (ID 2.813", Closed 4/22/04) Owen tubing patch (ID-2.25") @ 5,662'- 5,694' I `Locator sub @ 5,877' 'Baker Model F Permanent Packer w/ 10' seal bore @ 5,877' X-NiDDIe (ID 2.813") @ 5,896' Wireline re-entry guide @ 5,909' Pad SU 43-9 2,312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. a a TD PBTD 6,858' MD 6,820' MD 6;336' TVD 6,302' TVD M Muun~oM Conductor 13-3/S" K-55 68 ppf Top Bottom MD Surf 80' TVD Surf 80' Tubing 3-1/2" N-80 9.3 ppf AB-Mod Top Bottom 8rd MD Surf 5,909' TVD Surf 5,487' Surface Casing 9-518" P-110 47 ppf BTC Top Bottom MD 0' 2,111' TVD 0' 2,072' 12-1 /4" hole Cmt w/ 620 sks of Class G, -20bb1 of returns to surface Production Casing 7" L-80 29 ppf BTC Top Bottom MD 0' 6,858' TVD 0' 6,336' 8-1/2" hole Cmt w/ 690 sks of class G' -30 bbls of returns to surface MD Ft TVD Gun Date 84 5,679' - 5,689' 10' 5,279' - 5,288' 2.1/2", 6 spf, 60° (11/5198) Isolated with Owen Special 2.25" ID Clearance Patch (12/8/04) Upper Beluga Perforations: 6,098' - 6,113' 15' 5,658' - 5,671' 1-11/16" Owen Swg Well Name & Number: Sterling Unit 32-9 Lease: Sterling Unit Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,679' - 6,113' Perf (TVD): 5,279' - 5,671' Angle @ KOP & Depth: 1.5° / 100' @ 900' MD Angle @ Perfs: 26° Date Completed: 11/5/1998 Ground Level: (AMSL) RKB: 28' (AGL) Revised by: Kevin Skiba Revision Date: 7/19/2010 • Marathon MARATHON Oil Company August 11, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Sterling Gas Field Well: Sterling Unit 32-9 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~,.: P , e~ ~ c> CUU~ ,~..,~a ~r',-. `~ "{~ $~ 0 ~~ Attached for your records is the10-404 Report of Sundry Well Operations for SU 32-9 well. This report covers the capillary string installation performed under Sundry #308- 209. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, `~. „!~ ~ Kevin J. Skiba Engineering Technician ~~~t~~~ AllG ~ ~ 2flfl8 Enclosures: 10-404 Report of Sundry Wefl Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS "` , ~~ STATE OF ALASKA j./„~Oj~ ALA OIL AND GAS CONSERVATION COM~I~~I`~ ~ 2; , ~; I REPORT OF SUNDRY WELL OP~R,A~I;QN.S 1. Operations Abandon Repair Well Plug Perforations Stimulate Cher ~ Install Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Capillary String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Development Q, Exploratory^ 198-042 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20485-00-00 7. KB Elevation (ft): 9. Well Name and Number: 265' Sterlin Unit 32-9 ' 8. Property Designation: 10. Field/Pool(s): A-028063 Sterling Unit /Beluga Poot 11. Present Well Condition Summary: Total Depth measured 6,858' . feet Plugs (measured) NA true vertical 6,336'. feet Junk (measured) NA Effective Depth measured g~820' - feet true vertical 6,302' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: Sterling = 5,662'- 5,694` Beluga = 6,098'- 6,128' True Vertical depth: Sterling = 5,263'- 5,292' Beluga = 5,658'- 5,685' , 3/8" 2205 Stainless Steel 6,098' Tubing: (size, grade, and MD) 3-1/2" N-80 5,909' Haliburton PHL Retrievable Packer 5,573' Packers and SSSV (type and measured depth) Baker Mod. F Permanent Packer 5,877' 12. Stimulation or cement squeeze summary: Intervals treated (measured): S ~~, Q~1~ ~ ~ 2~~8 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,850 0 200 678 Subsequent to operation: 0 2,675 1 200 695 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas 0 ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-209 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M_D novan Title Production Engineer ~'L~f ~~ Signature ~ Phone (907) 283-1333 Date August 11, 2008 UI~1UI-un~-. • • out. Lock gates behind us. aiy Operations ort Date: 71112008 Job Category. R&M MAINTENANCE i4 Nr Summary Redeploy 3!8° DynaCoil string 6098' KB. svn rme ti,o r~ Dur s code Petivit code s.:~: rouble Code ConmeM 08:00 09:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SWP. 09:00 10:30 1.50 RURD COIL AF Spot equipment Lay liner down. RU Dynacoil unit. Stab toll in injector. Set Fluid control valve ~ 3100 psi (5660'tvd x 8.7 ppg x .052 = 2560 psi. plus 500 psi.} Install BHA and pull test to 750 lbs. Replace packing in pack off assembly. Carry injectorto WH. Bleed down tree cap and install pack off on H. AF RIH wf 318" coil and standard BHA to 6090' KB. AF Land 3.8" Dynacoil @ 6098' KB. Set slips. Tighten Radigan packing and hydraulic packing to 2500 psi. Disassemble injectorto free coil. Set spool. Install tubing from foamer skid. Begin injecting at max rate for 30 min to insure tubing is full. Reduce foamerto 1 gallon per day. Install signage and install LOTO on swab and upper master valves. AF Secure WH and location. Clean up location. Turri in permit. Sign out and leave loc. Report Printed: 81112008 50-133-20485-00-00 ADL 028063 ~: 265' (28' AGL) 1 011 811 9 9 8 1 012 8/1 9 9 8 used: 1 1 /811 9 9 8 Camco KBUG-LTS Chemical Injection Mandrelw/ 1/4" (.049 wall) Chemical injection line @ 998' (1" chemical injection valve installed 2/12/99) McMurry SMO-1 Gas Lift Mandrel @ 5521' (1" dummy valve installed 2/15/99) Halliburton PHL Retrievable Packer @ 5,573' Halliburton XU sliding Sleeve @ 5630' w/ X- Profile (ID 2.813", Closed 4/22/04) Owen tubing patch (ID-2.25") @ 5,662'- 5,694' 'Locator sub @ 5877' "Baker Model F Permanent Packer w/ 10' seal bore @ 5,877' X-NiDDIe (ID 2.813") @ 5,896' W ireline re-entry ouide @ 5,909' terling Unit 32-9 Pad SU 43-9 2,312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. a ~ ~ tt~ Ma~nioM Conductor 13-3/8" K-55 68 ppf Top Bottom MD Surf 80' TVD Surf 80' Tubino 3-1/2" N-80 9.3 ppf AB-Mod Top Bottom 8rd MD Surf 5,909' TVD Surf 5,487' Surface Casing 9-518" P-110 47 ppf BTC Top Bottom MD 0' 2,111' TVD 0' 2,072' 12-1/4" hole Cmt w/ 620 sks of Class G, -20bb1 of returns to surface 7" L-80 29 ppf BTC Top Bottom MD 0' 6,858' TVD 0' 6,336' 8-1/2" hole Cmt w/ 690 sks of class G' -30 bbls of returns to surface MD Ft TVD Gun Date 5,679' - 5,689' 10' 5,279' - 5,288' 2-1/2", 6 spf, 60° (1115/98) Isolated with Owen Special 2.25" ID Clearance Patch (1218104) 098' - 6,113' 15' 5,658' - 5,671' 1-11/16" Owen Swg Jet (12112104) 113' - 6,128' 15' 5,671' - 5,685' 1.11/16" Owen Swg Jet (12112104) TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Capillary String 3/8" 2205 Stainless Steel Top Bottom MD Surf 6,098' TVD Surf 5,658' Well Name & Number: Sterling Unit 32-9 Lease: Sterling Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): Pert (TVD): Angle @KOP and Depth: 1.5° / 100' @ 900' MD Angle @ Perfs: 26° KOP TVD: 900' Date Completed: November 5, 1998 RKB: 28' Prepared By: Kevin Skiba Last Revision Date: August 11, 2008 • • ~ a a o SARAH PAUN, GOVERNOR °~a~ OIIr ~ ~ 333 W CO1~T5ERQA~'I011T COMMI55IO1~T . 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 ~~~ JUI~ ~ ~ 20Q$ Re: Sterling Gas Fleld, Upper Beluga Unr~lefined .Gas Pool, Sterling Unit 32-9 Sundry Number: 308-209 ~~~-b~- Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Comrriission an application for rehearing. A request for rehearing is considered_timely_jfit_is_received_by ____ _____ _____.. 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this~~ day of June, 2008 Encl. • M Marathon MARATHON Oil Company June 11, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Sterling Unit, Pad 43-9 Well: Sterling Unit 32-9 (PTD 198-042) Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~,-UN 1 3 2G~08 Alaska C3i! & Ca ~; ~~. ~'cmr~i~sicn A~cir~.~a We propose to run a 3/8" capillary string in SU 32-9. With the availability of a capillary injection unit on the Peninsula starting the week of June 23rd 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 6098' MD. The past capillary string installation into KTU 24-6H (PTD 199-073) has yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would like to continue to install capillary strings in other wells like SU 32-9 and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~/~~ . Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File DMD KJS ~~~v ~ ~~~ STATE OF ALASKA ~Q 1 ~" ~~AL~ OIL AND GAS CONSERVATION COM~ION ~~ JU~~! ~ ;.'' 4 APPLICATION FOR SUNDRY APPROVAL ~`~ \~'~~ 20 AAC 2s.2so ~laska Oil & Gas Co s. ~bf~fl~issias~ 1. T e of Re uest: Abandon Sus end ^ ' s`w ~ ~~ < ~ Other ^/ yp q p ^ Operational shutdow Perforate Waive Alter casing ^ Repair well ^ Plug Perforation Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Poo^ Re-enter Suspended Well ^ String ' 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ , Exploratory ^ 198-042 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20485-UO-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S ^ ~ Sterling Unit 32-9' pacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): f~ A 028063 265' Sterling Unit I Beluga Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,858' - 6,336' ~ 6,820' 6,302' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 13-3/8" 80' 80' 3,450 psi 1,950 psi Surface 2,083' 9-5/8" 2,111' 2,072' 9,440 psi 5,310 psi Intermediate Production 6,830' 7" 6,858' 6,336' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Sterling = 5,662'- 5,694' Sterling = 5,263'- 5,292' 3-1/2" N-80 5,909' Beluga = 6,098'- 6,128' Beluga = 5,658'- 5,685' Packers and SSSV Type: Haliburton PHL Retrievable Packer Packers and SSSV MD (ft): 5,573' & Baker Mod. F Permanent Packer 5,877' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 24, 2008 Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature Phone (907) 283-1333 Date June 11, 2008 • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~v~ ~~ APPROVED BY ~~ Approved by: ~ COMMISSIONER THE COMMISSION Date: v - Form 10-403 Revised 06/2006 0 R I G I ~ A L ~~ J~~ ~ ~ 20°B Submit in Duplicate 2008 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, BC, KGF .and NGF WBS#s SD#3 - W0.08.18049.CAP.001 KBU 11-8Y, 33-6X, 41-7 - W0.08.18053.CAP.001 BC 13 - W0.08.18054.CAP.001 CLU 6 - W0.08.18056.CAP.001 ~J~ SU 32-9 - W0.08.18117.CAP.001 ~~ GO 6 - W0.08.18196.CAP.001 Objective - Install a 3/8" Capillary String into these wells to alleviate liquid loading. We intend to treat the producing fluid level in • each of these 8 wellbores with foamer. Install and Complete CICM (injection skids) to utilize on wellheads. We have seen an incremental increase on KTU 24-6H capillary string installation of approximately 475MCFD. Procedure Companies Evolved: UOSS, BJDC, BJCS, BigG Installation Order ell Maximum Setting Depth Maximum String Len th Minimum String Needed at Surtace trin Slze and T e lan a Connection Est'd Producing Fluid Level a De th Gauge Ring ID run Recommended Setting Depth From PT+Ta 1 CLU 6 8042' 8200' 45' 2205 3l8" X 0.049" WT 4-1116 5M RX39 7880' 8058' _ 2.300" 8020' 2 SU 32-9 6200' 6250' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 3 BC 13 8590' 8750' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 7900' 10055' 2.300" 8580' 4 GO 6 10120' 10300' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD • 5 SD 3 9290' 9450' 45' 2205 3l8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 6 KBU 41-7 6910' 7050' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 7 KBU 11-8Y 8145' 8300' 45' 2205 3l8" X 0.049" WT 3-1116" 10M BX154 TBD TBD TBD TBD 8 KBU 33-6X 8200' 8350' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 2008 Capillary String Installation Page 2 Installation Procedure: 1.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41-7, all other wells have units placed. They will complete Installation of items that are pertinent to operation of CICM. b) Move NS#3 CICM to GO#6 well 2.) UOSS: (Hold PJSM and JSA) a) Removal of all well houses to setup for BJ Dynacoil Unit b) Replacement of CICM roof on (3) new skids, after tanks are set inside containment. 3.) Big G: (Hold PJSM and JSA) a) Complete explosion proof electrical end fittings for CICM b) Complete tubing for hookup of Dynacoil - if needed. - Placement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tubing disconnects when well work is needed, thus reducing exposure to trapped pressure. 4.) BJDC: 1. Hold PJSM and Complete JSA/JHA 2. Move in rig up BJ Dynacoil unit. 3. Replace tree-cap flange with specified internally threaded flange listed above in the matrix. 4. MU BHA and secure to 3/8" string. 5. MU WHA to internally threaded flange 6. MU Trailer Haskell Pump to WHA with 1" male NPT tie back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" -This will prevent BHA from traveling down flowline. BHA is small and capable of flowing into flow-Tee 9. RIH with capillary below "Est'd Producing Fluid Level". All strings must be set into the producing fluid level to prove the most effective. 10. Set Rattiguns and Leave 1.5 times SITP or greater as requested by BJDC on hydraulic pack off. 11. "OPEN WELL TO PRODUCTION" 12. Leave remaining. spool of tubing outside of well for soap injection skid hookup. 13. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 14. Lockout/Tagout Swab, Upper Master and Lower Master. (Install BJ Dynacoil signs on all valves stating "Do Not Operate BJ Dynacoil in wellhead". Proceed to Lockout valves with production lock and cable.) 15. Hookup injection line to CICM, and set specified rate for each well. 16. RDMO, Cleanup site, Sign-out 50-133-20485-00-00 ADL 028063 ~: 265' (28' AGL) 10118/1998 10/28/1998 ased: 1118/1998 Camco KBUG-LTS Chemical Injection Mandrelw/ 1/4" (.049 wall) Chemical injection line @ 998' (1" chemical injection valve installed 2/12/99) McMurry SMO-1 Gas Lift Mandrel @ 5521' (1" dummy valve installed 2/15/99) Halliburton PHL Retrievable Packer @ 5,573' Halliburton XU sliding Sleeve @ 5630' w/ X- Profile (ID 2.813". Closed 4/22/04) terling Unit 32-9 Pad SU 43-9 2,312' FSL, 449' FEL, Sec. 9, TSN, R10W, S.M. Conductor 13-318" K-55 68 ppf Top Bottom MD Surf 80' TVD Surf 80' Surface Casing 9-5/8" P-110 47 ppf BTC Top Bottom MD 0' 2,111' TVD 0' 2,072' 12-114" hole Cmt wl 620 sks of Class G, -20bb1 of returns to surface 7" L-80 29 ppf BTC Top Bottom MD 0' 6,858' TVD 0' 6,336' 8-1/2" hole Cmt w/ 690 sks of class G' -30 bbls of returns to surface \ MD Pt TVD Gun Date 64 5,879' - 5,689' 10 ' 5,279' - 5,288' 2-112", 6 spf, 60° (1115198) Isolated with Owen Special 2.25" ID Clearance Patch (12/8104) Locator sub @ 5877' Baker Model F Permanent Packer, w/ 10' seal bore @ 5,877' X-Nicole (ID 2.813") @ 5,896' Wireline re-entry ouide @ 5,909' Uooer Beluga Perforations: 6,098' - 8,113' 15' 5,658' - 5,671' 1-11118" Owen Swg Jet (12112/04) 6,113' - 6,128' 15' 5,671' - 5,685' 1-11118" Owen Swg Jet (12/12/04) TD PBTD 6,858' MD 6,820' MD 6,336' TVD 6,302' TVD Well Name & Number: Sterling Unit 32-9 Lease: Sterling Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): Perf (TVD): Angle @KOP and Depth: 1.5° 1100' @ 900' MD Angle @ Perfs: 28° KOP TVD: 900' Date Completed: November 5, 1998 RKB: 28' Prepared By: Kevin Skiba Last Revision Date: June 11, 2008 ~aRan~oM Y • M Marathon MARATHON Oil Company June 11, 2008 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 9071283-1350 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave .1UN ~. 2 2008 Anchorage, Alaska 99501 Alaska Oil ~ Gay ~ c~~. (;c~r~~i~sicr~ A~~ c~°a~a Reference: 10-407 Well Completion Report 1 (~ Field: Sterling Field ~ t -1 ~ ~ ~ Well: Sterling Unit 32-9 ;~~,~~® JUi_ 4 ~ 2008 Dear Mr. Maunder: Enclosed for your records is the 10-407 Well Completion Report covering the work performed on SU 32-9 well under Sundry #303-297. The work encompassed isolating the Sterling zone and adding perforations to the Beluga formation. This work was completed on December 13, 2004. , While reviewing our files, we noticed that we had inadvertent~y documented, and submitted. this work operation on a 10-404 Sundry form on (1/27/05. In an effort to correctly close out this work activity, I am resubmitting this information on the requested 10-407 Well Completion Report. Please contact me at (907) 283-1371 if you have any questions or require additional information. Sincerely, I~ /~jn- i V +~S/~- - Kevin J. Skiba Engineering Technician Enclosures: 10-407 Well Completion Report cc: Houston Well File Operations Summary Kenai Well File KJS STATE OF ALASI44 AL~ OIL AND GAS CONSERVATION COM ION ~~~ ~ ~ z00$ WELL COMPLETION OR RECOMPLETION REPORT A,~VD,.~OG~;gR FALSE Oil ^ Gas Q Plugged ^ Abandoned ^ Suspended ^ 2oanczs.~os zonnczs.~~o ~ GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1 • - - ° Developme~Cl~~;36 Exploratory^ ervice ^ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date Cqom~ Sus ., or Aband.. ~~ 8 2. Permit to Drill #: 198-042 Sundry#: 303-297 3. Address: PO Box 1949, Kenai Alaska, 99611-1949 6. Date Spudded: 10/18/1998 13. API Number: 50-133-20485-00-00 - 4a. Location of Well (Governmental Section): Surface: 2,312' FSL, 449' FEL, Sec. 9, TSN, R10W, S.M. ' 7. Date TD Reached: 10/28/1998 14. Well Name and Number: Sterling Unit 32-9 ° Top of Productive Horizon: 2,695' FSL, 2,227' FEL, Sec. 9, T5N, R10W, S.M. 8. KB (ft above MSL): 265' ~ Ground (ft MSL): 237'. 15. Field/Pool(s): Total Depth: 2,859' FSL, 2,722' FEL, Sec. 9, TSN, R10W, S.M. 9. Plug Back Depth(MD+TVD): 6,820' MD 6,302' TVD Sterling Unlt /Beluga POOI ' 4b. Location of Well (State Base Plane Co r inates, NAD 27 : o yz. Surface: x- 3,732 31V7~j~~ ~,~~gp,~ ~-3~one- 4 10. Total Depth (MD + TVD): ~ 6,858' MD 6,336' TVD 16. Property Designation: A-028063 TPI: x- .31~+l66 y- ,+. .2;s9~o;8a8 Zone~-,~ Total Depth: x- 0 3<Z ~(4~ ,?,3gpsgd'~Zi ~n~e`-" 4 11. SSSV Depth (MD + TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes No ~ ~~~, (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List II Igqgs hergg~~n~ bmit~I~ct~ ic~rprinted,' fo - atiog p~2p~y4AC 25~07y1): Co~,-ir~• ~ f ~K gt nAr ~-etri tl' Scu O ?-$•O$ 22. CASING, L INER AND CEMENTING ECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8" 68# K-55 Surf 80' Surf 80' Driven 9-5/8" 47# P-110 0' 2,111' 0' 2,072' 12-1/4" 620 sks, Class G -20 bbls 7" 29# L-80 0' 6,858' 0' 6,338' 8-1/2" 690 sks, Class G -30 bbls 23. Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 5,909' 5,630' & 5,877' MD TVD Gun ' ' ' " Upper Beluga 6,098 -6,128 5,658 -5,680' 1-11116 Owen Swing 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: 3/31/1999 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: Hours Tested: 24 Production for Test Period Oil-Bbl: 0 Gas-MCF: 5500 Water-Bbl: 0 Choke Size: Gas-Oil Ratio: 100% Gas Flow Tubing Press. 1650 Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: 5500 Water-Bbl: 0 Oil Gravity -API (corr): NA 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~I• /•70 ~Ji7 E j _ / a _ . .~ ~, ,iU~ ~ 12008 ~•~ ~~~~~ _ - ~ ~ g. - Form 10-407 Revised 2/2007 ,~°l` ~ ~ I ^ i ~ONTINUED ON REVERSE ice; Ivy/ L ~ ~~~_©~ 28. GEOLOGIC MARKERS (List all formations and m encountered): 29. FORMATION TESTS NAME M TVD Well tested? Yes ~ ff yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, ff needed, and submit detailed test information per 20 AAC 25.071. Sterling B-4 5,679' 5,279' Beluga 6,041' S,60T Formation at total depth: 30. List of Attachments: O erations Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Kevin J. Skiba Title: Engineering Technician - ~ Signature: • Phone: (907) 283-1371 Date: June 11, 2008 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: ff this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytica! laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Marathon Oil Company • Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date ;From - To ~ 12!9/2004 09:00 - 09:30 112/11/2004 STERLING UNIT 32-9 STERLING UNIT 32-9 RECOMPLETION Start: 12/8/2004 NABORS DRILLING Rig Release: NABORS ALASKA 160 Rig Number: 160 ____~.__ I Sub Hours ~ Code ;Code; Phase 0.50 ~ SAFETY I MTG_ PATCH i 09:30 - 10:30 1.00 RURD_ ELEC PATCH 10:30 - 11:15 I, 0.75 RUNPU ELEC PATCH I i 11:15 - 11:45 0.50 j LOG ~ CSG ;PATCH 11:45 - 12:45 1.00 I _ RUNPUL _ I ELEC ~ PATCH 12:45 - 13:15 , 0.50 PULD_ ~ BHA_ ~ PATCH 13:15 - 13:30 f 0.25 SAFETY ! MTG_ PATCH 13:30 - 14:00 j 0.50 PULD BHA_ PATCH 14:00 -15:00 ; 1.00 RUNPU ELEC PATCH 15:00 -15:05 ~ 0.08 LOG_ CSG_ PATCH 15:05 - 15:30 15:30 - 17:00 10:00 - 10:30 10:30 - 17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 21:00 21:00 - 21:30 21:30 - 23:15 0.42 ~ BLOWD TBG_ 1.50 RURD ELEC -I 0.50 SAFETYIMTG_ 7.00 RURD_ICOIL 1.00 TEST_ BOPE 0.50 SAFETY MTG_ 2.00 TEST BOPE ~~ 0.501 BLOWDf~COIL 1.75' RUNPUtJCOIL 23:15 - 02:45 ' 3.50 02:45 - 03:45 1.00 03:45 - 05:00 i 1.25 05:00 - 06:00 12/12/2004 106:00 - 07:45 12/13/2004 (07:45 - 09:00 i 09:00 - 14:30 09:15 - 11:15 11:15 - 11:30 I 11:30 - 14:00 i PUMP; N2_ RUNPUL COIL JET_ N2_ 1.00 ~ JET„_ N2_ i 1.75 ~ JET_ N2_ 1.25; RUNPUL,~COIL 5.50 RURD_( COIL 2.00 RURD4; ELEC 0.251 SAFETY MTG_ 2.50 PULD PGUN Page 1 of 2 Spud Date: 10/18/1998 End: Group: Description of Operations Arrive on location with permi# and hold safety meeting while pad is plowed and sanded. Well has been shut in, but was Flowing 1100Mscfd at 740psi. RU electric line unit. PU GR/CCL and 2.74" gauge cutter RIH w/ assembly. Tag at 5628' (sliding sleeve) and work through. Drift tubing and casing to 6200' to ensure all clear to proposed perfs. Obtain correlation with GR/CCL POOH w/ tool string. At surface, lay down tool GRlCCUGC. Lay out tubing patch. Hold safety meeting to discuss radio silence. Arm firing head and PU RIH w/ Owen special clearance patch (ID=2.25"). Correlate patch and fire. Se` a good indication and taa patch set at PATCH !Bleed down tubing while POOH. PATCH IAt surface with tool. THP down to 540 psi (line pressure) with no flow. RD E-line and depart location. CMPFLW BJ arrive on location. Sign in, obtain permit, and hold safe#y meeting. CMPFLW Rig up equipment including riser to BOP. Stab CT. PU injector head. RU flowlines and BHA to permit standard and reverse circulating. CMPFLW Load coil tubing to pressure test. Having problems with fluid pump rate gauge. CMPFLW Hold crew change safety meeting. CMPFLW Complete shell test. Pressure/Ftn test blind rams and tubing rams to 300/4500psi. ;CMPFLW !Purge methanol from CT w/ N2. CMPFLW I RIH w/ CT. Begin pumping N2 down annulus taking returns to CT at 350 scfm at 5700' per BJ pumping program. CMPFLW i Pump N2 varying rates and wait to see Fluid to surface. CMPFLW ;Decide to POOH and check nozzle for plugging. Shut down N2 unit. CMPFLW !Begin to see retums at suface at 1100'. Cool down N2 unit to resume pumping and run back in hole. Made 18bb1 fluid and N2 broke through to surface. RIH to below tubing tail and circ at minimum rate waiting for more N2. Lost most N2 pressure while flowing to tank. Suspect fluid level was higher than design and first bite of fluid was too large given pressure restrictions. Estimate original fluid level at 3700' `CMPFLW With more N2 available, continue reverse circulating from 6400' making additional 10bb1. PUH to tubing tail to allow N2 circulation to lift CT. ,CMPFLW Run back in to 6200' and continue pumping N2. Start seeing N2 to surface w/ CT deep indicating most fluid dried up. RIH to 6400' and continue taking returns to ensure pert zone will remain clear of produced water. CMPFLW ;POOH w/ CT. Shut in choke when water r turns ctQp~pping nn~~ ~ N2 rep sure, i CMPFLW At surface. Freeze protect reel and rig down CT unit. Stack equipment aside for mob to West Fork CMPPRF WL at pad, held PJSM, secured work permit. RU wireline unit. Ready to arm guns. ;CMPPRF ~ Held 5aftey meeting prior to arming gun. Went to communication black out and radio silence. Man stationed at fhe pad gate. (CMPPRF Armed 1 11/16" Owen swing Jet 2 pertorating gun with CCL and weight bar. Gun number1 - 15'. RIH to bottom. WHP= 1075 prig. Used j WHP to PT lubricator. Punted: 4/8/2008 10;45:09 AM ,~ Marathon Oil Company ~ Page 2 of 2 Operations Summary Report Legal Well Name: STERLING UNIT 32-9 Common Well Name: STERLING UNIT 32-9 Spud Date: 10/18/1998 Event Name: RECOMPLETION Start: 12/8/2004 End: Contractor Name: NABORS DRILLING Rig Release: Group: Rig Name: NABORS ALASKA 160 Rig Number: 160 Date ;From - To Hours Code ~ Sub Phases Description of Operations _ _._ _.____-'~_ ~ Code ~ ----.__ _._ _ 12/13/2004 ~ 14:00 - 14:45 0.75; PERF_ TBG_CMPPRF IGun #1 on bottom correlate to open Schlumberger log dated No. 6, ~ ~ 1998. Pulled gun up to perforate from 6113 - 612$' DIL. shot gun, ~ pressure went up to 1 00 psig in 5 minutes. POOH with gun. ' 14:45 - 15:00: 0.25 PULD_ PGUN CMPPRF OOH with gun. Verified the gun shot. MU gun number 2. j 15:00 - 15:50 ; 0.83 PERF_ TBG_ CMPPRF RIH with gun#2, correlate to same log. Pulled gun up to shoot from 6098 to 6113' DIL shoot gun number 2, no change in surface pressure. POOH with gun. 15:50 - 16:15 i 0.42 PULD_; PGUN CMPPRF OOH with gun, atl shots fired. Start flowing well to flow back tank to blow off nitrogen left from coil during the reverse circulation. 16:15 -17:00) 0.75 ~ RURD ' ELEC CMPPRF RD a line unit. secure well. 17:00 -18:00 ~ 1.00: FLOW BACK CMPPRF Good gas to flow back tank. Roll the well into production. Started well j on line at 1.3 mmcfpd. AT 1890 psig. Open well up to 3.5 mmcfpd. ',18:00 - 19:00 ! 1.00 ! FLOW_ BACK ~ CMPPRF Moniotor well, no water, WHP = 1828 psig at 3.3 MMCFPD rate. ~ ~ Wire line unit left lease 12/16/2004 07:00 - 16:00 ; 9.00 j RURD_ PIPE CMPPRF RD flew back equipment from well. Released choke, light plants ~ ~ heaters. i ' I I i i i i i i ~ i ( ~ i I ~ t ~ I ~~ i ~ ~ j I ~ i I t ~ ~ j , i ~ ~ i ~ I i I ' ! ~ i i I I i Printed: 4/8/2008 10:45:09 AM ') ') Northern Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 , , . M Marathon MARATHON Oil Company ~ January 27, 2005 C\ cv- {)Ur 'ð" Winton Aubert State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Ave, Suite 100 Anchorage, AK 99501 RECEIVED JAN 2 8 2005 on & Gas Cons. Commission Reference: Sundry Notice Field: Sterling Unit Well: Sterling Unit 32-9 Dear Mr. Aubert; Please find the enclosed 10-404 Report of Sundry Well Operations for Marathon Sterling Field Well SU 32-9. This is a report subsequent to work completed to isolate Sterling production and to add Beluga perfs in SU 32-9. This work was finished December 13, 2004 and production was immediately turned to sales. The well is currently producing about 5.5MMcfd at 1650psi. I have also enclosed a detailed Operations Summary Report and an updated Well Schematic for your review. If you require further information, I can be reached at 907-283- 1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, /ì¡A iÆ ~-yyØtP Denise Titus Production Engineer Enclosures: Sundry Form 10-404 Operations Sundry Report Wellbore Diagram SCANNED FEB 11 2005 n.... ,~ P 1 C 1 f\ , ,Ô,.. L . . , '" ¡ . , STATE OF ALASKA ì ALA~. ~~) OIL AND GAS CONSERVATION COMMlv"ION REPORT OF SUNDRY WELL OPERATIONS ~ I JAN 2 8 2005 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: Repair Well U Pull Tubing D Operat. Shutdown D Plug Perforations U Perforate New Pool 0 Perforate D 4. Current Well Class: Development D Stratigraphic D A':1,hXQ 0:1,&. fI""o. Stimulate U 011Yer DUdS WaiverD Time Extension D tmcnorage Re-enter Suspended Well D 5. Permit to Drill Number: Marathon Oil Company Exploratory D Service D 6. API Number: 50-133-20485 98-042 3. Address: P. O. Box 196168, Anchorage, AK 99519- 6168 7. KB Elevation (ft): 9. Well Name and Number: 27.8' KB-GL S U 32-9 8. Property Designation: 10. Field/Pool(s): A-028063 Sterling Unit! Sterling Pool 11. Present Well Condition Summary: Total Depth measured 6858' MD feet true vertical 6336' TVD feet Effective Depth measured 6820' M D feet true vertical 6302' TVD feet Casing Length Size MD Structural 80 13 3/8" 80' Conductor Surface 2,111 95/8" 2111' Intermediate Production 6,858 7" 6858' Liner Plugs (measured) Junk (measured) N/A N/A TVD Burst Collapse 80' NIA NIA 2072' 9440 5310 6336' 8160 7020 Perforation depth: Measured depth: S-5679'-86' B.6098'-6128' True Vertical depth: S-5279'.85' B-5658'-5680' Tubing: (size, grade, and measured depth) 3 1/2", AB Mod. Butt L-80, 9.3 ppf 5909' Packers and SSSV (type and measured depth) Halli PHL & Bkr F 5630' & 5877' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 800 1 5500 0 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 775 1650 Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or NIA if C.O. Exempt: Contact Denise Titus Printed Name Del'ise M. Titus,? Signarure ¡ ~~Jf,tí4ù Title Production Engineer Phone 907-283-1333 Date 1/27/2005 Form 10-404 Re,"sed 04/2004 RBDMS BFl FFR 0 8 M R I (~ II~ A I Submit Original Only M MARATHON Camco KBUG-LTS Chemical Injection Mandrelw/ 1/4" (.049 wall) Chemical inj~ line @ 998' (1" chemical injection valve installed 2/12/99) 13 3/8" K-55 0 68 ppf n/a 80 9 5/8" P-110 0 47 ppf BTC 2111 . McMurry SMO-1 Gas Lift Mandrel @ 5521' (1" dummy valve installed 2/15/99) i Halliburton PHL Retrievable Packer @ 5,573' Halliburton XU sliding Sleeve @ 5630' w/ X- Profile (ID 2.813"~peaed-2~1~/99 Closed 4/22/04) Owen tubing patch (ID- 2.25") @ 5662'-5693.5' Sterling B-4 Perforations 5679-5689' AIT Locator sub at 5877' Baker Model F Permanent Packer @ 5,877' w/ X-Nipple @ 5896' (ID 2.813") Wireline re-entry guide @ 5,909' m m E-line tagged PBTD at 6810' 11/4/98 7" L-80 0 29 ppf BTC 6858 Well Name & Number: Sterling Unit 32-9 Lease Sterling Unit County or Parish: KPB State/Prov. AK Country: USA Perforations: (MD) (TVD) Angle/Perfs Angle @KOP and Depth 0 KOP TVD 0 BHP: 0 BHT: 0 Completion Fluid: FWHP: FBHP: FWHT: FBHT: Other: Date Completed: RKB: Prepared By: Don Eynon Last Revision Date: _ • JO ~ ~--- Upper Beluga Perfs 6,098'-6,128' (12/13/04) ~ w/ Owen 1-11/16" Swino Jet 2 ) ) Page 1 of 2 Marathon OiFCompany Operations Summary Report Legal Well Name: STERLING UNIT 32-9 Common Well Name: STERLING UNIT 32-9 Event Name: RECOMPLETION Contractor Name: Rig Name: Date From - To Hours Code Sub Phase Code 12/9/2004 09:00 - 09:30 0.50 SAFETY MTG - CMPRUN 09:30 - 10:30 1.00 RURD - ELEC CMPRUN 10:30-11:15 0.75 RUNPUL ELEC CMPRUN 11,:15 -11:45 0.50 LOG- CSG- CMPRUN 11 :45 - 12:45 1.00 RUNPUL ELEC CMPRUN 12:45 - 13:15 0.50 PULD - BHA- CMPRUN 13:15 - 13:30 0.25 SAFETY MTG- CMPRUN 13:30 - 14:00 0.50 PULD - BHA- CMPRUN 14:00 - 15:00 1.00 RUNPUL ELEC CMPRUN 15:00 - 15:05 0.08 LOG- CSG- CMPRUN 15:05 - 15:30 0.42 BLOWDNTBG - CMPRUN 15:30 - 17:00 1.50 RURD - ELEC CMPRUN 12/11/2004 10:00 - 10:30 0.50 SAFETY MTG - CMPFLW 10:30 - 17:30 7.00 RURD - COIL CMPFL W 17:30 - 18:30 1.00 TEST- BOPE CMPFLW 18:30 - 19:00 0.50 SAFETY MTG- CMPFLW 19:00 - 21 :00 2.00 TEST- BOPE CMPFLW 21 :00 - 21 :30 0.50 BLOWDNCOIL CMPFLW 21:30 - 23:15 1.75 RUNPUL COIL CMPFLW 23: 15 - 02:45 3.50 PUMP - N2 - CMPFLW 02:45 - 03:45 1.00 RUNPUL COIL CMPFLW 03:45 - 05:00 1.25 JET- N2 - CMPFLW 05:00 - 06:00 1.00 JET - N2- CMPFLW 12/12/2004 06:00 - 07:45 1.75 JET- N2- CMPFLW 07:45 - 09:00 1.25 RUNPUL COIL CMPFLW 09:00 - 14:30 5.50 RURD - COIL CMPFLW 12/13/2004 09: 15 - 11: 15 2.00 11:15-11:30 0.25 11 :30 - 14:00 2.50 Start: Rig Release: Rig Number: Spud Date: 8/1/1998 End: Group: 12/8/2004 Description .of Operations Arrive on location with permit and hold safety meeting while pad is plowed and sanded. Well has been shut in, but was flowing 11 OOMscfd at 740psi. RU electric line unit. PU GR/CCL and 2.74" gauge cutter RIH wi assembly. Tag at 5628' (sliding sleeve) and work through. Drift tubing and casing to 6200' to ensure all clear to proposed perfs. Obtain correlation with GRICCL POOH wi tool string. At surface, lay down tool GR/CCL/GC. Layout tubing patch. Hold safety meeting to discuss radio silence. Arm firing head and PU RIH wi Owen special clearance patch (ID=2.25"). Correlate patch and fire. See good indication and tag patch set at 5662'-5693.5 Bleed down tubing while POOH. At surface with tool. THP down to 540 psi (line pressure) with no flow. RD E-line and depart location. BJ arrive on location. Sign in, obtain permit, and hold safety meeting. Rig up equipment including riser to BOP. Stab CT. PU injector head. RU flowlines and BHA to permit standard and reverse circulating. Load coil tubing to pressure test. Having problems with fluid pump rate gauge. Hold crew change safety meeting. Complete shell test. Pressure/Ftn test blind rams and tubing rams to 300/4500psi. Purge methanol from CT wi N2. RIH wi CT. Begin pumping N2 down annulus taking returns to CT at 350 scfm at 5700' per BJ pumping program. Pump N2 varying rates and wait to see fluid to surface. Decide to POOH and check nozzle for plugging. Shut down N2 unit. Begin to see returns at suface at 1100'. Cool down N2 unit to resume pumping and run back in hole. Made 18bbl fluid and N2 broke through to surface. RIH to below tubing tail and circ at minimum rate waiting for more N2. Lost most N2 pressure while flowing to tank. Suspect fluid level was higher than design and first bite of fluid was too large given pressure restrictions. Estimate original fluid level at 3700' With more N2 available, continue reverse circulating from 6400' making additional10bbl. PUH to tubing tail to allow N2 circulation to lift CT. Run back in to 6200' and continue pumping N2. Start seeing N2 to surface wi CT deep indicating most fluid dried up. RIH to 6400' and continue taking returns to ensure perf zone will remain clear of produced water. POOH wI CT. Shut in choke when water returns stop trapping 1000psi N2 pressure. At surface. Freeze protect reel and rig down CT unit. Stack equipment aside for mob to West Fork WL at pad, held PJSM, secured work permit. RU wireline unit. Ready to arm guns. Held Saftey meeting prior to arming gun. Went to communication black out and radio silence. Man stationed at the pad gate. Armed 1 11/16" Owen swing Jet 2 perforating gun with CCL and weight bar. Gun number1 - 15'. RIH to bottom. WHP= 1075 psig. Used WHP to PT lubricator. Printed: 1/27/2005 8:25:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') Marathon Oil Company ()peratiQn$$l.Imrnary Report STERLING UNIT 32-9 STERLING UNIT 32-9 RECOMPLETION Start: Rig Release: Rig Number: Date Sub From - To Hours Code Code Phase 12/13/2004 14:00 - 14:45 0.75 14:45 - 15:00 0.25 15:00 - 15:50 0.83 15:50 -16:15 0.42 16:15 - 17:00 0.75 17:00 - 18:00 1.00 18:00 - 19:00 1.00 12/16/2004 07:00 - 16:00 9.00 12/8/2004 ) Page 2 of 2 Spud Date: 8/1/1998 End: Group: Description of Operations Gun #1 on bottom correlate to open Schlumberger log dated No.6, 1998. Pulled gun up to perforate from 6113 - 6128' DIL. shot gun, pressure went up to 1900 psig in 5 minutes. POOH with gun. OOH with gun. Verified the gun shot. MU gun number 2. RIH with gun#2, correlate to same log. Pulled gun up to shoot from 6098 to 6113' DIL, shoot gun number 2, no change in surface pressure. POOH with gun. OOH with gun, all shots fired. Start flowing well to flow back tank to blow off nitrogen left from coil during the reverse circulation. RD e line unit. secure well. Good gas to flow back tank. Roll the well into production. Started well on line at 1.3 mmcfpd. AT 1890 psig. Open well up to 3.5 mmcfpd. Moniotor well, no water, WHP = 1828 psig at 3.3 MMCFPD rate. Wire line unit left lease RD flow back equipment from well. Released choke, light plants heaters. Printed: 1/27/2005 8:25:41 AM ) ICY~"o4'L ) Suþject: SU 32-9 Patch tubing and perforate Upper Beluga. From: "Titus, Denise M." <dmtitus@marathonoil.com> Date: Mon, 06 Dee 2004 14:42:50 -0900 T<# \víntón~äubert@adf1':\in~state~~k~ us: : . . Winton, Please see attached procedure to isolate the Sterling perforations and add Upper Beluga perfs in well SU 32-9. Sundry approval for this work was obtained some time ago, but the work was not completed. The procedure differs from the original in that a tubing patch will be required to isolate the Sterling perforations. Let me know if you have any questions. Thank you, Denise Titus Production Engineer Marathon Oil Company 907.283.1333 «SU 32-9 Upper Beluga Revised for Casing Patch.doc» «SU 32-9 Upper Beluga.ZIP» 32-9 Upper Beluga Revised for Casing SU 32-9 Upper Beluga Content-Description: Revised for Casing Patch.doc Content-Type: application/msword Content-Encoding: base64 32-9 Upper Content-Description: SU 32-9 Upper Beluga.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 SC,ANNEO DEC 1 4 2004 ~RAmo~ ) ) Marathon Oil Company Alaska Region ABU SU 32-9 Recompletion Sterling Unit, Pad 43-9 WBS # RW.03.09556.CAP API # 50-133-20485 History: SU 32-9 was drilled as a Sterling Gas producer. After being shut in the well returned to production at 600 mcfd and 5 bwpd. Log analysis indicates upper Beluga potential from 6,098' to 6,128'. Objective: Shut in the Sterling B-4 (5679' -5686') interval behind the sliding sleeve and perforate the upper Beluga from 6,098' to 6,128' to evaluate for rate and reserves. Procedure: 1. S1 well 24 hours prior to RU of slickline. 2. MIRU flow back tank, chicksan, hard line and choke skid. Pressure test flow back iron to 2500 psi. 3. M1 slickline unit. a. Hold pre-job safety and environmental awareness meeting. RU slickline uni t. b. MU lubricator and BOPE to tree. Test lubricator and BOPE to 2500 psi. c. RIH with 2.75 GR to establish fluid level and verify PBTD, POOH. d. MU 30' Owen Special Clearance Tubing Patch with dummy elements for testing patch length tolerance on slick line. R1H to confirm patch can be installed in tubing across Sterling production interval. Shorten-Lengthen patch as well profile of 3.5 production tubing will allow. 4. Move in e-line company. a. Hold pre-job safety and environmental awareness meeting. RU E-line unit. b. MU lubricator and BOPE and pump in sub to tree. Test lubricator and BOPE to 2500 psi. Monitor wellhead pressures for build while perforating. c. MU Owen Special Clearance Tubing Patch with length of patch identified in step 3. RIH and correlate to tubing collars on Expro production log. Set patch across Sterling B-4 (5679' -5686') production interval with overlap above and below. POOH. ') ) d. Blow down well to check for patch integrity. If well does not blow down set an additional patch across sliding sleeve located at 5630', leaving room to sever tubing below Halliburton PHL packer at 5573 with jet cutter. Repeat attempt to blow down well. If well does not blow down a rig workover will pull tubing and replace the interval between the packers. e. IF well blows down and does not build pressure, reapply gas pressure to 1400 psi from SU 41-15 for required under balance to perforate UB. f. MU 15' 1 11116' Owen Swing Jet II perforating gun with CCL and weight bar. RIH and correlate to Schlumberger perforation summary log dated November 6 1998. g. Perforate interval from 6,113' to 6,128'. POOH h. MU 15' 1 11116' Owen Swing Jet II perforating gun with CCL and weight bar. RIH and correlate to Schlumberger perforation summary log dated November 6 1998. i. Perforate interval from 6,098' to 6,113'. POOH J. RDMO e-line unit. 5. Flow well to tank to clean up. a. Ifwell will flow at unload rate (3.6 to 4.0 MMSCFPD) above minimum FTP of 1500 psi do not increase rate until well stabilizes. b. Maintain a minimum flowing tubing pressure of 1500 psi which equates to a 1715 psi BHP (30% drawn down) with a methane gradient and minimal water production. c. Turn well to production once stabilized rates and pressures are observed. . ') At - ~ . Cameo KBUG-L TS Chemical Injection ...or. ~ ..-II ¡j ------ ~ ::":;;:i:) ~~: Mandrelw/1/4" (.049 wall) Chemical injection ~ [@ f line @ 998' (1" chemical injection valve installed ¡¡1~ it :¡¡¡ ¡¡1\ 2/12/99) ~~ [ :~¡ f:¡ ~¡: . .H--':" ~1. McMurry SMO-1 Gas Lift Mandrel @5521' (1" :*: . j>; ~~¡ : ~ ~~: dummy valve installed 2/15/99) I.~~ I ¡~ . ........:.:. . L----- Halliburton PHL Retrievable Packer @ 5,573' I I ~ I 11¡ ~'.~ ': i4: ,.-- . . . '; »~.:: ,¡} . It.¡ ~, I,..,..g¡ :, --- 't~~ i~' t; E-line tagged PBTO at 6810' 11/4/98 I I I ,. 'W': ~ ~: ~: i i I i ~~ ;:::~;~::~::~.=:~::A Lt.-.. ,..~..~.~..>.,.~. Y~¡~1rî~tfJt ) ~ ~:: ¡:~ ~ I ~:: :~* ¡~ ~~ ií;i. 13 3/8" 68 ppf K-55 n/a 0 80 ... 95/8" 47 ppf P-110 BTC 0 2111 Halliburton XU sliding Sleeve @ 5630' w/ X- Profile (10 2.813" Opened 2/15/99) Sterling B-4 Perforations 5679-5689' AIT X-Nipple @ 5896' ( 102.813") Wireline re-entry guide @ 5,909' Proposed Upper Beluga Perfs 6,098'-6,128' 7" 29 ppf L-80 BTC 0 6858 Well Name & Number: SU 39-2 Lease I Sterling Unit County or Parish: #REF! I State/Provo #REF! I Country: I #REF! Perforations: (MO) (TVO) I Angle/Perfs Angle @KOP and Depth #REF! I KOP TVO I #REF! BHP: #REF! BHT: #REF! Completion Fluid: FWHP: FBHP: FWHT: I FBHT: I I Other: I~S.-o42- Subject: BC-9L and'SU 32-9 From: "Eynon, Don" <deeynon@marathonoil.com> Date: Thu, 01 Jul 200421 :12:59 -0800 tØ:,Wi;õ~~~¿a\Jb~r;t~aarpiii¡'$t~t~~~~~j9~\~,::.i,';',;¡i-~,:,I;:: ",.I!~' ":":":' I". ' "r 'e>' " CÇ:'"l'it~s~'P~r1is~M~"'~prørfitY~@M~rê~hpng)ilrç9rn~ Winton, Per our conversation of Wednesday here is the Sundry Application and associated documentation for work on BC-9L via email, a hard copy will also go out today. The work entails identifying the zone making water with a production log and then isolating it with a casing patch. We ran a temp survey and the source of the water is not as clear cut as we thought so we will be watching it over the weekend and then deciding if we need to do a PL T for further clarification. I do not anticipate setting a patch any earlier than Thursday of next week, if not later. «AOGCC BC 9 Cover Letter Sundry.doc» «Upper Beluga Patch.doc» «BC 9.xls» «Application for Sundry Approval Form 1 0-403 Rev 2004.xls» I q g .' 04 2- In regard to the Sterling Unit well SU 32-9 Sundry application # 303-297. The approved procedure was written to isolate the Sterling Pool by closing a sliding sleeve and adding Beluga perfs. We have attempted to isolate the Sterling perforations by closing the sleeve but still had production, a subsequent PL T indicates a hole in the 3.5" tubing straddling the Sterling pool. We would like to set a 3.5" tubing patch across this interval and then test the wellbore integrity, if successful we will then proceed with adding the Beluga perforations. As we discussed we will proceed with the current sundry approval and report the work on the subsequent Report of Operations, please confirm this is OK or let me know if an additional sundry is needed. Thank You Don Eynon Marathon Oil Company Production Engineer 907-283-1337 Office 907 -398-9954 Cell 877-950-7558 Pager BC 9 Cover Letter Content-Description: AOGCC BC 9 Cov~r Letter Sundry.doc Content-Type: application/msword Content-Encoding: base64 Upper Beluga Content-Description: Upper Beluga Patch.doc Content-Type: application/msword Content-Encoding: base64 Content-Description: BC 9.xls Content-Type: application/vnd. ms-excel Content-Encoding: base64 Application for Sundry Approval Form 10-403 Rev Application for Sundry Content-Description: Approval Form 10-403 Rev 2004.xls Content-Type: application/vnd .ms-excel Content-Encoding: base64 Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907~564-6489 September 24, 2003 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Sundry Notice Field: Sterling Unit Well' Sterling Unit 32-9 Dear Ms. Palin Enclosed please find the two Application for Sundry Approvals along with an operations program and a wellbore diagram. The first Sundry Application is for an operations shut down for isolating the Sterling B4 sand behind a sliding sleeve. The second Sundry Application is for perforating the Upper Beluga sand. If you require further information, I can be reached at 907-564-6318 or by e-mail at dee ynon@ ma ratho noil. com. Sincerely, Donald Eynon Operations Engineer Enclosures' Sundry Notice Operations Plan Wellbore Diagram STATE OF ALASKA ~, ALASKA OIL AND GAS CONSERVATION COMMIbSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon~-~ Suspend Well~-] Operation ShutdownF-'--~ Perforater-'-] Variancer~ Annular DisposalF-- Alter CasingS---7-] Repair WoIIF-1 Plug Perforations[-'--] Stimulate~--~ Time Extensionr-~ Other~'J Change Approved Program[---~ Pull Tubing~----'~ Perforate New Pool[~ Re-enter Suspended Well~--~ 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company DevelopmentE~ ExploratoryE~ 98-42 3. Address: Stratigraphicl I Servicel I 6. APl Number: PO Box 196168, Anchorage, Alaska 50- 133-20485 7. KB Elevation (ft): 9. Well name and number; 265' KB, 237.25' GL Sterling Unit 32-9 8. Property Designation: 10. Field/Pools(s): A-028063 Sterling Unit, Un-named Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft.) ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): Plug (measured): Junk (measured): 6,858' MD I 6,336' TVD 6,820' MD I 6,302'TVD Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 3/8" 80' 80' Surface 2111' 9 5/8" 2,111' 2,072' 9440 psi 5310 psi Intermediate Production 6858' 7" 6,858' 6,336' 8160 psi 7020 psi Liner Perforation Depth MD (ft): I Perforation Depth ,TVD (ft): Tubing Size: ITubing Grade: ITubing MD (ft.): 6,098'-6,128' MD I 5,658' - 5,685 3.5" I N-80 I 5,909' Packers and SSSV Type: Packers and SSSV MD (ft): PHL Packer at 5573', XU sliding sleeve @ 5,630, F Packer @ 5877' '12. Attachments: Description Summary of ProposalF'1 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ' ] I Exploratory F"] Development 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/29/2003 OilF-] Gas~ Pluggedr~ Abandonedr'~ 16. Verbal Approval Date: WAG F-] GINJ['~ WINO ~--'~ WDSPL Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Donald Eynon Title Production Engineer Signature ~.~v~ "~,~_ ~'/'~ :~"A ~ Phone (907)-564-6318 Date 9/23/2003 Commission Use Only ISundry Number: Conditions of approval: Noti.jf~ Commission so that a representative may witness 50 'Z~_ Plug Integrity [-"'-'] BOP Test [--"-] Mechanical Integrity Test F~ Location Clearance E~ Other: r o - /o'7 Subsequent Form Requested: Approved by: . .,...~,~ COMMISSIONER THE COMMISSION Date: F°rm 10'403 Revised O'RI61N/tL s~ .~plicate Marathon Oil Company Alaska Region ABU SU 32-9 Recompletion Sterling Unit, Pad 43-9 WBS # RW.03.09556.CAP API# 50-133-20485 History: SU 32-9 was drilled as a Sterling Gas producer. After being shut in the well returned to production at 600 mcfd and 5 bwpd. Log analysis indicates upper Beluga potential from 6,098' to 6,128'. Objective: Shut in the Sterling B-4 (5679'-5686') interval behind the sliding sleeve and / perforate the upper Beluga from 6,098' to 6,128' to evaluate for rate and reserves. Procedure: 1. SI well 24 hours prior to RU of slickline. , MIRU flow back tank, chicksan, hard line and choke skid. Pressure test flow back iron to 2500 psi. 3. MI slickline unit. . a. Hold pre-job safety and environmental awareness meeting. RU slickline unit. b. MU lubricator and BOPE to tree. Test lubricator and BOPE to SITP. c. RIH with 2.7 LIB to establish fluid level and verify PBTD. /,,. d. RII-I with XU shifting tool to sliding sleeve at 5630'. Close sleeve. POOH. Blow down well to production facility to an estimated BHP of 1400 psi and shut in well. Monitor well for pressure build to verify sliding sleeve is holding. 5. Move in e-line company. a. Hold pre-job safety and environmental awareness meeting. RU E-line unit. b. MU lubricator and BOPE and pump in sub to tree. Test lubricator and BOPE to 2500 psi. Monitor wellhead pressures for build while perforating. c. MU 10' 2.5" HSD power jet 2506 HMX perforating gun with CCL and weight bar. RIH and correlate to Schlumberger perforation summary log dated November 6 1998. d. Perforate interval from 6,118' to 6,128'. POOH e. MU 10' 2.5" HSD power jet 2506 HMX perforating gun with CCL and weight bar. RIH and correlate to Schlumberger perforation summary log dated November 6 1998. f. Perforate interval from 6,108' to 6,118'. POOH g. MU 10' 2.5" HSD power jet 2506 HMX perforating gtm with CCL and weight bar. RIH and correlate to Schlumberger perforation summary log dated November 6 1998. h. Perforate interval from 6,098' to 6,108'. POOH i. RDMO Schlumberger. 6. Flow well to tank to clean up. a. If well will flow at unload rate (3.6 to 4.0 MMSCFPD) above minimum FTP of 1500 psi do not increase rate until well stabilizes. b. Maintain a minimum flowing tubing pressure of 1500 psi which equates to a 1715 psi BHP (30% drawn down) with a methane gradient and minimal water production. c. Turn well to production once stabilized rates and pressures are observed.. Contacts: Completion Reservoir Eng Geologist Work Phone Pa~er Don Eynon 564-6318 268-6953 Ralph Affinito 564-6303 231-3775 Bob Lanz 564-6427 Sterling Field Well SU 32-9, Pad 43~9 / Marathon Oil Co., Alaska Region AP!: 5{)-I Y3-20485 KB-Gl,: 29.71' KB-Tt'-ff': 30.()0' 2..,~ 12' 'FSI.,, 449' FEL Sec. 9, T5N, RIOW, S.lVl. Cmnco K]BUO-LTS chemical injection mandrel w/ 1/4" (0.04~9" wall) injection 1.ine ((?.?. 998' 1" chemical injec, tion valve instal.led 2/12/99 Tubing: 3-1/2", 9.3//, N-80, EIJE 8rd, AB-Mhd. (11 .ints o159.2# NU 13utt., 660' - 992') 86' AI'[ (6 spt; 60° phased) F.,,lecst~:ic tine tagged PBTi.D (('(), 68 [0' [',[,M (11/4/98) Drive Pipe 9-518", 47#, P-110, BTC Casi.ng (~211 i' Cm.t ,,vi 620 sk.s of class G M.{:Murry SMO-I Gas Lift Mandrel '@ 5521" (1 ". dm'nmy' valve ir~.stal, led 2/'15/99') Halliburton. P'f!IZL Retrievable Pat, kef Hallibm'ton XU sliding sleeve ~ 5630' w/X-profile (iff) = 2.813") (opened 2/1.5/9.9) Loc'ator sub ([} 5877 Baker model F permatmrtt packer (~ 58'77' w/10' sealbore X N'ipple (b) 5896' (ID = 2.813") Wi.mi ine 'I>,.e-Entry, G-uide (~ 5909' n", 29#~ L-gO, BTC casing (~! 68>8 Cmt w/690 sks of class O Last Rev: JCi.l-~: 212(')f':)0 198-042-0 STERLING UNIT 32-09 50- 133-20485-00 MARATHON OIL CO Roll #1: Start: Stop Roll #2: Start Stop MD 06858 TVD 06336 Completion Date: 11/9/98 Completed Status: 1-GAS Current: Name L DSSI 1 /' BL(C) 2110-6848 OH 5 12/2/98 12/3/98 L DSSI/GR v/FINAL BL(C) 2110-6848 OH 12/1/98 12/2/98 L GR/P~I~/~//~]t~.~:[,~I LGR 5350-6810 8~ CH 2/16/99 2/16/99 L PE~ ~ ~'a~3-1 LGR5450-58003[~O~ CH 2/16/99 2/16/99 L PEX-AIT/GR ~'F~ BL(C) 2110-6854 OH 12/1/98 12/2/98 L PEX-~T~DT/GR ~~ BL(C)2110-6854 OH 12/1/98 12/2/98 L PEX-CMRT/GR ~~ BL(C)2110-6854 OH 12/1/98 12/2/98 L PIUGR ~F~ BL(C)2110-6848 OH 12/1/98 12/2/98 R DmSRVY ~ BH 0-6858 OH 3/1/99 3/1/99 D R SRVYCALC d BHI 225-6858 O 11/16/98 11/19/98 Interval Sent Received T/C/D Tuesday, January 09, 2001 Page 1 of 1 -._. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL X lb. TYPE TEST STABLILIZEDr i/--i NON STABILIZED ANNUAL MULTIPOINT IX I CONSTANT TIME SPECIAL OTHER ISOCHRONAL X 2. Name of Operator 7. Permit No. Marathon Oil Company 98-42 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20485 4. Location of Well 9. Unit or Lease Name At surface Sterling Unit 2312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. !10. Well Number SU 32-9 11. Field and Pool Sterling Field 5. Elevation in feet (KB, DF etc.) I6. Lease Designation and Serial No. Sterling Pool 27.8' KB-GL] A-028063 11/98 6858' 6820' Single completion, cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ff. Perforations: From To 7" 29~ 6.184" 6858' 5679' - 5686' MD 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 3~" 9.3~ 2.992 5909' 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 5814'I -] - 0.566 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg.r~ Csg. E~] 104 45 14.65 23. Length of flow channel (L) 5679' I Vertical Depth (H> I 5279' Ga. %CO2 1%N2 0.25 0.2 %H2S I Pr°ver 0 Meterrun I Taps X 24. Flow Data Tubing Data Casing Data Choke Prover Odfice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3 X 1.75 6.6 4.1 72 1972.83 55 2.000 2. 3 X 1.75 6.6 7.5 67 1926.42 57 2.000 3. 3 X 2 6.7 8.1 63 1863.4 63 2.000 4. 3 X 2 6.6 6.0 70 1910.85 63 6.000 5. X Basic Coefficient ~/ (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 80.0 0.9887 1.329 2,155 2. 80.0 0.9933 1.329 3,975 3. 109.0 0.9971 1.329 5,910 4. 109.0 0.9905 1.329 4,270 5. Pg. 125 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 532 0.566 2. 527 3. 523 Critical Pressure 4. 530 Critical Temperature 5. Form 10-421 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE n:\drlg~sterling~su32-9~AOGCC4PT, xls Pc 2,012 Pc2 4,046,977 Pf PF 0 No. Pt Pt2 Pc2 - PF Pw Pv¢ Pc~ - Pw~ Ps Ps~ PF- Ps2 1. 1,973 3,892,058 154,919 ...... 2. 1,926 3,711,094 335,883 3. 1,863 3,472,260 574,718 .... 4. 1,911 3,651,348 395,629 .... 5.~ 0 0 25. AOF (Mcfd) 26,079 n 0.672 Remarks: Data performed with downhole pressure gauges. I hereby certify~at the foregoing is~rue and correct to the best of my knowledge. Signed~~ ~i,~~~~'-~'~ ~,3o~', e.,¢ Title Production Engineer Date 4/12/99 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ -,] hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE n:\drlgtsterling~su32-9~,OGCC4PT.xls IPR Company Marathon Oil Company Field Sterling Unit Well SU 32-9 su3294pt Test Multi-rate and PBU Date 4/5-6/99 Gauge Halliburton 106 _ -- -- -- -- // (Pavg2-Pwf~) [psia2] versus Qg [MSCF/day] C and n I.P.R. Test type Modified Isochronal Reservoir Pressure AOFP C n 1978.96 psia 26079.1 MSCF/day 0.788494, MSCF/day/psia**2n 0.671845 Test points 3 04-1999 Sterling Unit 32-9 Multi-rate and PBU, 4/5-$/99 Saphir Level 3 V2.20J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL X lb. TYPETEST STABLILIZED' '1--1 NON STABILIZED ANNUAL MULTIPOINT IX I CONSTANT TIME SPECIAL OTHER ISOCHRONAL X 2. Name of Operator 7. Permit No. Marathon Oil Company 98-42 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20485 4. Location of Well 9. Unit or Lease Name At surface Sterling Unit 2312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. 10. Well Number SU 32-9 ~ 11. Field and Pool Sterling Field 5. Elevation in feet (KB, DF etc.) 16. Lease Designation and Serial No. Sterling Pool 27.8' KB-GLI A-028063 11/98 6858' 6820' Single completion, cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7" 29¢¢ 6.184" 6858' 5679' - 5686' MD 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 3~" 9.3/¢ 2.992 5909' 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 5814'I '-I '- 0.566 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. r~ Csg.['---] 104 45 14.65 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3 X 1.75 6.6 4.1 72 1972.83 55 2.000 2. 3 X 1.75 6.6 7.5 67 1926.42 57 2.000 3. 3 X 2 6.7 8.1 63 1863.4 63 2.000 4. 3 X 2 6.6 6.0 70 1910.85 63 6.000 5. X Basic Coe, fficient ~ (24--Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 80.0 0.9887 1.329 2,155 2. 80.0 0.9933 1.329 3,975 3. 109.0 0.9971 1.329 5,910 4. 109.0 0.9905 1.329 4,270 5. Pg. 125 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 532 0.566 2. 527 3. 523 Critical Pressure 4. 530 Critical Temperature 5. Form 10-421 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE n:\drlg\sterling~su32-9~,OGCC4PT, xls :. Pc 2,012 Pc2 4,046,977 Pf PF 0 No. Pt PF Pc~ - Pt2 Pw Pw~ Pc~ - Pw~ Ps Ps~ PtTM - Ps2 1. 1,973 3,892,058 154,919 ...... 2. 1,926 3,711,094 335,883 ...... 3. 1,863 3,472,260 574,718 ...... 4. 1,911 3,651,348 395,629 ..... 5. 0 0 25. AOF (Mcfd) 26,079 n 0.672 Remarks: Data performed with downhole pressure gauges. I hereby certify~at the foregoing is~rue and correct to the best of my knowledge. Signed~ ~ '~[~~~~ ~.3o~.,~F~_\~,e.,¢ Title Production Engineer Date 4/12/99 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ ~ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~/ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE n:\drlg\sterling~su32-9~,OGCC4PT, xls IPR su3294pt Company Marathon Oil Company Test Multi-rate and PBU Field Sterling Unit Date 4/5-6/99 Well SU 32-9 Gauge Halliburton 106 104 (Pavg=-PwF) [psia2] versus Qg [MSCF/day] C and n I.P.R. Test type Modified Isochronal Reservoir Pressure AOFP C n Test points 1978.96 psia 26079.1 MSCF/day 0.788494, MSCF/day/psia**2n 0.671845 04-1999 Sterling Unit 32-9 Multi-rate and PBU, 4/5-6/99 Saphir Level 3 V2.20J Alaska ~ ..... ~ion Domestic Production Marathon Oil Company P.O. Box 196168 AnchOrage, AK 99519-6168 Telephone 907/561-5311 February 16.1999 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK_9_9501-3120 The following logs are enclosed: ~o=_ Sterling Gas Unit Reproducibl 1) SU 41-15 Packer Setting Record Run: Three January 4. 1999. 2) SU 41-15 Perforating Record Run: Three January. 4. ! 999. 3) SU 41-15 Gamma Ray Collar Locator Log Run: Three January. 4, 1999. 4) SU 41-15 Perforation Summary. Log Run: One January 12.1999. 5) SU 41-15 Depth Determination Run: One January 14. 1999. 6) SU 41-15 Depth Determination Log Run: One January 17. 1999.- 7) SU 32-9 Perforation Summary. Log Run: One November 6, 1998. 8) SU 32-9 Gamma Ray/CCL Packer Setting Summary Run: One November 4. 1998. 9) SU 41-15 Caliper Gamma Ray Run: Two December 26. 1998. 10) SU 41 - 15 Density, Neutron Gamma Ray, Caliper 'i99q - Gas Cons. ¢omrni~ ~n0h0ra,qe A subsidiary of USX Corporation Environmentally aware for the long run. Alaska F,~i°n Domestic Production Marathon P.O. Box 196168 Oil Company Anchorage, AK 99519-6168 Telephone 907/561-5311 **Platform Express** Run: Two December 26. 1998. ~ I 11) SU 41-15 Array Induction Gamma Ray, Caliper **Platform Express** Run: Two December 26. 1998. 12) SU 41-Dipole Shear Sonic Gamma Ray 15 Run: Two December 26, 1998. 13) SU 41-15 Natural Gamma Ray Spectroscopy Run: Two December 26. 1998. 14) SU 41-15 Comb. Magnetic Res. Tool Gamma Ray Run: Two December 26. 1998. 15) SU 41-15 Density. Neutron Gamma Ray, Caliper **Platform Express** Run: One December 6. 1998. 16) SU 41-15 Array Induction Gamma Ray **Platform Express** Run: One December 6, 1998. 17) SU 41-15 Natural Gamma Ray Spectrometry. Run: One December 6, 1998. 18) SU 41-15 Relabeled Dipole Sonic PEX/AIT DSI Run: One December 6. 1998. 19) SU 41-15 Relabeled Dipole Sonic AITH/DSI/PEX Run: Two December 26. 1998. 20) SU 41-15 Array Induction **Platform Express** Run: One December 6. 1998. 21) SU 41 - 15 Density, Neutron Gamma Ray, Caliper Run: One **Platform Express** December 6, 1998. -~B !6 i999 22) SU 41-15 Natural Gamma Ray Spectrometry. Run: One December 6. 1998. ,';tlaska Oil & Gas ~ns, ,ql0h0r. ase 23) SU 41-15 Caliper Gamma Ray Run: Txvo December 26. 1998. 1 1 24) SU 41-15 Density. Neutron Gamma Ray, Caliper **Platform Express** Run: Two December 26. 1998. 1 1 1 1 25) SU 41-15 Natural Gamma Ray Spectroscopy Run: Two 1 A subsidiary of USX Corporation Enviror~mentally aware for the long run. 1 1 1 1 1 1 1 1 Alaska ~:gion Domestic Production Marathon Oil Company December 26. 1998. P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 \~O ~' O~-t \ { 26) SU 41-15 Comb. Magnetic Res. Tool Gamma Ray Run: Two 1 December 26, 1998. 27) SU 41-15 Array Induction. Gamma Ray, Caliper Run: Two **Platform Express* December 26, 1998. 28) Su 41-15 LIS 9 track tape Run # 1 Sterling Gas Field/Marathon Oil Company: AIT/PEX/DIS/NGT/CMR Customer Tape Logged: December 6, 1998 1600BPI Start: 10376' Stop: 2132.5' Job#' 99004 (1 tape) 29) SU 41-15 LIS 9 track tape Run #2 Sterling Gas Field/Marathon (1 tape) Oil Company: AIT/PEX/NGT/DSI Customer Tape Logged: December 26, 1998 1600BPI Start: 12595.0' Stop: 10310.0' Job#: 99004 Please sign and return confirming you have received these documents. MARATHON OIL COMPANY ,% ~ "~ - Kirsten K. Gamel ,! ~)'~ : () Received B~~ ~'~ Enclosures Date: .~D/{~ /C/I C~ (''9 A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA AL/- A OIL AND GAS CONSERVATION COIV.__~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILE] GAS[~ SUSPENDEDE~ ABANDONEDE~ SERVICE[~ 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 98-42 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20485 4. Location of Well at Surface ;.. :. -. - ~:.~: ..; ?:~.~.~...,?,_~:~,~_,~.~ 9. Unit or Lease Name 2312' FSL, ~' FEL, Sec. 9, T5N, R10W, S.M... ..... ~;'-~'~ ~ ~.:~~ ~~. Sterling Unit At top of Producing Inte~al ~ ; ~ ~,~ 10. Well Number :.~____ ;~'~ SU Field 32-9 26~' FSL, 222~ FEL, Sec. 9, T5N, R10W, S.M. ~ : ~~ :r :~ ~.;,~.... ~ (~~ 11. At Total Depth ~ '~ ;-~¢~ and Pool 2859' FSL, 272~ FEL, Sec. 9, T5N, R10W, S.M. -- ~.~.~~. Sterling Unit 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Sterling Pool 5.1 27.8' KB-GL A-028063 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband.115. Water Depth, if offshore 116. No. of Completions 10/18/1998 10/30/1998 11/9/1998I N/A feet MS L] one 22. Type Electric or Other Logs Run PEX, AIT, DSI, DITE Pl21klA 'L 23 CASING, LINER AND CEMENTING RECORD ~ i ~ I ~ I I ~ ~ ~ ~/¢&~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULL~Z,_¢~¢-~ ~ 13 3/8" 6~ K-55 0 80 Driven Driven N/A 9 5/8" 47¢ P-110 0 2111 12-1/4" 620 sks N/A 7" 2~ L-80 0 6858 8-1/2" 690 sks N/A 24. Perorations open to Production (MD+TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.~ 5909' 5630' & 5877 Sterling B-4: 5679' - 86' MD, 5279' - 85' TVD 6 spf, 2-1/2" hollow carrier guns 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production l Method of Operation (Flowing, gas lift, etc.) N/A ~ N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I N/A FIowTubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (cor0 2~HOUR RATE--~ ~ress. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ~ter. Submit core chips. N/A Form 10-407 Rev. 7-1-80 N:\drlg~sterling~su32-9~AOGCOMPLXLW CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME VIEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Sterling B-4 5679' 5279' N/A 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby cedify lhat lhe foregoing i~ true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlgtsterling~su32-9~AOGCOMPL.XLW Sterling Field Well SU 32-9, Pad 43-9 Marathon Oil Co., Alaska Region API: 50-133-20485 KB-GL: 27.80' KB-TI-IF: 28.00' 2312' FSL, 449' FEL Sec. 9, T5N, R10W, S.M. Camco KBUG-LTS chemical injection mandrel w/1/4" injection line @ 998' Tubing: 3-1/2", 9.3#, N-80, EUE 8rd, AB-Mod. (11 jnts of 9.2# NU Butt., 660'- 992') Isolated Perforations Sterling B-4: 5679' - 86' A IT (6 spf, 600 phased) Electric line tagged PBTD (~ 6810' ELM (11/4/98) PBTD= 6820' TD: 6858' 13-3/8", 68#, K-55 Drive Pipe @ 80' 9-5/8", 47#, P-110, BTC Casing @ 2111' Cmt w/620 sks of class G McMurry SMO- 1 Gas Lift Mandrel @ 5521' (1" dmmny valve installed 11/4/98) Halliburton PHL Retrievable Packer @ 5573' Halliburton XU sliding sleeve @ 5630' w/X-profile (ID = 2.813") Locator sub @ 5877 Baker model F permanent packer @ 5877' w/10' sealbore X Nipple @ 5896' (ID = 2.813") Wireline Re-Entry Guide @ 5909' 7", 29#, L-80, BTC casing ~ 6858' Cmt w/690 sks of class G Last Rev: JGE, 11/16/98 Sterling Unit #32-9 17 Oct: Accepted rig @ 12:00 p.m. 10/16/98. Start N/U diverter and R/U top drive. 18 Oct: Finish R/U top drive and stack. Test diverter, alarms, and accumulator. P/U 5" dp and HWDP f/drlg w/top drive. Start P/U BHA. 19 Oct: Finished P/U BHA and RIH. Tagged @ 62'. Drlg 12-1/4" hole. Start building 2.5 degrees/100' @ 970'. Rotate, slide and surveys. 20 Oct: Drlg w/MWD and mud motor. Circ and short trip. Circ hole clean. TOOH L/D BHA. 21 Oct: R/U to run csg. Ran 3 jts and tagged bridge @ 121', couldn't wash through. Pulled csg OOH and ran in to clean to bottom. Ran 49 jts 47#- Buttress csg. Washing to bottom. 22 Oct: Cmt 9-5/8 csg w/DS.-WOC-N/D stack and cut csg. Start welding on head. 23 Oct: Pressure test wellhead. Nipple up BOP. Testing BOPE. 24 Oct: Pressure test BOP. Pick up and stand back 141 jts drill pipe in derrick. Pick up BHA and TIH. PT casing. Drill out cement. 25 Oct: Drill cement. Run FIT test. Dump and clean mud tanks. Fill tanks and mix FLO PRO/KCL mud. 26 Oct: Mix mud and displace hole. Drill and survey 2125-2748'. Wiper trip to surface csg. Drill and survey 2748-3100'. 27 Oct: Drill and survey 3100' - 3513'. Trip for new BHA. Clean out to bottom. TOH to csg shoe and repair top drive. 28 Oct: Trip in hole. Drill and survey 3513' - 4944'. Wiper trip through new hole. Drill and survey to 5350'. 29 Oct: Drill and survey 5350' - 6162'. Circulate and trip for bit. 30 Oct: TIH. Drill and survey 6162-6858'. Circulate and condition hole for logs. 31 Oct: Circulate. Trip out. Log with Schlumberger. 1 Nov: Log with Schlumberger. Trip in hole and circulate for casing. TOH laying down DP. 2 Nov: Trip out of hole. Rig up and run 7" production casing. Circulate and cement casing. Sterling Unit #32-9 (Continued) 3 Nov: Cement 7" casing with 690 sx 'G' cement w/additives. Set csg slips, nipple down BOP, install tbg head, and nipple up BOP. Pressure test BOP. 4 Nov: Pressure test BOP. Pick up 3-1/2" DP and TIH. Tag cement at 6659'. Drill cement to 6820'. PT csg to 3000 psi. Trip out of hole. 5 Nov: Trip out, pick up 7" csg scraper and trip to bottom. Displace mud from hole with 3% KCL. Trip out, laying down DP and BHA. 6 Nov: Set permanent packer on electric line. TIH with tubing. Perforate Sterling B-4 Sand. 7 Nov: TIH with tubing. Set upper packer. Land tubing, ND BOPE, attempt to NU production tree. Prepare to skid rig. 8 Nov: 9 Nov: Prepare rig for skidding operation. Wait on tbg bonnet for 5M Christmas tree. Install new tbg bonnet and production tree. Pressure test to 5000 psi. Release rig for skidding operation. ~~=¢1_~ SURVEY CALCULATION AND FIELD WORKSHEET Jol, No. !)~!.~!!!4~§3_ .... Sidetrack No. Page .~! :[.,rt._] :~ Company _M_A__R~__T__I-!ON_.Q~ 9Q~_~5~ ..... Rig Contractor & No. 5o~'~...5.5 p~.~ ~9~ ..................... Field 5T~5I~(~ ~A5 t~l~[) ....... Well Name & No. PAD SU43-9/SU32-9 Su~ey Section Name MWD BHI Rep. T. DUNN - R. MALYEVAC ~LL DATA Target TVD ...... 0:'r) Target Coord. N/S ................... Slot Coord. N/S 2311.80 ...... Grid Correction 0.000 ._ Depths Measured Froln: RKB Target Description Target Coord. E/W Slot Coord. E/W -449.18 Magn. Declination 21.670 Calculation Me,od MINIMUM CURVATURE Target Direction (DD) BuildXWalkXDL per: 100fi~ 30m ~ 10m ~ Ven. Sec. Azim. 282.71~ Magn. to Map Corr. 21.670 Map North to: OTHER ..... S~VEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depfl~ Angle Direction Leng~ TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) {~'er ~m ~:T) Drop (-) Le~ (-) .......................................................................................... ~D" 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 18-OCT-98 MWD 225.00 1.00 2.79 225.00 224.99 0.34 1.96 0.10 0.44 0.44 18-OCT-98 MWD 353.00 1.31 0.98 128.00 352.96 0.83 4.54 0.17 0.24 0.24 ............................................................................................................................................................. 18-OCT-98 MWD 442.00 1.34 355.62 89.00 441.94 1.34 6.59 0.11 0.14 0.03 18-OCT-98 MWD 532.00 1.37 350.04 90.00 531.91 2.06 8.70 -0.15 0.15 0.03 ............................................................................................................................ 18-OCT-98 MWD 621.00 1.60 347.97 89.00 620.88 2.99 10.97 -0.60 0.27 0.26 .............................................................................................................................. 18-OCT-98 MWD 711.00 1.71 342.73 90.00 710.85 4.19 13.48 -1.26 0.21 0.12 18-OCT-98 MWD 800.00 1.80 343.06 89.00 799.80 5.55 16.08 -2.06 0.10 0.10 18-OCT-98 MWD 890.00 1.93 344.49 90.00 889.76 6.96 18.90 -2.88 0.15 0.14 19-OCT-98 MWD 986.00 2.38 323.50 96.00 985.69 9.24 22.06 -4.49 0.94 0.47 .................................................................................... 19-OCT-98 MWD 1016.00 3.18 309.80 30.00 1015.65 10.45 23.09 -5.50 3.45 2.67 ............................................................ 19-OCT-98 MWD 1081.00 4.54 299.80 65.00 1080.51 14.51 25.52 -9.12 2.33 2.09 ................................................................ 19-OCT-98 MWD 1176.00 5.77 295.22 95.00 1175.12 22.77 29.43 -16.70 1.36 1.29 -4.82 19-OCT-98 MWD 1206.00 5.97 296.98 30.00 1204.96 25.75 30.78 -19.46 0.90 0.67 5.87 19-OCT-98 MWD 1272.00 6.98 296.96 66.00 1270.54 32.97 34.15 -26.09 1.53 1.53 -0.03 ..... 19-OCT-98 MWD 1358.00 8.80 292.30 86.00 1355.72 44.52 39.02 -36.84 2.24 2.12 -5.42 19-OCT-98 MWD 1464.00 10.00 291.80 106.00 1460.30 61.60 45.51 -52.88 1.13 1.13 -0.47 19-OCT-98 MWD 1560.00 11.90 288.36 96.00 1554.55 79.68 51.73 -70.02 2.09 1.98 -3.58 19-OCT-98 MWD 1655.00 14.00 282.83 95.00 1647.13 100.93 57.36 -90.52 2.56 2.21 -5.82 19-OCT-98 MWD 1749.00 17.89 278.89 94.00 1737.50 126.71 62.12 -I 15.88 4.29 4.14 -4.19 19-OCT-98 MWD 1830.00 20.38 278.74 81.00 1814.02 153.20 66.19 -142.12 3.07 3.07 -0.19 19-OCT-98 MWD 1941.00 23.60 276.43 111.00 1916.93 194.58 71.61 -183.32 3.00 2.90 -2.08 19-OCT-98 MWD 2061.00 24.35 276.08 120.00 2026.58 243.03 76.92 -231.79 0.64 0.62 -0.29 Last Suvery in 12 1/4" Hole 25-OCT-98 MWD 2227.00 26.00 279.90 166.00 2176.81 313.37 86.81 -301.67 1.39 0.99 2.30 [ ~ ~ SURVEY CALCULATION AND FIELD WORKSHEET J,,b No. (!45_ _1. 7.~14~_8_~3 ..... Sidetrack No. }'age '~ Company MARATHON OIL COMPA__N_._Y ............ Rig Contractor & No.._N_0. r_d_!c_. A_K_'_D?!!!!~_}_g. - _g !60_ .... Field S_ T__E _R_ I_.. I_ N_ _Q (]~\_S. 5!L_:!~!)_ · Well Name & No. PAD SU43-9/SU32-9 Survey Section Name MWD BHI Rep. T. DUNN - R. MALYEVAC li~'~ WELL DATA Target TVD 0:T, Target Coord. N/S Slot Coord. N/S 2311.80 Grid Correction 0.000 Depths Measured From: RKB [~ MSL[i] SS ~_'.] Target Description Target Coord. E/W Slot Coord. E/W -449.18 Magn. Declination 21.670 Calculation Method MINIMUM CURVATURE ......... Target Direction (Dr>) Build\Walk\DL per: 100frei 30m[~ 10m [-1 Vert. Sec. Azim. 282.71 Magn. to Map Corr. 21.670 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /'W(-) DL Build ( +) Right (+) Comlnent Type ~FT~ (Dr)) (DD) {FT) (FT) (FT) (FT) ¢Pcr 100 FT) Drop (-) Left (-) 25-OCT-98 MWD 2324.00 27.50 276.30 97.00 2263.44 356.87 92.92 -344.88 2.28 1.55 -3.71 : ................................................. 25.-OCT-98 MWD 2420.00 28.30 278.80 96.00 2348.28 401.60 98.83 -389.40 1.48 0.83 2.60 25-OCT-98 MWD 2516.00 28.60 276.90 96.00 2432.69 447.16 105.08 -434.70 0.99 0.31 -1.98 25-OCT-98 MWD 2612.00 28.80 279.10 96.00 2516.90 493.10 111.49 -480.34 1.12 0.21 2.29 25-OCT-98 MWD 2708.00 28.90 276.00 96.00 2600.99 539.22 117.58 -526.25 1.56 0.10 -3.23 25-OCT-98 MWD 2804.00 29.00 277.50 96.00 2684.99 585.44 123.04 -572.39 0.76 0. I0 1.56 ............... 26-OCT-98 MWD 2996.00 29.20 277.00 192.00 2852.76 678.39 134.82 -665.02 0.16 0.10 -0.26 26-OCT-98 MWD 3186.00 28.50 278.00 190.00 3019.17 769.68 146.78 -755.91 0.45 -0.37 0.53 ................................................................................................................................................................................................................................................... 26-OCT-98 MWD 3375.00 28.70 280.20 189.00 3185.12 859.96 161.09 -845.23 0.57 0.11 1.16 .......................................................................................................... 26-OCT-98 MWD 3473.00 29.20 277.40 98.00 3270.87 907.28 168.34 -892.10 1.47 0.51 -2.86 -- 27-OCT-98 MWD 3657.00 25.30 279.20 184.00 3434.43 991.24 180.41 -975.45 2.17 -2.12 0.98 ......................................................................... 27-OCT-98 MWD 3847.00 25.80 277.50 190.00 3605.85 1072.94 192.30 -1056.52 0.47 0.26 -0.89 27-OCT-98 MWD 3943.00 24.00 280.30 96.00 3692.92 1113.26 198.51 -1096.45 2.24 -1.87 2.92 /" ....................... '~' .... 27-OCT-98 MWD 4038.00 24.40 280.60 95.00 3779.57 1152.17 205.58 -1134.75 0.44 0.42 0.32 ............ ................................................................................... 27-OCT-98 MWD 4134.00 23.70 282.50 96.00 3867.24 1191.28 213.40 -1173.07 1.09 -0.73 1.98 --. ........................................................................................................................ 27-OCT-98 MWD 4323.00 24.10 283.60 189.00 4040.04 1267.85 230.70 -1247.66 0.32 0.21 0.58 27-OCT-98 MWD 4420.00 24.50 283.70 97.00 4128.44 1307.76 240.12 -1286.45 0.41 0.41 0.10 27-OCT-98 MWD 4516.00 23.60 285.00 96.00 4216.11 1346.87 249.80 -1324.36 1.09 -0.94 1.35 27-OCT-98 MWD 4609.00 24.00 285.20 93.00 4301.20 1384.36 259.58 -1360.59 0.44 0.43 0.22 27-OCT-98 MWD 4706.00 24.30 285.40 97.00 4389.71 1424.01 270.05 -1398.87 0.32 0.31 0.21 ................................................................................................................................................................................................................................ 27-OCT-98 MWD 4801.00 24.10 287.40 95.00 4476.36 1462.86 281.05 -1436.22 0.89 -0.21 2.11 · 28-OCT-98 MWD 4897.00 23.70 287.90 96.00 4564.13 1501.61 292.84 -1473.28 0.47 -0.42 0.52 28-OCT-98 MWD 4992.00 23.70 285.90 95.00 4651.12 1539.69 303.94 -1509.82 0.85 0.00 -2.11 28-OCT-98 MWD 5087.00 23.70 287.00 95.00 4738.11 1577.79 314.75 - 1546.44 0.47 0.00 1.16 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-01483 Sidetrack No. Page 3 of 3 Company MARATHON OIL COMPANY ........................... Rig Contractor & No. Nordic AK _D...r_i!l_i~g - #160 Field STERLING GAS F!_E_!._D_ Well Name & No. PAD SU43-9/SU32-9 Survey Section Name MWD BHI Rep. T. DUNN - R. MAI.YEVAC i~'r~~ WELL DATA Target TVD ............ {t_fl_')_ ............... Target Coord. N/S ............... Slot Coord. N/S ....... 23_1_~_1:8._0_0 ........ Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -449.18 Magn. Declination 21.670 Calculation Method _M_I_NI_M~U_M- C_U__R_y_5.]_~_U__R__E Target Direction II)O) Build\Walk\DL per: 100ft[2~ 30m[-] 10in [-] Vert. Sec. Azim. 282.71 Magn. to Map Corr. 21.670 Map North to: OTItER SURVEY DATA Survey Survey Incl. ttole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+ ) / S(-) E(+) / W(Ti-- DL Build (+) Right (+) Comment Type (VT) (DD) (DD) (FT) (FT) (FT) (FT) Per 100 FT) Drop (-) Left (-) 28-OCT-98 MWD 5279.00 24.30 286.20 192.00 4913.51 1655.70 337.05 -1621.27 0.36 0.31 -0.42 28-OCT-98 MWD 5471.00 23.80 285.90 192.00 5088.84 1733.82 358.69 -1696.47 0.27 -0.26 -0.16 28-OCT-98 MWD 5661.00 24.30 287.00 190.00 5262.35 1811.08 380.62 -1770.73 0.35 0.26 0.58 28-OCT-98 MWD 5855.00 25.10 288.70 194.00 5438.60 1891.81 405.48 -1847.88 0.55 0.41 0.88 28-OCT-98 MWD 6042.00 25.70 289.60 187.00 5607.52 1971.51 431.80 -1923.64 0.38 0.32 0.48 29-OCT-98 MWD 6140.00 26.20 289.60 98.00 5695.64 2014.08 446.19 -1964.04 0.51 0.51 0.00 29-OCT-98 MWD 6616.00 27.20 288.00 476.00 6120.88 2226.74 515.06 -2166.51 0.26 0.21 -0.34 30-OCT-98 MWD 6811.00 27.50 285.80 195.00 6294.09 2316.07 541.09 -2252.21 0.54 0.15 -1.13 Last Survey in 8 1/2" Hole 30-OCT-98 MWD 6858.00 27.60 285.80 47.00 6335.76 2337.78 547.01 -2273.13 0.21 0.21 0.00 NO SURVEY - Projection to Bott . · su32 9.txt ORIGINAL R~CEIVED MARATHON Oil Company Pad 43-9 SU32-9 slot ~SU32-9 Sterling Gas Field Kenai Peninsula, Alaska Page 1 su32 9.txt SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <0-6858> Our ref : svy5874 License : Date printed : 10-Feb-99 Date created : 28-Oct-98 Last revised : 3-Nov-98 Field is centred on n60 31 54.076,w151 1 34.674 Structure is centred on n60 31 54.076,w151 1 34.674 Slot location is n60 32 16.842,w151 1 43.653 Slot Grid coordinates are N 2390021.729, E 314741.273 Slot local coordinates are 2311.80 N 449.18 W Page 2 su32 9. txt Projection type: alaska- Zone 4, Spheroid: Clarke- 1866 Reference North is True North MARATHON Oil Company SURVEY LISTING Page 1 Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Your ref : PMSS <0-6858 Last revised : 3-Nov-98 Page 3 su32 9.txt ,- Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Dogleg Deg/100ft Vert Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 225.00 1.00 2.79 224.99 1.96 N 0.10 E 0.44 0.34 353.00 1.31 0.98 352.96 4.54 N 0.17 E 0.24 0.83 442.00 1.34 355.62 441.94 6.59 N 0.11 E 0.14 1.34 532 . 00 1 . 37 350 . 04 531.91 8.70 N 0.15 W 0.15 2.06 621.00 1.60 347.97 620.88 10.97 N 0.60 W 0.27 2.99 711.00 1.71 342.73 710.85 13.48 N 1.26 W 0.21 4.19 800.00 1.80 343.06 799.80 16.08 N 2.06 W 0.10 5.55 890.00 1.93 344.49 889.76 18.90 N 2.88 W 0.15 6.96 985.00 2.38 323.50 984.69 22.02 N 4.48 W 0.95 9.21 1016.00 3.18 309.80 1015.65 23.09 N 5.52 W 3.34 10.47 1081.00 4.54 299.80 1080.51 25.52 N 9.14 W 2.33 14.53 1176.00 5.77 295.22 1175.12 29.43 N 16.72 W 1.36 22.79 1206.00 5.97 296.98 1204.96 30.78 N 19.48 W 0.90 25.77 1272.00 6.98 296.96 1270.54 34.15 N 26.11 W 1.53 32.98 Page 4 su32 9.txt 1358.00 1464.00 1560.00 1655.00 1749.00 1830.00 1941.00 2061.00 2227.00 2324.00 2420.00 2516.00 2612.00 2708.00 2804.00 2996.00 8.80 10.00 11.90 14.00 17.89 20.38 23.60 24.35 26.00 27.50 28.30 28.60 28.80 28.90 29.00 29.20 292.30 291.80 288.36 282.83 278.89 278.74 276.43 276.08 279.90 276.30 278.80 276.90 279.10 276.00 277.50 277.00 1355.72 1460.30 1554.55 1647.13 1737.50 1814.02 1916.93 2026.58 2176.81 2263.44 2348.28 2432.69 2516.90 2600.99 2684.99 2852.76 39.02 N 45.51 N 51.73 N 57.36 N 62.12 N 66.19 N 71.62 N 76.93 N 86.81 N 92.92 N 98.83 N 105.08 N 111.49 N 117.58 N 123.04 N 134.82 N Page 5 36.85 W 52.90 W 70.04 W 90.54 W 115.90 W 142.14 W 183.33 W 231.80 W 301.68 W 344.89 W 389.41 W 434.71 W 480.36 W 526.27 W 572.41 W 665.04 W 2.24 1.13 2.09 2.56 4.29 3.07 3.00 0.64 1.39 2.28 1.48 0.99 1.12 1.56 0.76 0.16 44.54 61.62 79.70 100.94 126.73 153.22 194.60 243.05 313.39 356.89 401.62 447.18 493.12 539.24 585.45 678.40 3188.00 3375.00 3473.00 3657.00 3847.00 3943.00 4038.00 4134.00 4323.00 4420.00 4516.00 4609.00 4706.00 4801.00 4897.00 4992.00 5087.00 28.50 28.70 29.20 25.30 25.80 24.00 24.40 23.70 24.10 24.50 23.60 24.00 24.30 24.10 23.70 23.70 23.70 278.00 280.20 277.40 279.20 277.50 280.30 280.60 282.50 283.60 283.70 285.00 285.20 285.40 287.40 287.90 285.90 287.00 3020.93 3185.11 3270.87 3434.42 3605.84 3692.92 3779.57 3867.24 4040.03 4128.44 4216.10 4301.19 4389.70 4476.36 4564.13 4651.11 4738.10 su32 9. txt 146.91 N 161.07 N 168.31 N 180.38 N 192.27 N 198.49 N 205.55 N 213.38 N 230.67 N 240.09 N 249.78 N 259.56 N 270.03 N 281.02 N 292.81 N 303.91 N 314.72 N Page 6 756.89 W 845.26 W 892.13 W 975.48 W 1056.55 W 1096.48 W 1134.78 W 1173.10 W 1247.69 W 1286.48 W 1324.38 W 1360.62 W 1398.90 W 1436.25 W 1473.31 W 1509.84 W 1546.46 W 0.44 0.57 1.47 2.17 0.47 2.24 0.44 1.09 0.32 0.41 1.09 0.44 0.32 0.89 0.47 0.85 0.47 770.66 859.99 907.30 991.27 1072.97 1113.28 1152.19 1191.30 1267.87 1307.78 1346.89 1384.38 1424.03 1462.89 1501.64 1539.71 1577.82 su32 9.txt 5279.00 24.30 286.20 4913.50 337.03 N 1621.30 W 0.36 1655.73 5471.00 23.80 285.90 5088.84 358.66 N 1696.50 W 0.27 1733.84 Ail data is in feet unless otherwise stated. level) . Coordinates from slot ~SU32-9 and TVD from Estimated RKB (265.00 Ft above mean sea Bottom hole distance is 2338.04 on azimuth 283.53 degrees from wellhead. Vertical section is from wellhead on azimuth 282.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company SURVEY LISTING Page 2 Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Your ref : PMSS <0-6858 Last revised : 3-Nov-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Dogleg Vert Deg/100ft Sect 5661.00 24.30 287.00 5262.34 380.60 N 1770.76 W 0.35 1811.10 Page 7 su32 9.txt 5855.00 25.10 288.70 5438.59 405.46 N 1847.91 W 0.55 1891.83 6042.00 25.70 289.60 5607.52 431.78 N 1923.67 W 0.38 1971.53 6140 . 00 26 . 20 289 . 60 5695 . 64 446.16 N 1964.07 W 0.51 2014.11 6616.00 27.20 288.00 6120.88 515.03 N 2166.53 W 0.26 2226.76 6811.00 27.50 285.80 6294.09 6858.00 27.60 285.80 6335.76 - NO SURVEY 541.06 N 546.98 N 2252.24 W 0.54 2316.10 2273.16 W 0.21 2337.80 Projection to TD Page 8 s%~32 9.txt Ail data is in feet unless otherwise stated. level) . Coordinates from slot #SU32-9 and TVD from Estimated RKB (265.00 Ft above mean sea Bottom hole distance is 2338.04 on azimuth 283.53 degrees from wellhead. Page 9 su32 9.txt -- Vertical section is from wellhead on azimuth 282.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company SURVEY LISTING Page 3 Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Your ref : PMSS <0-6858 Last revised : 3-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 6858.00 6335.76 546.98 N 2273.16 W Projection to TD - NO SURVEY Casing positions in string 'A' Page 10 sing Top MD Top TVD su32 9.txt Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Ca 3/8" CSG 5/8" CSG 0.00 0.00 0.00 0.00 0.00N 0.00N 0.00E 92.00 92.00 0.33N 0.00E 2110.00 2071.13 79.30N 0.02E 252.05W 13 Target name Revised Targets associated with this wellpath Geographic Location T .V.D. Rectangular Coordinates Strlng B4 Rvsd 16-0c -May-97 5245.00 394.20N 1747.82W 20 Page 11 Alask~.~-,qegion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 1. 1998 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Sterling Gas Field 1) SU 32-9 Dipole Shear Sonic Gamma Ray. Caliper Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30. 1998 Reproducible Prints 1 1 2) SU 32-9 Comb. Mag. Resonance Tool Gamma Ray, Caliper **Platform Express** Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30, 1998 3) SU 32-9 Array Induction Gamma Ray, Caliper **Platform Express** Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30. 1998 1 1 1 1 4) SU 32-9 Phasor Induction Gamma Ray Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30, 1998 1 1 5) SU 32-9 Array Induction. Density Neutron, Gamma Ray, Caliper **Platform Express** Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30, 1998 1 1 Please sign and return confirming you have received thesedocuments MARATHON OIL COMPANY Kirsten K. Gamel Received By' Enclosures Date: DEC 0£ 1998 A!asl~a 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alask~ ,~_-.gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 2. 1998 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Sterling Gas Field ~g'Oq '2-- -- 1) SU 32-9 Dipole Shear Sonic Gamma Ray, Caliper Sterling Gas Field/Marathon Oil Company, Kenai Alaska October 30. 1998 Reproducible Prints 1 1 Please sign and return confirming you have received these doeument~. MARATHON OIL COMPANY ~.~..~,-,- 0,,- ~998 Kirsten K. Gamel Enclosures'Date :~~ ~~Ch~u~ A subsidiary of USX Corporation Environmentally aware for the long mn. STATE OF ALASKA ALASka.. OIL AND GAS CONSERVATION COMM~---~,ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILE~ GAsE~ SUSPENDEDE~ ABANDONED[~ SERVICEE~ 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 98-42 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20485 4. Location of Well at Surface -- ................. : ~ 9. Unit or Lease Name At top of Producing Interval ~- .....~':" ~ 10. Well Number 2695' FSL, 2227' FEL, Sec. 9, T5N, R10W, S.M. at 5679' MD ~"~" ' ' _~ SU 32-9 2859' FSL, 2722' FEL, Sec. 9, T5N, R10W, S.M. .~.,~.=.~.¢ ........... Sterling Unit 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. Sterling Pool 27.8' KB-GL '--I A-028063 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Complelions 10/18/98 10/30/98 11/9/98'1 N/A feet MS LI one 17. Total Depth (MD+'I-VD)6858, MD, 6336' 'I'VD 18. Plug Back Depth (MD+TVD)6820, MD, 6302' TVD 19. Directional Survey Yes, ,No[~ [~,, !20' Depth where SSSV setN/A feet MD [ 21. Thickness of PermafrostN/A 22. Type Electric or Other Logs Run PEX, AlT, DSI, DITE 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE iCEMENTING RECORD AMOUNT PULLED 13 3/8" 68~ K-55 0 80 Driven Driven N/A 9 5/8" 47# P-110 0 2111 12-1/4" 620 sks N/A 7" 29# L-80 0 6858 8-1/Z' 690 sks N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/Z', 9.3# 5909' 5630' & 5877' Steding B-4: 5679' - 86' MD, 5279' - 85' 'I'VD 6 spf, 2-1/2" hollow carrier guns 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST ,, Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A [ N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATERoBBL CHOKE SIZE IGAS-OIL RATIO I N/A TEST PERIOD ----~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~- 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 N:\drlg~sterlinCsu32-9~AOGCOMPL.XLW.xls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Steding B-4 5679' 5279' N/A Beluga 6041' 5607' N/A 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby cert~hal the foregoing is, lrue and correct to the best of my knowledge Signed L.....\ '~ ~~~,,~ Gary Eller Title Production Engineer Date 2/17/99 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg~steding~su32-9~,OGCOM PL.XLW,xls Sterling Field Well SU 32-9, Pad 43-9 Marathon Oil Co., Alaska Region API: 50-133-20485 KB-GL: 29.7 I' KB-TI-W: 30.00' 2312' FSL, 449' FEL Sec. 9, T5N, RIOW, S.M. Camco KBUG-LTS chemical injection mandrel w/1/4" injection line @ 998' _ Tubing: 3-1/2", 9.3//, N-80, EUE 8rd, AB-Mod. (11 jnts of 9.2//NU Butt., 660'- 992') Isolated Pertbrations Sterling B-4: 5679'- 86' A IT (6 spt; 60° phased) Electric line tagged PBTD (~ 6810' ELM (11/4/98) / "-% PBTD = 6820' TI) = 6858' 13-3/8", 68#, K-55 Drive Pipe ~ 80' 9-5/8", 47#, P-110, BTC Casing ~ 2111' Cmt w/620 sks of class G McMurry SMO-1 Gas Lift Mandrel @ 5521' (1" dummy valve installed 11/4/98) Halliburton PHL Rethevable Packer @ 5573' Halliburton XU sliding sleeve @ 5630' w/X-profile (ID = 2.813") Locator sub ~ 5877 Baker model F permanent packer @ 5877' w/I0' sealbore X Nipple @ 5896' (ID = 2.813") Wireline Re-Entry Guide @ 5909' 7", 29#, L-80, BTC casing @ 6858' Cmt w/690 sks of class G Last Rev: JGE, 11/16/98 Sterlinq Unit #32-9 17 Oct: Accepted rig @ 12:00 p.m. 10116198. Start N/U diverter and PJU top drive. 18 Oct: 19 Oct: Finish R/U top drive and stack. Test diverter, alarms, and accumulator. P/U 5" dp and HWDP f/drlg w/top drive. Start P/U BHA. Finished P/U BHA and RIH. Tagged @ 62'. Drlg 12-1/4" hole. Start building 2.5 degrees/100' @ 970'. Rotate. slide and surveys. - 20 Oct: Drlg wlMWD and mud motor. Circ and short trip. Circ hole clean. TOOH L/D BHA. 21 Oct: R/U to run csg. Ran 3 jts and tagged bridge @ 121', couldn't wash through. Pulled csg OOH and ran in to clean to bottom. Ran 49 jts 47#- Buttress csg. Washing to bottom. 22 Oct: Cmt 9-518 csg w/DS.-WOC-N/D stack and cut csg. Start welding on head. 23 Oct: Pressure test wellhead. Nipple up BOP. Testing BOPE. 24 Oct: Pressure test BOP. Pick up and stand back 141 jts drill pipe in derrick. Pick up BHA and TIH. PT casing. Drill out cement. 25 Oct: Drill cement. Run FIT test. Dump and clean mud tanks. Fill tanks and mix FLO PRO/KCL mud. 26 Oct: Mix mud and displace hole. Drill and survey 2125-2748'. Wiper trip to surface csg. Drill and survey 2748-3100'. 27 Oct: Drill and survey 3100' - 3513'. Trip for new BHA. Clean out to bottom. TOH to csg shoe and repair top drive. 28 Oct: Trip in hole. Drill and survey 3513' - 4944'. Wiper trip through new hole. Drill and survey to 5350'. 29 Oct: Drill and survey 5350' - 6162'. Circulate and trip for bit. 30 Oct: TIH. Drill and survey 6162-6858'. Circulate and condition hole for logs. 31 Oct: Circulate. Trip out. Log with Schlumberger. 1 Nov: Log with Schlumberger. Trip in hole and circulate for casing. TOH laying down DP. 2 Nov: Trip out of hole. Rig up and run 7" production casing. Circulate and cement casing. Sterlinq Unit #32-9 (Continue(i) 3 Nov: 4 Nov: 5 Nov: 6 Nov: 7 Nov: 8 Nov: 9 Nov: Cement 7" casing with 690 sx 'G' cement w/additives. Set csg slips, nipple down BOP, install tbg head, and nipple up BOP. Pressure test BOP. Pressure test BOP. Pick up 3-1/2" DP and TIH. Tag cement at 6659'. Drill cement to 6820'. PT csg to 3000 psi. Trip out of hole. Trip out, pick up 7" csg scraper and trip to bottom. Displace mud from hole with 3% KCL. Trip out, laying down DP and BHA. ? Set permanent packer on electric line. TIH with tubing. Perforate Sterling B-4 Sand. TIH with tubing. Set upper packer. Land tubing, ND BOPE, attempt to NU production tree. Prepare to skid rig. Prepare rig for skidding operation. Wait on tbg bonnet for 5M Christmas tree. Install new tbg bonnet and production tree. Pressure test to 5000 psi. Release rig for skidding operation. r - SURVEY CALCULATION AND FIELD WORKSIIEET Well N,illlc X NtJ, i'AI) 51.J4 ~ 9;5tJ32-9 Survey ~ccilull N,l{llc NIWI~ ............. .... 'l'al~c[ l~c~d/llUh~ll Target Coord E/W ~lo[ Coord E/W -449 ........... 18 NI,~}~ I)CCIIII,II/t~II 21 070 (',lkliJ..[~,.l ,%lctl~,.l .NII?,I.XII/NI la,get l),lcca,m ii{!'{ liu,ld'xWalkXDl, t,cr: 100t't[~ 3i)mil lOml] Vcrt. Sec. Azim. _ ~ ~ Magn I,, Map (?orr. '~! ~{~t{ NI.,i~,N,,itl, ,,, tlllll.R .............. SIIRVbY~ DATA ............. . . ......... NIWI) (J Iai I) 1)1) (1 iii) l) Or} {) Oil Il O0 I) ()11 lie IN iq)iN l ..... 180("1 q8 MWI) 223 I,) I I~l) 2 79 223 O0 224 99 0 34 196 l) 10 t~ l{ 0 4.1 ........ 18()("1 98 M~kl) 35~1~O I 31 tt98 12800 35290 083 4 54 ii 17 ii 21 02.1 18.O('i'98 NIVVI) 4.12 t~l} I .~.1 355 62 89 O0 411 94 I 34 659 ........... 18-O(71'.t)8 NIWI) 532 1)0 I 37 350 04 9000 531 91 206 870 ._ 18-f')(;l 98 MWI) b21 1;(1 I o1) 3-1797 89 (10 62~1 88 299 I0 97 111,o t) 2 / ii 2o .. .. 18 ()("i 9a M~Vl) 71i ()il i,71 342,73 9000 710 85 419 13,48 I 2t, 0 21 0,12 ............... 18-()(71' 9~ MWI) 8()l).O(I 1,80 343,06 8900 7')9 80 5.55 16,08 .2 i16 {) It) 11 t0 .... 18-f)('/' 98 MWI) 8911 IlO 1.93 344.49 90.1)0 889 70 6.96 18.90 -288 o 1> 01,l ...................... 19 I)(' I' 9~ MWI) 986.01} 238 323.50 96.00 985.69 9.24 22 06 -4 .19 I) 91 0.17 19-OC1'9S MWD 1016.00 3.18 309.80 30.00 1015.65 10.45 23.09 -5 50 3.15 267 ............................. 19 ()("1 98 MWI) lligl (l(I ,1.5,1 299.80 65.00 1080.51 14.51 25.52 -9.12 2 33 2.09 19-O(Yi'-98 MWi) 1170.o0 5.77 295.22 95.00 1175.12 2277 29.43 · 16.70 1.3o 1.29 -4.82 19..()(Y1'-98 MWI) 1206.00 5.97 296.98 30.00 120-196 25.75 30.78 -19.46 0.90 0.67 5.87 19-OC1'.98 MWI) 127200 6.98 296.96 66.00 1270.54 32.97 34.15 -26.09 1.53 1.53 -0.03 19-OC1'-98 MWI.) 1358110 8,80 292.30 86.00 135572 4452 39.02 -30.84 2 24 2 12 -5.,12 19 ()1'1' ~18 MWI) I lb{ I}O lOOI} 291,80 lOO.O0 1.1()0 3() 61 60 45.51 -52.88 i.13 1.13 0.17 ............. 19-OC1' 98 blWl) 15b0(}O 11.90 288.36 96.00 155.1 55 79 08 51.73 .7002 2 09 I 98 .358 ........... 19 OCi' 9~ MWI) 165500 14.00 282.83 95 O0 1647 13 li}O 93 57.36 -90.52 2 5~ 'i 2 21 -5.82 ... . . 19.OC1' 98 51WI~ 17-19 1}(} 17.89 278.89 94.00 1737 50 12o 71 62.12 -115.88 .i 2o 4 I-I 4.19 19-()("1' 9S MWI) 163ti.Or) 20.38 27874 81 O0 1814 02 153 20 66.19 -I-12 12 3 o7 3 07 -0 19 ........ 19.OC*1'.98 MWI) 19.11 O0 23.60 276.43 i 1100 1910 93 19458 71.61 -183.32 3 oO 290 -2.08 ....................... 19.()CI' 95 M~VI2 20ol ilo 2.1.35 276.08 120.00 2021, 58 243 03 76.92 -231.79 0 I)4 0 62 -029 l.a~i Su,c[) m 12 i' 1" Il,dc ................ 25 f)('l '~ MWI~ '2'2271111 26,1)1} 279 90 160,00 217~, 81 313 37 86.81 -301 67 I 39 0 99 2 30 , , , t ,, , ,,, , ,, , , ,,, ,,,,~ , ' - , , , , ' ' "" "'" 1SURVEY CALCULATION AND FIELD WORKSHEET j,,~,~,, ,,4.~.,~.!~3 's,,~,.t,.:l,.~ ~,, t ~,lt,i,.~,,.?~I~R.~I'II(~N ()Il. t'()MI'ANh 1~ ('~ml~a~l,~l & N~) N~,I~, .XK l~r41~H~ ~1~,~ l'~cl,l 511t~1 1~',~, t, '~'~ I Iii 1) Well Name k N~, PAl} bl143 9/5U32 9 So{roy Sccllt)ll NalllC blWl) Bill l<¢p I I)INN WEIA~ DATA ............ 'l'a~gct l)c,c~q,t~,,a 'l'arSct ('t)old [~/W 51t)l (]t)t)fd I?'W --~-~q ~ M.~g~ I),-,It~t.~,m 21 (,~ (',d, ul,,~,m Nlcth,,d NIININIIINI t'lil(V ....... sI~VEY DATA ' ' I ............................ 'l'>l)C ti'l) II)D) (DI)) (1:[) (11) (1'1) ().1~ r,: 1(~,1 l, I)r(lI) (-) I.cfl ( ) ...................... 25 (}('1' u~ ~IWI~ 2 ~2,1 ()1) 2750 276 30 97 00 2263 44 35o 87 92 92 -34.1 88 2 28 I 55 3 ...... 25.()('/ u8 MWI} 2.1211 ()() 25 30 278 80 9o.00 2348 28 401 60 98 83 ~5') 40 I ~ t) 83 2 . 25 t}('l 98 MWI) 251(, t)() 28 60 276 90 9600 2432 69 447 l0 105 08 l~.l 70 ~ ';') () )1 I 98 .... 25-()(71'95 hlWl.) 2o12 ()() 28.80 279 10 9000 2516 90 .193 10 I11 49 .lc() t.1 I I ' t) 21 2 2,) . _ 25-tj(,'1 98 MWI) 2'11)8t)1) 28 9() 276110 90 00 26H()99 539 22 117 58 .52;) 25 I ,~, () It) 3 2) 25OC1 98 MWI) 280.4.(/0 29(}0 277.50 9600 208-1 99 58544 123 04 5'i2 ~,; t~ /(, t) 11) I 5~, 26..{)Ci' 98 MWI} 9~, ' 29.20 2852 ,))o.00 277.00 192 00 76 678.39 134.82 -()o5 1t2 () It) 0 It) -0 20 ................................................ 26-.OCi'.98 MWI) 318600 28.50 278.00 190.00 3019.17 769.68 146.78 .755 91 t) 15 .037 0.53 .... 26 ()(Yi 98 MWI} 3375.00 28.70 28020 18900 31~5.12 859.96 161.09 -84523 t) 5'1 0 11 I 10 ............................................ 26-OC1'-98 MW1} 3473.00 29.20 277.40 98.00 3270.87 907.28 168.34 -892.10 I -17 051 -2.86 ....................................................................... 27-OC1'-98 NIWD 3657.00 25.30 279.20 184.00 3434.43 991.24 180.41 -975.15 2 17 -2.12 0.98 ....................................................................... 27-OCT-98 MWI) 3847.00 25.80 277.50 190.00 3605.85 1(172.94 192.30 -11)56.52 047 0.26 4).89 ............................................................................... 27.OC'i'-98 MWD 39.13.00 2400 280.3(} 96.00 369292 I I 13.26 198.51 -1096.45 2 2.1 -i 87 292 .................................................................. 274)C'1' 98 MWI) -I038 (}() 2,1,,10 280,60 95,0(} 3779,57 i152 17 205.58 -113,175 0.14 042 032 27,OC1 98 MWI} 413,1 (10 '23 70 282.50 96,00 3867,2.1 1191 28 213.40 -I 173117 1 09 0 73 I 98 27-OCI 98 blWI} 432300 2,1.10 283.60 189.00 40-10.(}-1 1207,85 230.70 -1247.66 032 0,21 0.58 27-OC1 98 N1WD 4420 00 24,50 283.70 97.00 4128.44 1307,76 240.12 -1286.45 0-11 0,41 0.10 27-OCT..98 MWi} 4516 00 23.60 285.00 9600 4216 11 1346 87 249.80 -1324.36 I 09 11 91 1.35 27-(}C1'-98 MWi) ,16o9 00 2,1(10 285,20 93.00 4301 20 1384,36 259.58 -1360.59 t) .1.1 () ,13 022 .......................... 27-O(Yl'-t)S MWI) ,1700.00 2-1.30 285.40 97.00 4389 71 1424.01 270.05 -1398.87 (} 32 () 31 0,21 ........ 27..()('1' 98 MWI) 480t 0() 2-1.10 287.40 95.00 4476 36 1.162.86 281.05 -1.130 22 1) 89 0 21 211 28.()("1 98 MWI} .1897.00 23.20 28290 96.00 450413 1501 61 292.84 -I-173.28 t) 47 -0.42 0.52 ................................ ) .... 28.(}("1.98 NIWI.) 4992.00 23.70 285.90 95.00 4651.12 1539.69 303.94 -1509.82 0 85 0.00 -2.11 ........... ............................... 28.(}("1 98 MWD 5087.00 23.70 287.00 95.00 4738 11 1572.~9 314.75 -1546.44 () 47 0.00 1.16 'l'al~c~ l)u cc~lon 28-0151' 96 28 OCI 98 28OC'1'-98 28-OCT 98 28-OCT.98 29-OC1'-98 29-OC1'-98 30-OC'I'-98 30 {){~1' 98 SURVEY CALCULATION AND FIELD WORKSHEET (',,ltq,.:u., M-\R.-\ I'II{)N ()11· t't)NII'.-\NY l,~l~.' k'~,)lltl.icl,'~l ,.k Nt) ..... Well N;,uw & Nt,. I'AIJStJ43 9/51132.9 SUlVcy ~CClIoll Naln¢ II WEI.L DATA 'l'argc[ Cot;rd. E/W Slot Cuord E/W -449 18 Bu,ldX',,¥all, xDL per: 100ft[~{ 3U.,[ I lU,nI I Vcn. ::;cc. ^z,m. 28!:~_! . III I I iii 0-151.01483 Nl.ig~ l).'cllnalion 21.0711 Magn t,) Mai) (?orr. 21 070 'Sidetrack No IL,m: ~ ,,I t'icld blt:l<l l;',l, {,'~:', I 11'1 1~ BIll Rep I I)IiNN 1~ .".IAI '~1 \ 11, i.,1:, NI,'.~ ,,i,.l l~ .... RI, Ii.'. .\INJ i , Nb: ('al,. tih~lz,ni Nlclh,,d ,\II.N IN11 i.M . M.t) Nt)l~l~ [~, tJllll. R l)cplh (ill 527') 5.171 ()() 5661 01) 5255 011 O0-I 2 (J() 6140.011 6616.00 6811,0(1 6858.11l) il.lc l)ircclloll iDDi 286.20 285,90 287 O0 288· 70 289.60 289.60 98.00 288.00 476.00 190.00 194.00 187.00 l.cngth TV 1) 192.00 4913.51 192 I)0 5098 84 526235 __ . 5438.00 5607.52 ._. 5695 04 612088 285.80 285.80 .- 195.00 6294.09 47,00 6335 76 SURVEY DATA 'l',~lal ('t n)fdlll.llc \"el lt~. dl (iq) iFF) 1655,70 337115 -1621 27 1733.82 358 69 -1696 47 181108 380.62 -1770 73 189181 405.48 -1817 88 1971.51 431.80 -1923 64 2014.08 446.19 -1904 fbi 2226.74 515.06 -2166,51 2316.07 541.09 -2252.21 2337,78 547.01 2273,13 lhl:ld Raic Build ( -*- ) I')mp 1-) .. . (J 31 () 26 0 26 {) 41 t) 32 0 51 0.21 · 0.15 11.21 ... V,',lll, Right ( I.cl't 0 42 0 16 0 58 0 88 11 48 0 -{).34 , -1.13 t) , ( i.a~,( Survey iii 8 1/2" It,dc N() SIJRVi:Y l'i~).l,:,.tt~ul [~) It, al TONY KNOWLE$, GOVEi~NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 14, 1998 W. C. Barren Operations Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re~ Sterling Unit SU 32-9 Marathon Oil Company Permit No: 98-42 Sur. Loc. 2312'FSL. 449'FEL, Sec. 9, T5N. R10W. SM Btmhole Loc. 2804'FSL. 263 I'FEL. Sec. 9, T5N, R1 OW, SM Dcar Mr. Barren: Enclosed is thc approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not attthorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipmcnt (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximatcly 24 hours) of the BOPE test performed before drilling below the surface casing shoe must bc givcn so that a representative of the Commission ma,,' witness the test. Notice may. be given bx'. contacting the Commission at 279-1433. Chairman~'~ BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section w/o cncl. Departmcnt of Environmcntal Consetwation w/o cncl. g:\cmn\ddg~sterling\su32-9\AOGCCPTD.XLW STATE OF ALASKA ALA~ ., OIL AND GAS CONSERVATION COMM._.$1ON PERMIT TO DRILL 210 AAC 25.005 la. Type of Work Drillr~ Re-DrillF-1 lb. Type of well. Exploratory[~ Stratigraphic Test[--1 Development Oil[~] Re-Entry[~ Deepen[~ Servicer-~ Development Gas~-~ Single Zone[~ Multiple Zone[-"~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 265' KB (est) feet Sterling Unit 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 A-028063 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 231ZFSL, 449'FEL, Sec. 9, TSN, R10W, S.M. Stealing Unit Blanket Surety At top of Productive Interval 8. Well Number Number 2706'FSL, 2197'FEL, Sec. 9, TSN, R10W, S.M. SU 32-9 5194234 At Total Depth 9. Approximate Spud Date Amount 2804'FSL, 2631'FEL, Sec. 9, T5N, R10W, S.M. 8/1/98 $200000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Line 3083 feet 1700 feet 1520 6663' MD, 6170' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure _~ (~ee 20 AAC 25.035 (e) (2)) Kickoff Depth 1000 feet Maximum Hole Angle 25.7 * Maximum Surface. 2178 ?cig at Total Depth (TVD) 18. Casing Program Setting Depth-~ Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD 'F'VD MD TVD (including stage data) Driven 13-3/8" 68~ K-55 P E 80-100 0 0 80-100 80-100 12 1/4" 9 5/8" 47# P-110 BTC 2100 0 0 2100 2059 675 sacks 8 1/2" 7" 29~ L-80 BTC 6663 0 0 6663 6170 590 sacks 20. Attachments Filing FeeL~J Property Plat~.J BOP SketchL~ Diverter SketohL~.J Drilling ProgramL~J Drilling Fluid Program~] Time vs Depth Plot[-"] Refraction Analys,sl-'-] Seabed Report[~ 20 A~C 25.050 Requ,rements[~ 21. I hereby certiht that the foregoing is true and correct to the best of my know~edge Commission Use Only Permit Number lAP, Number IApprova' Date Isee Cover Letter ~X.,.~/2.' 50_//,.,~,.....,~0 ~/~=,..~. ?...-/,Z/~"...~'~ iForOther Requirements Conditions of Approval Samples Required [~Yes '~No Mud Log Required F"~Yes [~No Hydrogen Sulfide Measures J--]Yes ~]No Directional Survey Required J~Yes ['"--]No Required Working Pressure for BOPE ~'12M ~13M ["-~5M [--110M [~15M Other: Original Signe(~ David W. Johnston by order of Approved by Commissioner the Commission Date Form 10-401 Rev. 12-1-85 Submit in Triplicate Alaska I~'bgion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 26, 1998 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Sterling Unit 32-9 Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, W. C. Barron Operations Superintendent PKB/nrs G:\CMI',~DR LG\STER LING\SU32-9~AOGCCLTR Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: SU 32-9 FIELD: PAD: 43-9 AFE No.' SLOT: NA TYPE: REVISION NO.: 0 Steding Gas Field 1503597 Development. Sterling B-4 Producer DATE: 2/24/98 SURFACE LOCATION: 2312' FSL, 449' FEL, Sec. 9, T5N, R10W, S.M. TARGETS: B-4 sand 2706' FSL, 2197' FEL, Sec. 9, T5N, R19W, S.M. BOTTOMHOLE LOCATION: 2804' FSL, 2631' FEL, Sec. 9, T5N, R19W, S.M. KB ELEVATION' GL ELEVATION' 265 ft. mean S.L. (est.) 235 fl. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS' FORMATION DEPTH (MD) DEPTH(TVD) Potable water is generally encountered between surface and 500 ft. Steding B4 5636 5245 Beluga 59-4 6474 6000 I1. ESTIMATED FORMATION TOPS AND CONTENT: POTENTIAL FORMATION DEPTH(MD) DEPTH(TVD) CONTENT Sterling B-4 5636 5245 gas/water (1900psig) Beluga 59-4 6474 6000 water TD 6663 6170 page 1 g:\cmn\ddg~erlinCsu32-9\PROG.XLS III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 13 5/8" X 5000 psi annular preventer and a 10"(minimum) O.D. vent line. The vent line valves will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 100' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) equipped with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer outfitted with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 13-5/8" weld on starting flange. CASING HEAD: CASING HEAD: 13-5/8" - 3000 psi x 9-5/8" SOW with base plate for 13 3/8". TUBING HEAD: 11"-3000 psi top x13 5/8" - 3000 psi bottom. CHRISTMAS TREE: 3 1/8" - 3000 psi christmas tree including two master valves, one flow tee, one wing valve and one swab valve. NOTE: Heads and tree may be upgraded to 5000 psi depending on cost, availability and the desire to standardize. page 2 g:\cmn\drlg~steding~su32-9\PROG.XLS IV. CASING PROGRAM: TYPE SIZE CONDUCTOR: 13-3/8" SURFACE: 9 5~8" PRODUCTION: 7" CASING DESCRIPTION SET VV'I'. GRADE THREAD FROM 68 ppf K-55 Surf 47 ppf P-110 BTC Surf 29 ppf L-80 BTC Surf SET HOLE TO(md/tvd) SIZE 80-100/80-10 Driven 2100/2059 12 1/4" 6663/6170 8 1/2" CASING DESIGN SIZE WEIGHT GRADE 9 5/8" 47 ppf 7" 29 ppf P-110 L-80 SETTING FRAC GRD FORM PRSS DESIGN FACTORS DEPTH,'I-VD @ SHOE (~ SHOE MASP TENS COLL BURST 2059' 12.0 964 1155 18.09 3.40 8.28 6170' 2888 2178 4.57 6.19 3.96 page 3 g:\cmn\ddg~steding~su32-9\PROG.XLS V. CEMENTING PROGRAM SURFACE: 9 5/8" @ 2100/2059 LEAD SLURRY ' Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 13.3 ppg. 1.8 cu. ft./sk gal/sk hrs:min 50 % 425 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 1600 fl. 15.8 ppg. 1.17 cu. ft./sk gal/sk hrs:min 50 % 250 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1.Remove thread protectors and visually inspect connections. 2.Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3.M/U float collar. (Baker-lok all connections to top of float collar) 4.Fill pipe until circulating. 5.Run remairling casing. M/U cementing head, install bottom plug and test all lines. 6.Circulate and reciprocate until no gain in circulating efficiency is made. 7.With as little shut down as possible, drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: 20 BBLS of weighted CW 100 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. N/D diverter. Set slips. N/U casing head and blowout preventers. 15. Test BOPE. Run wear bushing. page 4 g:\cmn\ddg~steding~su32-9\PROG.XLS V. CEMENTING PROGRAM (continued) PRODUCTION 7" @ 6663/6170 LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 2100 ft. 13.3 ppg. 1.80 cu. ft./sk gal/sk hrs:min 50 %(use 25% over caliper log.) 325 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 5000 ft. 15.8 ppg. 1.17 cu. fl./sk gal/sk hrs:min 50 %(use 25% over caliper log.) 265 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1.Remove thread protectors and visually inspect connections. 2.Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3.M/U float c~)llar. (Baker-lok all connections to top of float collar) 4.Fill pipe until circulating. 5.Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6.Circulate and reciprocate until no gains in circulating efficiency is made. 7.With as little shut down as possible, drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: 20 bbls weighted CW 100 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 15. Test BOPE. page 5 g:\cmn\drlg~sterling~su32-9\PROG.XLS VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO 'I-VD ppg sec/qt LOSS TYPE 0' 1000' 8.6-9 80-250 15-30 Freshwater spud 1000' 2100' 9.0-9.5 42-80 <12 Non-dispersed 2100' 6663' 9.6-10.0 50-70 <8 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of shale shakers and a 2-cone desander. Included will be equipment to dewater the underflow from the mud processing equipment to allow disposal of the cuttings and solids by slurfification and injection into disposal well at KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: RUN #1: Possibly run AIT/DSI. PRODUCTION: RUN #1: AIT/DSI/LDT/CNL. RUN #2: Possibly run MRIL(CMR). COMPLETION: A cement bond Iog(CET/GR) will be run pdor to completion. MUD LOGGING The well will be mud logged from 2100' md(casing point) to TD at 6663' md. CORING PROGRAM None planned. TESTING PROGRAM No open hole tests are planned for this well. page 6 g:\cmn\drlg~steding~su32-9\PROGoXLS VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS Anticipated bottomhole pressures in the Sterling sands is 1900 psi.(7 ppg EMW) Lost returns are possible in the depleted Steding interval. Hydrogen sulfide gas has not been encountered in any well in the Sterling field IX. OTHER INFORMATION DIRECTIONAL PLAN NORTH DESC MD 'I'VD INCL AZIM COORD WEST COORD VERT SECTION RKB 0 0 0 0 0 KICKOFF 1000 1000 0.0 282.7 0 build @ 2.5 deg/100fl HOLD 2028 1994 25.7 282.7 50 tangent section of 25.7 deg B-4 SAND 5636 5245 25.7 282.7 394 0 221 1748 0 227 1792 Total Depth 6663 6170 25.7 282.7 492 2182 2237 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) SU 43-9 88 1700 page 7 g:\cmn\ddg~steding~su32-9\PROG.XLS X, DRILLING PROGRAM CONDUCTOR: Drive 13 3/8" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and dg up rotary drilling rig. Nipple up 13 5/8" diverter, diverter valves, and 10" diveder line. Function test diverter and diverter valves. SURFACE: Ddll a 12 1/4" hole to 2100' md per the directional plan. Run and cement 9 5/8" casing. WOC. Cutoff 13 3/8" and 9 5/8". Weld on 9 5/8" SOW by 13 5/8" 5M wellhead. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. PRODUCTION: Drill float equipment and 10' of new formation w/8 1/2" bit. Run shoe test. Do not exceed 12.0 ppg equivalent mud weight. Drill a 8 1/2" hole from 2100' to TD per the directional program. Log. Pull wear bushing. Run and cement 7" casing. WOC. P/U BOP's. Set slips, cut casing, install tubing head and test to 3000 psi. N/U 13-5/8 x 5M B©PE. Test BOPE and choke manifold to 250 psi/3000 psi. Test Production casing to 3000 psi. COMPLETION: Completion procedure to follow. page 8 g:\cmn\ddg~sterling~su32-9\PROG.XLS g:~cm n~ rlg~sterling~su32.9~,OGCCl:rT'D.XLW Maximum Anticipated Surface Pressure Sterling Unit SU 32-9 Surface Casinq: 9 5/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (12.0 ppg + 1.0 ppg) x .052 x 2059' - (. 115 x 2059') MASP = 1392 - 237 MASP = 1155 PSI. Production Casing: 7" MASP = Formation pressure - Hydrostatic pressure of gas column. "- MASP = 9.0 ppg x .052 x 6170' - (.115 x 6170') ? MASP =_2888- 710 , ,/ MASP = 2178 PSI. NOTE: All casing in this design is new. MARATHON Oil Companyi I ~53 ~ I Structure : Pea 45-9 Well : 5USZ-9 Field : Sterling Gas Fiela Location : Kenai Peninsula, Aloskol 'i :CO 4 <- West (feet) ';'23 '350 g00 750 600 450 300 ~50 C 150 i i i i ! i I ! i i I i i i [ 2450 --,-- ¢'~ 2800 -- 0_ > 3500 I--- 3850 V 4200 Estimated SuMoce Location: 2312' FSL, 449' FEL Sec. g, TSN. RIOW, SM WELL PROFILE DATA + ,<Op ~o5o 4 i 2.50 I i 5.00 7.50 400 1 1750 1 2!CC 4 OLS: 2.50 :7 50 20.00 22.50 ..... oo,,,,i ..... 600 45O A I Z o h 300 ~50 ? .=~ 0 L 150 MO !nc D~r ~ North East V Sect Oe~/tOO 0.00 O.O~ 282.71 0.00 0 O0 0 ~ O.OO 0.~ 10~.~ 0.~ 282.71 1 ~0.~ 0 O0 0.~ 0.00 0.~ 202~20 25_70 2~2.71 ~9g~.05 4g g0 -221.24 226.80 2.~ 5636-20 25.70 282.71 5245.00 J94.20 -1747 82 1791.72 0.00 6662 7g 25 70 282 71 6170_00 492 16 -218,2 18 2236 gg O.00 · 900 ~ r~G 5250 4 ~6oo 4 \ 5950 q~l ~,~ Cteotec~ Oy jones For: P IBergaj Oote oIotted · 22-Feb--9~ [ Plot Reference is SU32-g Version ~6. C~rdinotes ore in f~t reference slot ~SU52-9. ~ T~e V~ical ~pt~~e Estimate~ RK8. 6300 fl 550 C 350 700 1CS0 ;400 ~750 -2100 2450 Verticol Section (feet) -> Azimuth 282.71 with reference O.00 N, 0.00 E /'rom slot #SU32-g MARATHON 0il Co~any Pad 43-9 SU32-9 slot #SU32-9 Sterling Gas Field Kena£ Peninsula, Alask& PROPOSAL LISTING Baker Hughes INTEQ Your ref , SU32-9 Version #6 Our faf : prop2395 Date printed = 22-Febo98 D&te created : 28oAug-97 Last revised = 22-Feb-98 Field is centred on n60 31 54.076,w151 1 34.674 Structure is centred on n60 31 54.076,w151 1 34.674 Slot location is n60 32 16.842,w151 i 43.653 Slot Grid coordinates ars N 2390021.729, E 314741.273 Slot local coordinates are 2311.80 N 449.18 W Projection type, alaska - Zone 4, Spheroid= Clarke o 1866 Re~erence North is True North MARATHON Oil Coz=pa~y Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A Depth Degrees Degrees Depth C 0 0 R D I N A T E PROPOSAL LISTING Page 1 Your ref : SU32o9 Version #6 Last revised : 22-Feb-98 R Dogleg Vert S Deg/100ft Sect 0.00 0.00 282.71 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 282.71 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 282.71 1000.00 0.00 N 0.00 E 0.00 0.00 KOP 1100.00 2.50 282.71 1099.97 0.48 N 2.13 W 2.50 2.18 1200.00 5.00 282.71 1199.75 1.92 N 8.51 W 2.50 8.72 1300.00 7.50 282.71 1299.14 4.31 N 19.13 W 2.50 19.61 1400.00 10.00 282.71 1397.97 7.66 N 33.96 W 2.50 3%.82 1500.00 12.50 282.71 1496.04 11.95 N 52.99 W 2.50 54.93 1600.00 15.00 282.71 1593.17 17.18 N 76.18 W 2.50 78.09 1700.00 17.50 282.71 1689.17 23.34 N 10].47 W 2.50 106.07 1800.00 20.00 282.71 1783.85 30.41 N 134.83 W 2.50 138.21 1900.00 22.50 282.71 1877.05 38.38 N 170.18 W 2.50 174.46 2000.00 25.00 282.71 1968.57 47.2% N 209.47 W 2.50 214.73 2028.20 25.70 282.71 1994.05 49.90 N 221.24 W 2.50 226.80 EOC 2500.00 25.70 282.71 2419.16 94.92 N 420.87 W 0.00 431.4% 3000.00 25.70 282.71 2869.68 142.64 N 332.%2 W 0.00 648.31 3500.00 25.70 282.71 3320.20 190.35 N 843.98 W 0.00 865.18 4000.00 25.70 282.71 3770.72 238.06 N 1055.53 W 0.00 1082.04 4500.00 25.70 282.71 4221.24 285.78 N 1267.09 W 0.00 1298.91 5000.00 25.70 282.71 4671.76 33].49 N 1478.64 W 0.00 1515.78 5500.00 25.70 282.71 5122.28 381.20 N 1690.19 W 0.00 1732.65 5636.20 25.70 282.71 52%5.00 39%.20 N 1747.82 W 0.00 1791.72 Strlng B% Rvsd 16-Oct-97 6000.00 25.70 282.71 5572.80 %28.92 N 1901.75 W 0.00 1949.52 6500.00 25.70 282.71 6023.32 %76.63 N 211~.30 W 0.00 2166.39 6662.79 25.70 282.71 6170.00 492.16 N 2182.18 W 0.00 2236.99 TD All data is in feet unless otherwise stated. Coordinates from slot #SU32-9 and TVD from Estimated RKB (265.00 Ft above mean sea level). Bottom hole distance is 2236.99 on azimuth 282.71 degrees from wellhead. Total Dogleg for wellpath is 25.70 degrees. Vertical section is from wellhead on azimuth 282.71 degrees. Calculation uses the minimum curva=ure method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your re~ : SU32-9 Version #6 Last revised : 22-Feb-98 Comments in wellpath MI) TVD Rectangular Coords. Cc~men~ 1000.00 1000.00 0.00 N 0.00 E KOP 2028.20 1994.05 49.90 N 221.24 W EOC 5636.20 5245.00 394.20 N 1747.82 W Strlng B4 Rvsd 16-Oct-97 6662.79 6170.00 492.16 N 2182.18 W TD Targets associated with this wellpath. Target name Geographic Loc&~ion T.V.D. Rectangular Coordinates Revised Strlng B% Rvsd 16-Oc 5245.00 394.20N 1747.82W 2fl-Mayo97 M2tP, AT~ON Oil Co=~oan¥ Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : SU32-9 Version #6 Last revised : 22-Feb-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 282.71 0.00 2311.80 N 449.18 W 0.00 0.00 500.00 0.00 282.71 500.00 2311.80 N 449.18 W 0.00 0.00 1000.00 0.00 282.71 1000.00 2311.80 N 449.18 W 0.00 0.00 KOP 1100.00 2.50 282.71 1099.97 2312.28 N 451.31 W 2.50 2.18 1200.00 5.00 282.71 1199.75 2313.72 N 457.69 W 2.50 8.72 1300.00 7.50 282.71 1299.14 2316.11 N 468.31 W 2.50 19.61 1400.00 10.00 282.71 1397.97 2319.46 N 483.14 W 2.50 34.82 1500.00 12.50 282.71 1496.04 2323.75 N 502.17 W 2.50 54.33 1600.00 15.00 282.71 1593.17 2328.98 N 525.36 W 2.50 78.09 1700.00 17.50 282.71 1689.17 2335.14 N 552.65 W 2.50 106.07 1800.00 20.00 282.71 1783.85 2342.21 N 584.01 W 2.50 138.21 1900.00 22.50 282.71 1877.05 2350.18 N 619.36 W 2.50 174.46 2000.00 25.00 282.71 1968.57 2359.04 N 658.65 W 2.50 214.73 2028.20 25.70 282.71 1994.05 2361.70 N 670.%2 W 2.50 226.80 EOC 2500.00 25.70 282.71 2419.16 2406.72 N 870.05 W 0.00 431.44 3000.00 25.70 282.71 2869.68 2454.44 N 1081.60 W 0.00 648.31 3500.00 25.70 282.71 3320.20 2502.15 N 1293.16 W 0.00 865.18 4000.00 25.70 282.71 3770.72 2549.86 N 1504.71 W 0.00 1082.04 4500.00 25.70 282.71 4221.24 2597.58 N 1716.27 W 0.00 129S.91 5000.00 25.70 282.71 4671.76 2645.29 N 1927.82 W 0.00 1515.78 5500.00 25.70 282.71 5122.28 2693.00 N 2139.37 W 0.00 1732.65 5636.20 25.70 282.71 52%5.00 2706.00 N 2197.00 W 0.00 1791.72 Strlng B% Rvsd 16-Oct-97 6000.00 25.70 282.71 5572.80 27%0.72 N 2350.93 W 0.00 1949.52 6500.00 25.70 282.71 6023.32 2788.43 N 2562.%8 W 0.00 2166.39 6662.79 25.70 282.71 6170.00 2803.96 N 2631.36 W 0.00 2236.99 TD All data is in feet unless o~herwise stated. Coordinates from SE Corner of Sec. 9, TSN, R10W SM and TVD from Estimated RKB (265.00 Ft above mean sea level). Bottom hole dista~ce is 2236.99 on asim~t-h 282.71 degrees from wellhead. Total Dogleg for wellpath is 25.70 degrees. Vertical section is ~rom wellhead on azimuth 282.71 degrees. Calculation uses t, he m~nimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref : SU32-9 Version #6 Last revised : 22-Feb-98 Comments in wellpath MD ~ Rectangular Coords. Cogent 1000.00 1000.00 2311.80 N 449.18 W KOP 2028.20 1994.05 2361.70 N 670.42 W EOC 5636.20 5245.00 2706.00 N 2197.00 W Strlng B4 Rvsd 16-Oct-97 6662.79 6170.00 2803.96 N 2631.36 W TD Targets associated with this wellpath. Target name Geographic Location T.V.D. Rectangular Coordinates Revised Strlng B4 Rvsd 16-Oc 5245.00 2706.00N 2197.00W 20-May-97 MARATHON Oil COml~any Pad 43-9,SU32-9 Sterling Gas Field,Kenai Peninsula, Alaska Measured Inclin Azimuth Tz-ue Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : SU32-9 Version Last revised : 22-Feb-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 0.00 0.00 282.71 0.00 0.00N 0.00E 0.00 0.00 314741.27 2390021.73 500.00 0.00 282.71 500.00 0.00N 0.00E 0.00 0.00 314741.27 2390021.73 1000.00 0.00 282.71 1000.00 0.00N 0.00E 0.00 0.00 314741.27 2390021.73 1100.00 2.50 282.71 1099.97 0.48N 2.13W 2.50 2.18 314739.15 2390022.2% 1200.00 5.00 282.71 1199.75 1.92N 8.51W 2.50 8.72 314732.80 2390023.78 2.50 19.61 314722.22 2390026.3% 1300.00 7.50 282.71 1299.14 4.31~ 19.13W 2.50 34.82 314707.43 2390029.92 1400.00 10.00 282.71 1397.97 7.66N 33.96W 1500.00 11.50 282.71 1496.04 ~1.95N 52.99W 2.50 54.33- 314688.48 2390034.51 1600.00 15.00 282.71 1593.17 17.18N 76.18W 2.50 78.09 314665.38 2390040.09 1700.00 17.50 282.71 1689.17 23.34N 103.47W 2.50 106.07 314638.18 2390046.68 1800.00 20.00 282.71 1783.85 30.41N 134.83W 2.50 138.21 314606.94 2390054.23 1900.00 22.50 282.71 1877.05 38.38N 170.18W 2.50 174.46 314571.72 2390062.76 2.50 214.73 31%532.58 2390072.23 2000.00 25.00 282.71 1968.57 47.24N 209.47W 49.90N 221.24W 2.50 226.80 314520.85 2390075.07 2028.20 25.70 282.71 1994.05 0.00 431.44 314321.96 2390123.20 2500.00 25.70 282.71 2419.16 94.92N 420.87W 0.00 648.31 314111.19 2390174.20 3000.00 25.70 282.71 2869.68 142.64N 632.42W 0.00 865.18 313900.42 2390225.20 3500.00 25.70 282.71 3320.20 Lg0.35N 843.98W 4000.00 25.70 282.71 3770.72 238.06N 1055.53W 0.00 1082.04 313689.65 2390276.21 4500.00 25.70 282.71 4221.24 285.78N 1267.09W 0.00 1298.91 313478.88 2390327.21 1478.64W 0.00 1515.78 313268.10 2390378.21 5000.00 25.70 282.71 4671.76 333.49N 5500.00 25.70 282.71 5122.28 381.20N 1690.19W 0.00 1732.65 313057.33 2390429.22 5636.20 25.70 282.71 52%5.00 ]94.20N 1747.82W 0.00 1791.72 312999.92 2390443.11 6000.00 25.70 282.71 5572.80 428.92N 1901.75W 0.00 1949.52 312846.56 2390%80.22 6500.00 25.70 282.71 6023.32 476.63N 2113.30W 0.00 2166.39 312635.79 2390531.23 6662.79 25.70 282.71 6170.00 492.16N 2182.18W 0.00 2236.99 312567.17 2390547.83 All data in feet unless otherwise stated. Calculation uses m/nimum cuz-vature method. Coordinates from slot #SU32-9 and TVD from Estimated RKB (265.00 Ft above mean sea level). Bottom hole distance is 2236.99 on azimuth 282.71 degrees from wellhead. Total Dogleg for wellpath is 25.70 degrees. Vertical section is from wellhead on azimuth 282.71 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Bake= Hughes INTEQ MARATHON Oil Company Pad 43-9,SU32-9 Sterling Gas Field,Kemai Peninsula, Alaska PROPOSAL LISTING Page 2 Your fez : SU32-9 Version #6 Last revised : 22-Feb-98 Comments in wellpath mmmmgtmmmmB~mmm~mm~ MD TVD Rectangular Coords. 1000.00 1000.00 0.00N 0.00E KOP 2028.20 1994.05 49.90N 221.24W EOC 5636.20 5245.00 394.20N ~747.82W Strlng B4 Rved 16-Oct-97 6662.79 6170.00 492.16N 2182.18w TD Targets associated with this wellDath. mmmmmmmmmmmmmmmmmmmmmmmmmm mmmmmm mm mmm Target name Geographic Location T.V.D. Rectangular Coordinates Revised Strlng B% Rvsd 16-Oc 52%5.00 39%.20N 1747.82W 20-May-97 SURFA~CE USE PLAN FOR STERLING SU-32-9 Surface Location: NEll4 of $El/4, Sec. 9, T5N, R10W, S.M. 1. Existing Roads Existing roads which will be used for access to Sterling Unit SU 32-9 are shown on the attached map. Soldotna, Alaska is the nearest town to the site and is also shown on the map. 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access SU 32-9. 3. Location of Existing Wells Well SU 32-9 will be drilled on pad 43-9. One well, SU 43-9, already exists on the pad and one additional well (SU 41-15) will be drilled. 4. Location of Existing and/or Proposed Facilities 1 The locations of existing production facilities in the Sterling Unit are shown on the attached drawing. The pad (43-9) will be expanded to accommodate the drilling rig as shown in the drawing. · Location of Water Supply No water well exists on pad 43-9 at this time. A dedicated water supply well will be drilled to provide water for the water-based mud. 1 Construction Materials The pad, 43-9 will be expanded to accommodate the drilling rig. The sand and gravel will be obtained from the approved gravel pit in the SW/4, NE/4, Sec. 5, T6N, R10W, S.M. Other materials will be obtained from various vendors and suppliers in Alaska. 7. Methods 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 of the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No. 9, Permit ¢f.81-176). G:\CMN~RLG~STERUNG~SU32-9~URFUSE Surface Use Plan Sterling Unit SU 32-9 Page 2 1 1 10. 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 WE #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor which provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four railer house type structures will be r~quired for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADEC approved disposal facility. No airstrip or additional structures will be necessary. Wellsite Layout The wellsite layout will be determined after construction of the drilling pad. Plans for Reclamation of the Surface Sterling Unit SU 32-9 will be drilled from an existing pad, which will be expanded to accommodate the drilling program. Reclamation of the pad will occur after the abandonment of SU 32-9 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. G:\C~RLG~STERLING~SU32-9~SURFUSE Surface Use Plan Sterling Unit SU 32-9 Page 3 11, 12. 13, Surface Ownership The surface owner of the land in the Sterling Unit is the U.S. Fish and Wildlife Service. The minerals are under the jurisdiction of the U.S. Bureau of Land Management. Other Vehicle parking areas, as well as other areas where equipment will be set up and operating will be lined with an impervious liner to prevent spills. 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 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: Nanle & Title: ~~ ~-/~- t..,, Marathon Oil ~ompany P. O. Box 196168 ~chorage, Alaska 99519~168 (907) 561-5311 G:\CNIN~RLG~STERUNG',SU32-g~SURFUSE DIVERTER SCHEMATIC STERLING UNIT 32-9 MARATHON OIL COMPANY J . 13-5/8" x 5M Annular Preventer Dive. er Sl~ool 13 3/8" CONDUCTOR 13 5/8' ~M HYDRILL ANNULAR PREV£NI'£R FL(:;. BOP STACK ELEVATION 13-,5/8" 5.000N SHAFFER EXHIBIT A SECTION I PROPOSED BOP STACK CONFIGURATION ktAIERIAL LIS[ ,,. II[U ,; -I- -- EXHIBIT A SECTION I CHOKE MANIFOLD DESIGN FI. AR[ FLAR£ T 39'-9 1/8' ELECTRIC ' (8'-0' X 2 o- ×?____~o x~3 74'--i 7/8~ END OF TUBULARS THIS IS A PROPRIETOR'/ 2525 C S:r~:. SA := 22'3 N~cf'x~cqe. A~csko 99503 RIG 160 RSB NTS GENERAL ARRANGMENT CHECKED OCT 97, 16CX)IO3AI ~,s_: of SP RES. B4 A A' Tyonek Coal - -5,000' - -10,000' 33 34 35 361 T6N - TIOW 6 5 4 3 2 1 Promsed B4 ~ "- Co~on 7] SU 32-9 i 11 12 ~I 18 1"~~i~/ 14 ,,. 13i,1! ' 22 23 24 T5N. R10W ~ 30 29 28 27 26 25 ,/ 31 32 33 34 35 36 C.I.-20' 0 1/2 1 I I I MILE ANCHORAGE HM4912 MARATHON OIL COMPANY ALASKAN PRODUCTION REGION STERLING GAS FIELD KENAI, ALASKA SU 32-9 /99~ DEVELOPMENT WELL February 1998 /]l'~ , / / / / /// / / / DRAI~fl BY RAR CHECKED BY SAM HORZ. SC, N.~I'. 'v~RT. SCAL~ N/A DRY, NO. 973165 SHEET C1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 THE APPLICATION OF MARATHON ) OIL COMPANY for an order granting ) an exception to spacing requirements of ) 20 AAC 25.055(a)(4) to provide for the ) drilling of the Sterling Unit 41-15 and ) Sterling Unit 32-9 gas development wells ) within the Sterling Unit, east of the city of ) Kenai. ) Conservation Order No. 426 Marathon Oil Company Sterling Unit Wells 41-15 and 32-9 May 20, 1998 IT APPEARING THAT: . Marathon Oil Company submitted applications dated April 23, 1998 and April 24. 1998 requesting exception to the xvell spacing provisions of 20 AAC 25.055(a)(4). The first exception would allow drilling the Sterling Unit 41-15 gas development well to a producing location closer than 1500 feet to a section line in an undefined gas pool. The second would allow drilling the Sterling Unit 32-9 gas development well to a producing location that is closer than 3000 feet from another well capable of producing from the same pool. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on May 2. 1998 pursuant to 20 AAC 25.540. 3. No protests to the application xvere received. FINDINGS: The Sterling Unit 41-15 gas development well will be drilled as a deviated hole from a surface location of 2327' from the south line (FSL) and 437' from the east line (FEL) of Section 9. T5N, R10W, Seward Meridian (SM) to a bottomhole location 4208' FSL and 1049' FEL of Section 15, T5N, R10W, SM. The Sterling Unit 32-9 gas development well will be drilled as a deviated hole from a surface location of 2312' FSL and 449' FEL of Section 9, T5N. R 1 OW, SM to a producing location of 2706' FSL and 2197' FEL of Section 9, T5N, R10W. SM. 2. Offset owners Bureau of Land Mangement, U.S. Minerals Management Service, Cook Inlet Region. Inc and the State of Alaska have been duly notified. 3. An exception to the ~vell spacing provisions of 20 AAC 25.055 (a)(4) is necessary, to allow the drilling of these ~vells. Conservation Order No. 426 May 20, 1998 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the Sterling Unit 41-15 and the Sterling Unit 32-9 gas ;yells will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: Marathon Oil Company's applications for exception to the well spacing provisions of 20 AAC 25.055 (a)(4) for the purpose of drilling the Sterling Unit 41-15 and the Sterling Unit 32-9 gas xvells are approved. DONE at Anchorage. Alaska and dated Mav 20, 1998. Rol~e~t N ~'357~er~s~n C~m~nissio Alaska Oil and Gas Conservation Commission Cammy Oechs0~ 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 bv it may lile with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23~ day ~bllowing the date of the order, or next working day ifa 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 I O-day period. ,,Ln affected person has 30 days from the date the Commission refuses the application or mails I or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied bv 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 dav after the application Ibr rehearina was filed). 2-26-98 OPERATOR ;100.00 CITY STATE P.O. Box 196168 ANCHORAGE ALASKA 99519-6168 NON-REPORTING 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF NON-EMPLOYEE COMP. PAYMENT PRIZES, AWARDS, OR DAMAGES Check Request ANC 2/26/98 A (nrs) Filing Fee for Permit to Drill - Sterling Unit SU 32-9 oo ~' : suo p,~nJ]SUllS]UaU~ u~o3 :NOISSIIAIIAIO0 'E)NI~::I:INIE)N3 .... N A / ............ 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