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191-064
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC M-30 TRADING BAY UNIT M-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 M-30 50-733-20430-00-00 191-064-0 W SPT 8764 1910640 2191 0 0 0 0 130 130 130 130 4YRTST P Adam Earl 3/9/2024 MIT-IA Well injection is intermittent, going to zero when pump is off and up to 200psi when on. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:TRADING BAY UNIT M-30 Inspection Date: Tubing OA Packer Depth 800 2390 2385 2385IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240313163237 BBL Pumped:2.9 BBL Returned:2.9 Thursday, April 11, 2024 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, January 27, 2020 P.I. Supervisor `-7�i 2�4 4� SUBJECT: Mechanical Integrity Tests r { Hilcom Alaska LLC M-30 FROM: Austin McLeod TRADING BAY UNIT M-30 Petroleum Inspector Sre: Inspector Reviewed By: P.I. SuprvL NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT M-30 Insp Num: mitSAM200127072530 Rel Insp Num: Well M-30 Type PTD 1910640 ' Type BBL Pumped: 3.6 " Interval 4YRTST Notes: MIT -IA _ API Well Number 50-733-20430-00-00 Inspector Name: Austin McLeod Permit Number: 191-064-0 Inspection Date: 1/24/2020 - Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min w - ITVD 8764 Tubing 2290 2.190 1,190- 2190 SPT Test psi 2191 IA 850 X870 - 2865 2815 -I Returned: 3.7 - OA 133 135 135 135 P/F P If Monday, January 27, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 05,2016 TO: Jim Regg 1114 14 I1( P.I.Supervisor t SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC M-30 FROM: Lou Grimaldi TRADING BAY UNIT M-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT M-30 API Well Number 50-733-20430-00-00 Inspector Name: Lou Grimaldi Permit Number: 191-064-0 Inspection Date: 1/2/2016 Insp Num: mitLG160104152246 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' M-30 Type Inj W'ITVD 8764 Tubing 2880 - 2861 • 2860- 2860 PTD 1910640 Type Test SPT Test psi 2191 IA 850 2340 - 2340 ' 2340 Interval 4YRTST P/F P ,i OA 122 122 122- 122 - Notes: Good solid test.All required documentation supplied prior to test. 444awtVte1 1) i�u I7nzsswes 4'(4* z) Ce-t( SCANztAk'4 3) Tes-r Pmsc‘we sage C�•1t,42;-- ;, l'poi+ SCA�NEa JUL 2 7 2Q15 Tuesday,January 05,2016 Page 1 of 1 • • o o c o Cr- p In C 1 --Ii11 +'Y e-,4 O 11 1 .I..4D 0 CD V CJ —4 t J I:, _... 1 t 11/!IL , s 0 � v 2- i g,� in 1-'9—. _ - a .....k 1 4. r, I a �ry U 0 0 . en 0ci -�_ d. un I n u � to M o X m 111111.1 � 1 14 - a ak _ 1 0111111111111111111111111111111111111111111111111111r I 0 No1 Y7 ri CI IQ 1 1 1 1 1 11 1 1 I A 1 1 Q 1!] O CD If] O lin 0 Co) C,1 �J � 74.40' I F Y: 12,499,535' Prod Pkrs: B FAB @ 11,959` Baker SABL3 @11,990' /ell Status: SI B -1 @ 13,190' _ Operator: Chevron Ownership: Chevron/PE , . id. BHP: G:4162 psi Spud Date: 4/3/1992 1'� HK:4496 psi Other: WO 10/21/96 WF:4674 psi WO 10/12/07 Tbg CO.Added a pkr. ,----- ismisinsil BHT: 180° CASING&Tubing Rotate 1,039' Description Weight Grade Conn ID Length Top Btn1 TOG Hrs Drive Pipe 26 Weld 965' 80' 1,039' Driven 55.0 hrs 1,439' Conductor 16 " 75.0# K-55 BTC 15.124 1,365' 80' 1,439' Surf 78.0 hrs Surface 13 3/8" 61.0# K-55 BTC 12.515 2,297' 81' 2,371' 1,885'Est 393.5 hrs ILi 13 3/8" 68.04 12.415 1,853' 2,371' 4,224' 4,224' ®LI 9 5/8" 47.0# 4,086' 81' 4,167' • 11:1 ECP Buttress 2' 4,167' 4,169' Production 8.681 9 5/8" 47.0# L-80 2,140' 4,169' 6,309' 3,750'Est 200.0 hrs 95/8" 47.0# Mod BTC 858' 6,309' 7,167' 4)1 95/8" 53.5# BTC 8.535 5,080' 7,167' 12,247' Liner 7 " 29.0# N-80 TKC 6.184 2,620' 11,383' 14,003' 11,383'Est 52.5 hrs Liner 5 " 18.0# N-80 AB FLAS 4.276 755' 13,865' 14,620' 13,865'Est 35.0 hrs Scab 7 5/8" 39.0# P-110 FL-4S 6.63 151' 4,113' 4,264' NA NA Tubing 4 1/2" 12.6# L-80 Hydril 533 3.958 11,852' 74' 11,926' TK-69 Coated w/CB Rings 12,247' n' Jewelry Description Depth Length ID OD WH Tbg Hanger,TC-1A-EN,SS,16"w/CIW 4"type H BPV profile.4-%"CS top x Hyd 563 btm 74' 0.83' E 1 Baker CPH Liner Pkr,7-5/8"x 9-5/8" 4,113' 9.55' 6.625" 8.375" 1 . '.ii W 02 (3)Joints of 7-5/8",39#,P-110 w/FL-4S 4,123' 131.24' 6.625" 7.625" 3 Baker Hyflo 3D Liner Hngr Pkr,7-5/8"x 9-5/8" 4,254' 10.50' 6.625" 8.437" 4 K-22 Anchor Tubing Seal Assy 4.75"(Plastic Coated).(1.38'in pkr) 11,926' 0.71' 3.875" 5.500" ' II' 11 5 Baker 85SAB47 X 40 Prod.Pkr w/MOE w/XO to 4-'/"Butt. 11,926' 10.69' 4.000" 5.860" 10 •` `, . 6 "XN"Nipple 4 1/2"Butt Box X Pin W/3.75"Profile 11,947' 1.21' 3.813" 5.250" ( � �" 11 7 Baker K-22 Anchor Seal Assy W/O Latch Or Seals 11,958' 0.71' 3.875" 5.500" 12 8 Baker 85FAB-47 Ret Production Pkr w/MOE 11,959' 9.17' 4.000" 5.860" 13. 9 Otis X Nipple 11,977' 1.74' 3.813" 5.250" ' 10 Baker'K-22'Locator Seal Assembly w/o seals 11,989' 0.78' 3.875" 5.560" '-=,.14 11 Baker'SABL-3' Packer,85SAB47X40. 11,990' 4.49' 3.875" 5.875" ® :•, 12 Baker MOE,w/XO 5"LTC x 4-1/2"Butt 11,994' 6.53' 4.590" 5.000" 13 Baker'F'Nipple,3.75"profile. 12,033' 1.28' 3.750" 5.250" 14 Baker'F'Nipple,3.75"profile. 12,055' 1.27' 3.750" 5.250" - 15 Baker Hydrotrip Sub w/WLEG 12,066' 1.46' 3.937" 5.600" -•-- l* ',U 16 Baker'F-1'Packer,Size 85-40. 13,190' 3.950" • moo i' 17 Baker MOE w/XO 5"LTC P x 4-1/2"Butt 13,194' 4.590" 17 18 Baker'F'Nipple,3.68"profile. 13,235' 3.680" 118 119 Baker'R'Nipple,3.68" /3.625"w/WLEG 13,270' 3.625" Perforations = Zone I Top I Btm I Amt I Gun Size I SPF I Phase I Date = G-ZONE _ G-2 12,340' 12,360' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 66 4-1/2" 4 60 7/1/1992 G-3 12,518' 12,568' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 80 4-1/2" 4 60 7/1/1992 14,003' G-5 12,830' 12,859' 29 4-1/2" . 4 60 _ 7/1/1992 ' G-5 12,869' 12,932' 63 4-1/2" 4 60 7/1/1992 HEMLOCK - = HB-1 13,207' 13,227' 20 2-%" 6 60 9/11/2007 HB-1 13,229' 13,249' 20 2-%" 6 60 9/11/2007 _ HB-3 13,429' 13,499' 70 12/21-27/02 HB-3/413,460' 13,490' 30 12/21-27/02 I.' '. HB-4 , 13,520' 13,570' 50 12/21-27/02 13,599' 13,629' 30 12/21-27/02 14,620' HB-5 13,689' 13,709' 20 12/21-27/02 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND 0 it, .• if z/7U1ip amu. A-30 Pmilo�,4 ( -o ►► .. A-06-ac /af+ in.°16- LCA l(oOi 04151Z'lt EXHIBIT 9 UNOCAL OIL & GAS OPERATIONS - ALASKA ` PRESSURE GAUGE CALIBRATION REPORT Manufacturer (Prcvnen, l Tag Number Serial Number ly03 2 'Gott-03 -c02 ' Face_Diameter. 2.5" 4" . 6" 8" _ Rated Accuracy: 1.00% 0.50% 0.25% • Range: 0 to PSI Connection Type: Bottom Tapped . < Back Tapped, Connection Size: 1/4" NPT 3/8" NPT 1/2" NPT GAUGE RESPONSE RISING FALLING ACTUAL INDICATED ACTUAL INDICATED 0% O C9 100% VO C3c. S-ar3-0 25% I i 5'15 lZso 75% 3-75-6 _ 3-7,j-0 50% '2.5 06 -e5-05-0 50% Z JJ 2 Sc -C3 75% 115"0 3-15-0 25% /7,5"6 1Z 5 100% 5c - S60Q 0% a 5 COMMENTS: . TECHNICIAN: DATE: /8/3//1/4.S— 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. o, ve,, PAGES TO DELETE Complete RESCAN Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: D Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED . n · Logs 'of various kinds . Other COMMENTS: Scanned by: Bevedy Dian(~~athan Lowell n TO RE-SCAN Notes:- Re-Scanned bY: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, January 17, 2012 Jim ,�� P.I. Supervisor 'Q-11 ' SUBJECT: Mechanical Integrity Tests HILCORP ALASKA, LLC M -30 FROM: Bob Noble TRADING BAY UNIT M -30 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: TRADING BAY UNIT M -30 API Well Number: 50- 733 - 20430 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN120106082441 Permit Number: 191 -064 -0 Inspection Date: 1/4/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M -30 'Type Inj. W TVD 8764 ' IA 539 2353 - 2338 2332 - P.T.D 1910640 ' TypeTest SPT Test psi 2191 OA 88 88 88 88 Interval 4YRTST - P/F P Tubing 2429 2423 2426 2426 Notes: ,. D FEB I C tAl Tuesday, January 17, 2012 Page 1 of 1 • • Page 1 - )f 2 Regg, James B (DOA) From: Regg, James B (DOA) - 7134 - ?Y, Sent: Thursday, December 01, 2011 10:12 AM K l (l ii 19(064o To: Johnson, Chris W. � Cc: DOA AOGCC Prudhoe Bay Subject: RE: Steelhead M -30 MIT I approve the necessary extension so the Commission can witness both with a single trip to the platform. Thank you for working with us to do this. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 _' y ;+ , 1 r t ' r , 907 - 793 -1236 °° - ii From: Johnson, Chris W. [mailto:chris.johnson @chevron.com] Sent: Thursday, December 01, 2011 10:09 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Myers, Chris S; Lovett, Juanita L; Bartolowits, Paul D; Johnson, Wayne E; Chivers, Mike W; Martin, J. Hal; Greenstein, Larry P; Hauck, Shane R Subject: RE: Steelhead M -30 MIT • Mr. Regg, Drilling should be rigging off of M -21 tomorrow. So there next BOP test will be when they rig up on M- 28. My only concern is the MIT is due the 10 of December. We would be happy to work with you and complete them at the same time. Chris Johnson Lead Operator Steelhead Platform 907 - 776 -6830 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, December 01, 2011 9:45 AM To: Johnson, Chris W.; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Myers, Chris S; Lovett, Juanita L; Bartolowits, Paul D; Johnson, Wayne E; Chivers, Mike W; Martin, J. Hal; Greenstein, Larry P Subject: RE: Steelhead M -30 MIT Not sure if you are still doing rig work on the platform; if you are, this test will need to be done at a time when AOGCC can witness both the MIT and BOPE test. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 12/1/2011 Page 2 of 2 From: Johnson, Chris W. [mailto:chris.johnson @chevron.com] Sent: Thursday, December 01, 2011 7:33 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Myers, Chris S; Lovett, Juanita L; Bartolowits, Paul D; Johnson, Wayne E; Chivers, Mike W; Martin, J. Hal; Greens ein, Larry P Subject: Steelhead M -30 MIT Mr. Regg and Ms. Brooks, We are due for a MIT on our M -30 well. We would be able to do the test on Monday December 5 Pleas,: advise if this date works for you and I will set up helicopter times. Chris Johnson Lead Operator Steelhead Platform 907 - 776 -6830 12/1/2011 • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 i h Tel 907 263 7815 V - UNTIN `%\-060 Mobile 907 223 0128 Fax 907 263 7897 b _ksc %tO -0 O Email jzager @chevron.com \L— t ‘ bCs-0V- .' , �� � ( November 16, 2011 � � ad\ _ �� NOV 1 7 ? ^h ' UIC Manager �' � s I P,3S(Off Thor Cutler, OCE -082 ► .11CP rgi p U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 Seattle, WA 98101 .`$f N e ` `+ i Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I infection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 UIC Manager • US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivar alchevron.com or 263 -7685. Regards , John,1ager Enclosures: l US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • • OMB No. 2040 -0042 Approval Expires 12/31/2011 United States Environmental Protection Agency EPA Washington, DC 20460 Application To Transfer Permit Name and Address of Existing Pernittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat • 640 Acres N Surface Location Description i t 1 1 1 - 4 � —T Sc 114 of ne 114 of SW 114 of SW 1/4 of Section !� Township 8n Range 13w -- - I- 4 - -- 4 - I-. 4 - Locate well in two directions from nearest lines of quarter section and drilling unit 1 1 1 11 1 - -1 - -�- - i — --� —�-�— t Surface 4 y I-- 4 — -4--1-4-- I Location 754 ft. frm (NuS) S Line of quarter section I 1 1 1 1 1 and Ii 3E from (EJW) W Line of quarter section. i W I I 11 it ( Well Activity Well Status Type of Permit - . - -4-1-4-- K Class I �c Operatin —, Individual 1 I f- � T 1 1 1 1 Area _ — I - _ - r " T _ _Cl ii Modification/Conversion Lf J I x I , Brine Disposal K Proposed Number of Wells { — —1 ` — — - - 1 Enhanced Recovery i t 1 1 1 1 1 1 1 Hydrocarbon Storage S Class ill Other Lease Number Sec Attached Well Number See Attached Name(s) and Address(es) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John 'Lager, General Manager 11/15/2011 • EPA Form 7520-7 (Rev. 12 -08) , • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9RD L50 -733- 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50 -733- 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131. FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 1I006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 11006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. 1 Agreement to Transfer UIC Permit No. AK- 1I006 -A • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 11006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK -I I006 -A s • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263 -7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer UIC Permit No. AK- 1I006 -A • • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By: "Ala. A y• c Name: a ii Name: a i_,„ t N4tn'S Its: 4ii ', < s ct, Its: ki P Date: A/yc.'. 6 �� Date: t)%1 IS Zo Pt 5 Agreement to Transfer UIC Permit No. AK- 11006 -A Page 1 of 2 Maunder, Thw»as E {DOA) _. From: Maunder, Tfiomas E {DOA) ~01. ~ ~ ~o Sent: Monday, April 19, 2090 9:43 AM To: 'Greenstein, Larry P' Cc: Martin, J. Hal Subject: RE: SHP M-30 possible communication from tubing into 9 518" casing Larry and Hal, Thanks for the no " ~n and clui~ trouble-sfiootRng. One of your initial srr~nts con " "ng this as valid of the "~ a is Co invents tcz the for noting re i anct c,~etting the no _ and . To i is very impo " Tom Mau r, PE AOGOG From: Greenstein, Larry P [malto:GreensteinlpC+ron.can] Sent: Monday, April 19, 2010 9:03 AM To: Maur-, Thomas E (DOA) Cc: Martin, J. Hal Subject: RE: SHP M-30 possible canmunication from tubing into 9 5J8" casing Tom,. Canfirmed as a False Alarm. Looking at the pressure data over the weekend. the casing pressure has fatten back down to an historical Cevel. The increase was completely related to an elevated injection water temp and has nothing to do with a loss at mechanical integrity.. Larry From.: Greenstein, Zany P Sent; Friday, April 16, 2010 i:55 PM To: 'Thomas Maunder' Cc: Martin, J. Hal Subject: SHP M-30 possible c;ornmunication from tubing into 9 5/$" casing Tam,. ALL. INDICATiONC Af~E THAT THIS IS ~ FALSE ALARM.: fn preparing for the bleed down we had discussed, the field guys noted that the cooling water pump had been shut down a couple of days ago. This would increase the temperature on the injection water which would heat up the backside fluids. The annulus pressure would then climb, but not equalize with the tubing pressure -exactly wfiat vre are seeing. They nave restarted tt~e pumpt u~rhich coots the injection water some and tf~e annulus pressure is starting bacK down. We are not going to bleed aft any pressure, just monitor it fc see how much the c®oler injection wafer affects the annulus pressure.. We were hoping the pressure increase was just some thermal type event like vte see when we shut in the well (look at 3/2Q- 3/21 events. which it dust might grave to be. Tl~e fluids in the annular cclumn then warm up towards 4/19/2fl 10 Page 2 of 2 formation temperatures arid, with a completely fall arrrt~lr~s, can res~xlt ~€~ a pressr~re increase urtrelatec to ar~y type of integrity failure. t've attached the schematic and the 90 day TtQ plot for additional infarmatian.. Thanks. for the review,, Torn,; ar~d let us know if our plan forward meets your approval. If this is confirmed as a FALSE ALARM, iYs a perfecf example of a monitoring system and operating procedures performing as necessary to protect against any severe consequences.. Kudos to our field guys for getting the unexpected pressure readings out far proper notifications and responses and investigating for alternate explanations. Larry From: Chivers, Mike W Sent: Friday, April 1b, 2010 10:43 AM 70: Martin, J. Hal Ce: l3artolowits, Paul D; Lee, Sohn R; Holt, Chester; Greenstein, Larry P; Ahrcx-d, Jeremy E; Bo~cireaux, Eric P Johnson, Chris W, M~r~i, Jimmy D Subject: FW: M-30 9 SJ8" l-ial Looking like we rrtay have communication between the tubing string and the 9 5~8'~ 5ee comment below. ~1ot sure who is ~air~~ to be interested in this the mast but this is aur' fast rr~rtr-irxg ~nrater irr~ectar ar~d ~e wart't have anywhere to prat the sewage discharge. If `ae 1©se this well.. I~lease advise. Mike Chivers Steel head. From: Madrid, Jimmy D Sent; Friday, April lb, 2010 1:32 AM To: Chivers, Mike W Subject: M-30 9 5J8° Heads up, M-30 9 5/$" casing Dame up from 55th on the 13~'. To 1150# on the 14~'. Up to 1200# on the 15~'. 1 was able to confirm that it is indeed a pressure increase last night. JM 4I19IZQ10 ~~` _~~~ M-30 Pressure Observations 3500 3000 2500 2000 v 3 N a a` 1500 1000 500 Tubing 9 5/8" 13 3/8" - 16" - X20" 26" - Rate 14000 12000 10000 8000 v ~o z 6000 4000 • • 2000 04/04/10 04/06/10 04/08/10 04/10/10 04/12/10 04/14/10 04/16/10 04/18/10 04/20/10 Time 3000 ~ ~`_ O ~ ~ M-30 Pressure Observations 2500 2000 a 3 1500 v a 1000 500 - Tubing 9 5/8" 13 3/8" - 16" 20" - 26" Rate 14000 12000 10000 8000 v m 6000 4000 • 2000 0~ 0 01/02/10 01/12/10 01/22/10 02/01/10 02/11/10 02/21/10 Time 03/03/10 03/13/10 03/23/10 04/02/10 04/12/10 04/22/10 74.40' 1,039' 1,439' 4,224' 12,247' 14,003' 14,620' Steelhead Platform ~`` 9~ Field: Trading Bay API#: 50-773-20430-00 Leg: B-1 Well Classificaton: Injector Slot#: 9 Total Depth: 15,271' Surface Location: PBTD: 14,575' X: 214,138' Tubing: 4-%", 12.6#, L-80, IBT-M Y: 2,499,535' Prod Pkrs: Baker FAB @ 11,959'; Baker SABL3 @11,990' Well Status: SI Baker F-1 @ 13,190' Operator: Chevron Ownership: Chevron/PE BHP: G :4162 psi Spud Date: 4!3/1992 HK: 4496 psi Other: WO 10/21/96 WF: 4674 psi WO 10/12/07 Tbg CO. Added a pkr. BHT: 180° Description Weight Grade Conn ID Length Top Btm TOC Hrs Drive Pipe 26 Weld 965' 80' 1,039' Driven 55.0 hrs Conductor 16 75.0# K-55 BTC 15.124 1,365' 80' 1,439' Surf 78.0 hrs rf S 13 3/8" 61.0# K 55 BTC 12.515 2,297' 81' 2,371' 1 ass' Est 393 5 hrs u ace 13 3/8" 68.0# - 12.415 1,853' 2,371' 4,224' . 9 5/8" 47.0# 4,086' 81' 4,167' E CP Buttress 681 8 2' 4.167' 4.169' Production 9 5!8" 47.0# L-80 . 2,140' 4,169' 6.309' 3,750' Est 200.0 hrs 9 5/8" 47.0# Mod BTC 858' 6,309' 7,167' 9 5!8" 53.5# BTC 8.535 5,080' 7,167' 12,247' Liner 7 29.0# N-80 TKC 6.184 2,620' 11,383' 14,003' 11,383'Est 52.5 hrs Liner 5 18.0# N-80 AB FLAS 4.276 755' 13,865' 14,620' 13,865' Est 35.0 hrs Scab 7 5/8" 39.0# P-110 FL-4S 6.63 151' 4,113' 4,264' NA NA Tubin 9 41/2" 12.6# L-80 H dri1533 Y 3.958 11,852' 74' 11,926' TK-69 Coated wl CB Rings Description Depth Length ID OD Tbg Hanger, TC-IA-EN, SS, 16" w/CIW 4" type H BPV profle. 4-%" CS top x Hyd 563 btm 74' 0.83' Baker CPH Liner Pkr, 7-5/8" x 9-5/8" 4,113' 9.55' 6.625" 8.375" (3) Joints of 7-5/8", 39#, P-110 w/ FL-4S 4,123' 131.24' 6.625" 7.625" Baker Hytlo 3D Liner Hngr Pkr, 7-5/8" x 9-5/8" 4,254' 10.50' 6.625" 8.437" K-22 Anchor Tubing Seal Assy 4.75" (Plastic COated). (1.38' in pkr) 11,926' 0.71' 3.875" 5.500" Baker 85SA647 X 40 Prod. Pkr w/ MOE w/ XO to 4-% " Butt. 11,926' 10.69' 4.000" 5.860" "XN" Nipple 4 1/2" Butt Box X Pin W/ 3.75" Profile 11,947' 1.21' 3.813" 5.250" Baker K-22 Anchor Seal Assy W/O Latch Or Seals 11,958' 0.71' 3.875" 5.500" Baker 85FAB-47 Ret Production Pkr w/ MOE 11,959' 9.17' 4.000" 5.860" Otis X Nipple 11,977' 1.74' 3.813" 5.250" Baker'K-22' Locator Seal Assembly w/o seals 11,989' 0.78' 3.875" 5.560" Baker'SABL-3' Packer, 85SAB47X40. 11,990' 4.49' 3.875" 5.875" Baker MOE, w/ XO 5" LTC x 4-Y~' Butt 11,994' 6.53' 4.590" 5.000" Baker 'F' Nipple, 3.75" profile. 12,033' 1.28' 3.750" 5.250" Baker'F' Nipple, 3.75" profile. 12,055' 1.27' 3.750" 5.250" Baker Hydrotrip Sub w/WLEG 12,066' 1.46' 3.937" 5.600" Baker'F-1' Packer, Size 85-40. 13,190' 3.950" Baker MOE w/ XO 5" LTC P x 4-1 /2" Butt 13,194' 4.590" Baker'F' Nipple, 3.68" profile. 13,235' 3.680" Baker'R' Nipple, 3.68" / 3.625" w/ WLEG 13,270' 3.625" Zone Top Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12.360' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 66 4-1/2" 4 60 7/111992 G-3 12,518' 12,568' 50 4-1/2" 4 60 7/111992 G-4 12,596' 12,676' 80 4-1 /2" 4 60 7/111992 G-5 12,830' 12,859' 29 4-1/2" 4 60 7/111992 G-5 12,869' 12,932' 63 4-1 /2" 4 60 711/1992 HEMLOCK HB-1 13,207' 13,227' 20 2-%' 6 60 9/11/2007 HB-1 13,229' 13,249' 20 2-%' 6 60 9/11/2007 HB-3 13,429' 13,499' 70 12/21-27102 HB-3/4 13,460' 13,490' 30 12/21-27102 HB-4 13,520' 13,570' 50 12/21-27/02 13,599' 13,629' 30 12/21-27/02 HB-5 13,689' 13,709' 20 12/21-27/02 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND WF-1 13,941' 13,960' 19 2-7/8" 6 60 7/2/1992 WF-1 13.972' 14,042' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 65 2-7/8" 6 60 7/211992 WF-3 14,144' 14,206' 62 2-7/8" 6 60 7/211992 WF-4 14,244' 14,360' 116 2-718" 6 60 7/2/1992 WF-5 14,384' 14,430' 46 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 28 2-7/8" 6 60 7/2/1992 As completed on 10/12/07 Prepared By: Steve Tyler Chevron h~. January 3, 2008 To. AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 WELL ~ LGG TYPE SCALE i LOG DATE IfJTERVAL LOGGED ! RUiJ # 6- ~ ~ FIL;b1 i CD LINE ~NOTEJ- I LA,, PDS. f - - - L- ----- - -- COMPLETION --------- __ - RECORD 2 718" HSD POWER JET OMEGA 12890 - M-30 6 SPF 5" 10-Sep-07 13305 1 1 1 PDS COMPLETION RECORD 1.56" TUBING PUNCH 4 11850 - M-30 SPF 5" 11-Sep-07 12250 1 1 1 PDS Y~1-3~ • Francisco Castro Technical Assistant r~ LJ Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~~~~ JAN 4 ~ 200 ~ -5~s~~ ~~: Please acknowledge receipt by signing and returning one copy of this trans tai br~FAX to~3(~~-263 7828. j_, , Received By: Date: ~; MEMORANDUM To: Jim Regg ~} P.I. Supervisor ~~'-~~ i ~ ~~'' ~ ~ ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 26, 2007 SUBJECT: Mechanical Integrity Tests UNIO~i OIL CO OF CALIFORNIA M-30 TRADING BAY UNIT M-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.; Comm Well Name: TRADING BAY UNIT M-30 Insp Num: mitCS071219073637 Rel Insp Num: API Well Number: 50-733-20430-00-00 Permit Number: 191-064-0 Inspector Name: Chuck Scheve Inspection Date: 12/I 1;2007 Packer Depth ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' `a-'0 jType Inj. I W I, TVD ~ IA ~ 876 `~~ 590 zsoo ~~ 2soo ' z3oo ~ - ' ~ P.T. i~I~64o 'TypeTest ! sFr i Test psi ~` zl~I.zs OA o ; o ~ -._ o - ~ ~~I Interval wtucovR p~F P Tubing ~, z4so 24so _ z45o ~ z4so NOteS' Pre-test pressures observed and found stable. - - - -- ~~~ SAN ~' ~ 2p0~ Wednesday, December 26, 2007 Pale I of I • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, December 14, 2007 10:17 AM To: 'Greenstein, Larry P' Cc: Martin, J. Hal Subject: RE: TBU M-30 • Page 1 of 2 I~ -~~ ~~~ ~ i71~ -l1`'~'7 Larry -Thank you for looking into this and for the explanation. Please remind the platform personnel that they need to communicate delays such as what occurred here. I think we have been more than willing to work with them and typically give them the benefit of doubt. It's a whole lot easier to do that when we are notified. Regarding SVS, I was disappointed when I saw the test results. You've probably seen our letter. i certainly expected more from that platform after all the effort that was expended in addressing compliance following our enforcement action for failure to test Steelhead SVS. I appreciate how busy things were on the platform, but I think the timing of the inspector's visit was probably more representative of real life than the inspections that are scheduled around other activities. If ever there was a time for the SVS to be functional, it is when simultaneous ops are ongoing on the platform. I don't need to say anything else about this, because I know you understand. Please make sure the platform operating persannel also understand. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, December 13, 2007 4:40 PM To: Regg, James B (DOA) Cc: Martin, J. Hal (~,, Subject: RE: TBU M-30 ~ ~ 4` (' ©`~ ~ Jim, r~ Turns out there was some other stuff going on that may have resulted in the operators just not being ready to do the MIT while the inspector was out there. Still doesn`t justify not taking advantage of the inspector`s presence to get the MIT done, but might give you some basis for understanding. As you know, due to C-12 being down and same gas wells flowing at different pressures than normal. there were some set points on pilots that hadn't been adjusted to the new flowing conditions which resulted in an abnormally high number of 'failures' during the November SVS testing ~,vhich the inspector was on Steelhead to witness. This really bugged the operators and got them out of their comfort zone. The drilling of M-17 had started {now done) and the platform was a busy place. Probably budgeted time for the SVS work assuming it went well and were upset that it hadn't. Talked with the engineer and he too knows they knew to get the well retested, with the state inspector, 2-3 weeks after returning it to service. Can't offer too much more of an explanation; Jim. The engineer did remind them more than once about getting this MIT done at their earliest convenience. Maybe this early December window was the first breathing room they felt they had. I've included a record ofi the October pre-injection MIT. on the new MIT form, for your files. Thanks Jim. 12/14/2007 • Page 2 of 2 Larry From: Greenstein, Larry P Sent: Wednesday, December 12, 2007 7:10 AM To: 'Regg, James B (DOA)' Subject: RE: TBU M-30 I agree Jim. The platform was notified that the M-30 well needed an official witnessed MIT dens within acouple/ three weeks of restarting injeation after the workover. Don't knew why they 'weren't ready', nabody contacted me fram the platform. I'll get with the engineer here to see if there was something else going on and then get back with you to let you know what happened. Thanks Jim, Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 07, 2007 11:23 AM To: Greenstein, Larry P Subject: TBU M-30 North Slope office got a call from Steelhead platform this morning about scheduling an MIT for M-30. From monthly report you sent yesterday, it appears M-30 has been on continuous injection (12000+BWPD) since November 1 (well actually commenced injection in mid October for a few days then was shut in). Daily Ops summary attached to 10-404 dated October 30, 2007 indicates that the IA was MIT'd to 2200 psi on 10/23/2007, but we do not have report for that MIT. As I understand it, inspector inquired with Steelhead personnel about witnessing an MIT when out there for safety valve tests 11/15/2007 but was told they were not ready to test (needed to discuss with town first). Curious why the delay in getting an Inspector witnessed MIT set up for M-30; approved sundry 307-281 requires AOGCC witnessed MIT after temperature equilibrium which should have occurred shortly after injection commenced. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 12/14/2007 STATE OF ALASKA ~*~~ nn • ION ~~~~~4~ ALASKA OIL AND GAS CONSERVATION COM~ ~~ ~~ Il~j REPORT OF SUNDRY WELL OPERATIONSpCrN~V U ~ ~~~7 1. Operations Abandon Repair Well ~ Plug Perforations Stimulate - Performed: Alter Casing ^ Pull Tubing 0 Perforate New Pool ^ Waiver ^ Time Extensior~horage Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Union Oil Company of California Development ^ Exploratory^ 91-64 3. Address: PO BOX 190247 Stratigraphic^ Service^~ 6. API Number: Anchorage, AK 99519--0247 50-733-20430 7. KB Elevation (ft): 9. Well Name and Number: 160' KB above MSL M-30 8. Property Designation: 10. Field/Pool(s): Steelhead Platform ADL 17594 McArthur River "G" Zone / W. Foreland 11. Present Well Condition Summary: Total Depth measured 14,620' feet Plugs (measured) 14,575' Junk (me asured) true vertical 10,686' feet 7 ~t o/ NQV ~ ~ ~~~/ ' ~~'CC: ~~ . Effective Depth measured 14,575 feet :+ true vertical 10,649' feet Casing Length Size MD TVD Burst Collapse Structural 965 26 80 to 1039 80 to 1001 1346 NA Conductor 1365 16 80 to 1439 80 to 1357 2630 1020 Surface 4150 13 3/8" 81 to 4224 81 to 3361 3090 1540 Production 12173 9 5/8" 81 to 12247 81 to 9386 6870 4750 Scab Liner 151 7 5/8" 4113 to 4264 3282 to 3389 12620 11080 Liner 2620 7 11383 to 14003 8692 to 10831 8160 7030 Liner 755 5 13865 to 14620 10717 to 11341 10140 10490 Perforation depth: Measured depth: See Attached True Vertical depth: See Attached Tubing: (size, grade, and measured depth) 4.5 (Plastic Coated) L-80 11,926' Packers and SSSV (type and measured depth) 11,926' & 11,959' & 11,990' & 13,190' 12. Stimulation or cement squeeze summary: Intervals treated (measured): S Treatment descriptions including volumes used and final pressure: ~. ~iQ~ ~ % ~~p~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 BPD 0 psi 0 psi Subsequent to operation: 12,650 BPD 50 psi 2,435 psi 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: Oi1^ Gas ^ WAG ^ GINJ ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-281 Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager Signature ~ Phone 263-7657 Date 10/30/2007 Form 10-404 Revised 04/2006 U ~ t G ~ ~ A ~ ~ ~i~~ Submit igin~l C~ly, ttt `~~- 1 ~ / //~ • Perforation Detail • Zone MD Top MD Btm TVD Top TVD Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 9,460' 9,476' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 9,497' 9,551' 66 4-1/2" 4 60 7/1/1992 G-3 12,518' 12,568' 9,605' 9,646' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 9,669' 9,735' 80 4-1 /2" 4 60 7/1/1992 G-5 12,830' 12,859' 9,862' 9,886' 29 4-1/2" 4 60 7/1/1992 G-5 12,869' 12,932' 9,894' 9,946' 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-1 13,207' 13,227' 9,596' 9,610' 20 2 7/8" 6 60 9/11/2007 HB-1 13,229' 13,249' 9,611' 9,625' 20 2 7/8" 6 60 9/11/2007 HB-3 13,429' 13,499' 10,357' 10,414' 70 12/21-27/02 HB-3/4 13,460' 13,490' 10,382' 10,407' 30 12/21-27/02 HB-4 13,520' 13,570' 10,432' 10,473' 50 12/21-27/02 13,599' 13,629' 10,497' 10,522' 30 12/21-27/02 HB-5 13,689' 13,709' 10,571' 10,588' 20 12/21-27/02 HB-5/6 13,758' 13,818' 10,628' 10,678' 60 12/21-27/02 WEST FORELAND WF-1 13,941' 13,960' 10,780' 10,795' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 10,805' 10,863' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 10,887' 10,941' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 10,947' 10,998' 62 2-7/8" 6 60 7/211992 WF-4 14,244' 14,360' 11,030' 11,126' 116 2-7/8" 6 60 7/2/1992 WF-5 14,384' 14,430' 11,145' 11,183' 46 2-7/8" 6 60 7/211992 WF-6 14,490' 14,518' 11,233' 11,256' 28 2-7/8" 6 60 7/2/1992 • M-3° CURRENT Steelhead Platform Field: Tradin Ba API#: 50-773-20430-00 RIGINAL RIG ' LEVATIONS Le B-1 Well Classifcaton: ector In Slot: 9 Total Depth: 15,271' Surface Location: PBTD: 14,575' X: 274 138' 7ubin 4-'/=" 12.6# IBT-M L-80 74.40' T 1 ~ ~ ~ Y: , z,4sssas' Prod Pkrs: , , , Baker FAB 11,959`, Baker SABL3 11,990' ; Well Status: SI Baker F-1 13,190' O erator. Chevron Ownership: Chevron/PE BHP: G :4162 si Spud Date: 4/3/1992 HK: 4496 psi Other: WO 10/21/96 _ WF: 4674 psi WO 10/12!07 Tbg CO. Added a pkr. HT 1R0° - _ _- - : 1,039' Description Wei ht Grade Conn ID Len th To B[m TOC ..ie ~:.. Hn Drive Pipe 26 Weld 965' 80' 1,039' Driven 55.0 hrs 1,439' Conductor 16 75.0# K-55 BTC 15.124 1,365' 80' 1,439' Surf 78.0 hrs 13 3/8" 61.0# 12.515 2,297 81' 2,371' 1 s6s E t 3sas hrs Surface 13 3/8" 68.0# K-55 BTC 12.415 1,853' 2,371' 4,224' s 4,224' 95/8" 47.0# 4,086' 81' 4,167' ECP Buttress 2' 4,167' 4,169' Production p Fla" a7.nu L-80 8.681 2.140' 4.169' 6.309' 3,750' Est 200.0 hrs 12,247 !! r ~ + WF 8 1 2 ~~~ 3 li ~_ 4 t 1~J ~ _ 11 5 6 (~ 12 7 g I 9 i s ', ~ d', 10 11 15 ~ 12 1~ ~~ 14 15 -~ ~~ 16 16 17 18 18 _, ~ -. 19 Tubing 141/2" I 12.6# I L-80 IHydri1533I 3.958 111,852'I 74' I17,g26'IR^99 Coated wl CB -: w 14,003' _- 14,620' r'f Description Depth Len th ID OD Tbg Hanger, TC-IA-EN, SS, 16" w/CI W 4 type H BPV profile. 4-%" CS lop x Hyd 563 bt 74' 0.83' Baker CPH Liner Pkr, 7-5/8" x 9-5/8" 4,113' 9.55' 6.625" 8.375" 3 Joints of 7-518", 39#, P-110 w/ FL-4S 4,123' 131.24' 6.625" 7.625" Baker H o 3D Liner Hn r Pkr, 7-5/8" x 9-5/8" 4,254' 10.50' 6.625" 8.437" K-22 Anchor 7ubin Seal Ass 4.75" Plastic Coated . 1.38'.n Pkr 11,926' 0.71' 3.875" 5.500" Baker 85SAB47 X 40 Prod. Pkr w/ MOE w/ XO to 4-%" Butt. 11,926' 10.69' 4.000" 5.860" "XN" Nipple 4 1/2" Butt Box X Pin W/ 3.75" Profile 11,947' 1.21' 3.813" 5.250" Baker K-22 Anchor Seal Ass W/O Latch Or Seals 11,958' 0.71' 3.875" 5.500" Baker 85FAB-47 Ret Production Pkr w/ MOE 11,959' 9.17' 4.000" 5.860" Otis X Ni le 11,977' 1.74' 3.813" 5.250" Baker'K-22' Locator Seal Assembl w/o seals 11,989' 0.78' 3.875" 5.560" Baker'SABL-3' Packer, 85SAB47X40. 11,990' 4.49' 3.875" 5.875" Baker MOE, w/ XO 5" LTC x 4-'/=" Butt 11,994' 6.53' 4.590" 5.000" Baker'F' Nipple, 3.75" rofle. 12,033' 1.28' 3.750" 5.250" Baker'F' Ni le, 3.75" prof le. 12,055' 1.27' 3.750" 5.250" Baker H drotri Sub w! WLEG 12,066' 1.46' 3.937" 5.600" Baker'F-1' Packer, Size 85-40. 13,190' 3.950" Baker MOE w/ XO 5" LTC P x 4-1/2" Butt 13,194' 4.590" Baker'F' Nipple, 3.68" rofle. 13,235' 3.680" Baker'R' Ni le, 3.66" / 3.625" w/ WLEG 13,270' 3.625" P['I f~~r~tiGiis Zone Top Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 20 4-1/2" 4 60 711/1992 G-2L 12,386' 12,452' 66 4-1/2" 4 60 7/111992 G-3 12,518' 12,568' 50 4-1/2" 4 60 71111992 G-4 12,596' 12,676' 80 4-1/2" 4 60 7/1/1992 G-5 12,830' 12,859' 29 4-1 /2" 4 60 7/1/1992 G-5 12,869' 12,932' 63 4-1 /2" 4 60 7/1/1992 HEMLOCK HB-1 13,207' 13,227' 20 2-'/." 6 60 9/1112007 HB-1 13,229' 13,249' 20 2-%" 6 60 9/11/2007 HB-3 13,429' 13,499' 70 12121-27102 HB-3/4 13,460' 13,490' 30 12121-27/02 HB-4 13,520' 13,570' 50 12121-27/02 13,599' 13,629' 30 12/21-27102 HB-5 13,689' 13,709' 20 12121-27102 HB-5/6 13,758' 13,818' 60 12121-27/02 WEST FORELAND WF-1 13,941' 13,960' 19 2-7/8" 6 60 7/211992 WF-1 13,972' 14,042' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 62 2-7/8" 6 60 7/211992 WF-4 14,244' 74,360' 116 2-7/8" 6 60 71211992 WF-5 14,384' 14,430' 46 2-7/8" 6 60 71211992 WF-6 14,490' 14,518' 28 2-7/8" 6 60 7/211992 As completed on 10/12/07 Pre ared B Steve T ler _ __ __ g ~l"0~9 - weu Name M-30 --- _. __- Primary Job Type Replace Tubing -- _ Jobs_ _ PrimaryJob Type Replace Tubing ' Daily Operations Chevron -Alaska SWW Daily Operations Summary (Field Name API/UWI (Lease/Serial Orig KB Elev (ftK6) (Water Depth (f ~!MCARTHUR 507332043000 IADL0017594 160.0 _ __ _-- -- --- - ~- 'Primary Wellbore Affected ',Main Hole Job Category iAFE No. Obtechve Actual Start End Date OC Engineer ~Workover R7037 Workover to replace corroded tubing and restore 9/5/2007 tubular int~rit~ to Waterflood Injection Well No. M-30_ _ _ 9/5/2007 00:00 - 9/6/2007 00:00 - - - _ __ __ -- Operations Summary _- _ Mobe rig. 9/6/2007 00:00 - 9/7/2007 00:00 _ _ Operations Summary Rigging Up _ ~i 9/7/2007 00:00 - 9/8/2007 00:00 _ _ Operations Summary Rigging Up ~ 9/8/2007 00:00 - 9/9/2007 00:00 -' Operations Summary ', Rlgging Up - - _ - -- --- - -- 9/9/2007 00:00 - 9/10/2007 00:00 Operations Summary Rigging Up I, _ ___ - 9/10/2007 00:00 - 9/11/2007 00:00 ~ Operations Summary Rigging Up 9/11/2007 00:00 - 9/12/2007 00:00 _ __ _____ _ _ _ ___ __ __ Operations Summary ~ ~ ~i NU Schlumberger Lubricator for perforating HB-1. Perforate HB-1. RIH w/ 1.56" x 5' long tbg punch. Drop down and logged up noting jewelry, found top of 8' pup @ 11918' picked up and shot from 11903' to 11908'. Tubing punch fired @ 22:35 hrs. Contiung w/ rig mobilization. -- - - - - - 19/12/2007 00:00 - 9/13/2007 00:00 __ - _ _ _ _ _ ~~, iOperations Summary ND Schlumb Lubricator. Continue w/ Mobilizing rig. - - -- ---- - _ 9/13/2007 00:00 9/14/2007 00:00 _ _ _ _ _ ___; --- _ - - - __ _ --- iOperations Summary ~ Mobilizing Rig. 'i9/14/2007 00:00 9/15/2007 00:00 _ _ __ -- - _ _- - _ Operations Summary Continue w/ mobllizing rig and addressing issues _ ___ 9/15/2007 00:00 - 9/16/2007 00:00 __ _ __ __ _ - --- -_ Operations Summary j ~ Continue with Rig mobilization. _ - - _-- -- 9/16/2007 00:00 - 9/17/2007 00:00 _ _ _ _ _ __ _ __ ___ _ __ Operations Summary Build WO Brine to 9.3 ppg NaCI.. Displace wellbore w/ 410 bbls of brine. Build an additional 300 bbls volume. Install BPV. 9/17/2007 00:00 - 9/18/2007 00:00 _ _ _ _ _ __ _ Operations Summary Continue w/ BOPE NU. _ __ - - - - 9/18/2007 00:00 - 9/19/2007 00:00 _ _ __ _ _ _ _ _ _ ____i _ _ __ __ __ Operations Summary Working to test BOPE. Problems w/ annular control on Kommey unit. working to resolve same. _ 9/19/2007 00:00_-_9/20/2007 00:00 _~ Operations Summary Work on 4 way valve. Continue to get a test on annular. _ 9/20/2007 00:00 - 9/21/2007 00:00 Operations Summary PUMU Landing Joint. RU Eline. RIH w/ tbg cutter. Cut tbg @ 11 940'. POH. RIH w/ 2nd tbg cutter. Cut tbg @ 7008'. POH RD Eline. PU work tbg hngr out. Working pipe up to 170k. - - __.~ 19/21/2007 00:00 - 9/22/2007 00:00 ';Operations Summary i Pull pipe free w/ 240K. LD hngr. Circ well. POOH. Found 8" split @ jt# 114. Found badly swelled pipe @ 7008' (failed 2nd cut). Cont POOH. - - - _ __ - 9/22/2007 00:00 - 9/23/2007 00:00 Operations Summary Finished laying down tbg. PU Fishing BHA #1. RIH while picking-up 3-1/2" DP. Working BHA through 7-5/8" scab @ 4110'. ;,.. ~ Chevron -Alaska SWW Daily Operations Summary Well Name jFiField Name API/UWI -'Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) M-30 MCARTHUR 1507332043000 ~ADL0017594 160.0 !Daily Operations ~ 9/23/2007 00:00 - 9/24/2007 00:00 -------- Operations Summary RIH locate TOF @ 11,919'. Dress tbg stub. Swallow 9' of fish. Work drill string rotation down to "K" anchor. , -. - - - - - _ - - - -- 9/24/2007 00:00 - 9/25/2007 00:00 - -- ---- Operations Summary Worked DP rotating while firing jars in 10k incerments t/ 90 k over. Fired jars @ 65k over & work 20 rounds rotation. Anchor came loose. Losses went zero. POOH w/ tbg stub and anchor. Found collet missing on anchor (LIH). Conduct BOPE Test. 9/25/2007 00:00 - 9/26/2007 00:00 -_ ',Operations Summary I~ Fin. testing BOP'S. GIH w/ Mule shoe. Worked into Top packer assbly. Washed same. POOH. 9/26/2007 00:00 - 9/27/2007 00:00 -- - - _ _ __ _ - - -_ _ -- _- Operations Summary ~i POOH w/ mule shoe. UD same. M/U seal assy on DP. GIH. Set seal assy @ 11,397. Test annulus to 400#. Held OK. R/U S/L. GIH w/ bailer to 12.033'. No jar action. POOH. Jars swiveled-off from fishing neck. Left jars & Bailer in hole. RIH w/ Slickline conveyed overshot. Latch onto jars. Jar li on fish. - - -- _ -- _ 9/27/2007 00:00 - 9/28/2007 00:00 _ _ __ _ __ __ ___ - - -- --- Operations Summary ';Fished for stuck bailers at 12,033'. Latched on and jarred same free. POOH w/ fish. L/D fishing tools. GIH and bail from 12,046' to 12,048'. Retrieving 9/28/2007 00 00 19/29/2007 00 OOun.- -- ---- - _ -- - - _ - _ _ - - _,I Operations Summary Cont. bailing with 2" bailers until no recovery. GIH w/ starbit and various tools attempting to work through junk. No success. - __ - , 9/29/2007 00:00 - 9/30/2007 00:00 - - - Operations Summary 'i Work on junk @ 12,043' w/ 1-3/4" blind box on Slickline. No progress. R/D S/L. POOH w/ Seal Assy. PUMU 3.7" mill, 2-7/8" Motor and 3-1/8" DC's. GIH. Cut drlg. line. Service rig. _ 9/30/2007 00:00 - 10/1 /2007 00:00 _ - - _ - - -- - Operations Summary i Cont RIH w/ 3.70" mill and motor assy to 11,938'. Attempt to get inside Top pkr. Lost 500 psi pump pressure, POOH. Found motor had come apart. LIH 3.7" Mill, 0.62" of motor, and motor rotor in hole. - - - - - 10/1/2007 00:00 - 10/2/2007 00:00 Operations Summary PUMU fishing BHA. RIH. rotate through scab. RI to top of pkr @ 11,938'. No indication of Fish. POOH. PUMU 2nd Fishing BHA. RIH. _- _ _-_ _ -_ 10/2/2007 00:00 - 10/3/2007 00:00 _- Operations Summary --- - _ _ - _ -- - - _._ - Continue to RIH. Attempt to washover & latch fish. No Joy. POOH. Conduct BOPE test. _ _ _ __ ~ 110/3/2007 00:00 - 10/4/2007 00:00 __ __ _ _. -- _ - ' Operations Summary 110/4/200 BOO:OOe 10 5/ 00 010:00 BHA #7. RI to 11,938' worked tools. Saw increase in pump pressure. POOH w/ 5k initial drag. - - _ - - - - -- Operations Summary Finished POOH. Had full recovery of fish. LD same. RIH w/ BHA #8 (3-1/2" bull nose mill & motor). 10/5/2007 00:00 - 10/6/2007 00:00 _ _ i Operations Summary ~ ~ Cont TIH. tag top of pkr @ 11938'. Break circ. Beginning milling work @ 11948'. First 10' acting like junk, making hole slowly. Begin to lose fluid while circulating @ approx 10bph. Cont milling U 12008' -top of F-nipple. No further progress. Checked static loss rate at +/- 3Bbl/hr.Trip for new mill. PUMU same. RIH. Work thru top of pkr. Took weight at +/- 12,000' (8' of fill). PU and attempt to establish circulation. Tools plugged. Trip to clean out tools. 10/6/2007 00:00 - 10/7/2007 00:00 Operations Summary 'Cont. RIH w/ BHA#9 to top of pkr @ 11,938'. Attempt to break circulation. No Joy. Drop dart. Open bypass sub. POOH. Found sand & sludge above motor. LD BHA. PU New motor. RI (3) stands. Circulate thru BHA. System pressured up. POOH. Unable to turn motor. LD motor. RIH (w/o motor) 20 stands. Circulate system. POOH. PU new motor. RIH. 10/7/2007 00:00 - 10/8/2007 00:00 __- __-_ Operations Summary Continue RIH w/ BHA #11. Wash down and tag @ 12,009'. Mill on debri for 2-1/2 hrs. No Joy maybe made < 1'. POOH. LD BHA. Bullnose mill showed a a wear ring of (+/-) 3". PUMU 3.4" tappered mill w/o motor. RIH. :>; 'i i`1 Chevron -Alaska SWW Daily Operations Summary ---- We~ll Name - Field Name .API/UWI 'I Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) ; I M-30 MCARTHUR ';507332043000 ADL0017594 160.0 Daily Operations 10/8/2007 00:00 - 10/9/2007 00:00 _ _ _ _ _ _ ' ~- ------ Operations Summary Cont to RIH w/ BHA. Tag TOL @ 11,383'. RI wash thru pkr to 12,009'. Tag solid. Work DP. No progress. PU above top of pkr. CBU. RI to 12,009'. Mill !; down thru junk. RI 30' past EOT. PU above pkr. CBU. POOH. LD BHA. PUMU seal assy. RIH. !Losses @ 10 bph. 10/9/2007 00:00 - 10/10/2007 00:00 __ _ __ _ _~ ---- `OperationsSummary - -- _.. _. _.. ----- -. ______ --.._ -__-. I iContinue RIH w/ Seal assy. Stab into pkr @ 11,938'. Pressure test tbg x csg annulus to 2200 psi for 30 min. Monitored PC x SC annulus. No change. RU !slickline. RIH w/ 2" GR. Tag top of "F" pkr @ 13,182' SLM. Tagged solid @ 13,222'. Work tools, pushing debris, to 13,360' SLM (96' below EOT). POOH. I, RD slickline. POOH w/ DP. LD135 joints of DP. -- ~ X10/10/2007 00:00 10/11/2007 00:00 ' - - _-- -- - - _ - _ - -~ Operations Summary (Continue to PU RIH w/ 4-1/2", 12.6#, L-80, w/ TK-69 coated Tubing. Displace tbg x csg w/ 9.2 ppg NaCI w/ 1% CRW-132. Losses at 9 bph - -- - - - -. 10/11/2007 00:00 - 10/12/2007 00:00 __ - - -- --- - -- ~Operations Summary ; Continue RIH w/ 4-1/2" 533 Hydril Coated tbg. Locate pkr @ 11,945' w/o latching into pkr. PU change tbg x csg annulus over to pkr fluid. RI stab into pkr ito latch anchor. No Joy on getting anchor to latch. Made several attempts w/ same result. POOH standing back 4-1 /2" injection string. - -- -- _ - - - ---- - - -_ _ __ 10/12/2007 00:00 - 10/13/2007 00:00 __ _ _________ __ Operations Summary Conduct BOPS test. PUMU new SAB pkr Assy. RIH tag F-1 pkr @ 11,958'. Space-out. PUMU tbg hngr. Position pkr @ 11,914'. RU slickline. RIH w/ "N" I~ Test Plug on teflon coated tool string. - - - --- 10/13/2007 00:00 - 10/14/2007 00 00 _ _ _ ___ ___j Operations Summary ! Continue RIH w/ "N" Test toll on slickline. Set plug in "XN" Profile @ 11,946'. Pressure up on tbg to 3500 psi. Set pkr @ 11,914'. POOH w/ slickline RD ; Same. RI land tbg w/ 25k on pkr. MIT tbg x csg annulus to 2200 psi for 30 min. ND BOPE. __ __ 10/14/2007 00:00 - 10/15/2007 00:00 ___ Operations Summary j Continue ND BOPE. NU Tree. Test same. Release Rig to M-17. -- --- -- -- - --- 10/15/2007 00:00 - 10/16/2007 00 00 _ __ _ _ _- _ - -- --- - Operations Summary Cost Adtustment Only ~-- - __ - -- --- __ --- - - -I i ; II • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R Novo 0 2007 REPORT OF SUNDRY WELL OPERATI(,~1 Oil & Gas Cans, Commission Anchorage 1. Operations Abandon Repair Well Plug Perforations Stimulate ~ Other _. _ __ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Union Oil Company of California Development ^ Exploratory^ 91-64 " 3. Address: PO BOX 190247 Stratigraphic^ Service 6. APi Number: Anchorage, AK 99519--0247 50-733-20430 ' 7. KB Elevation (ft): 9. Well Name and Number: 160' KB above MSL J M-30 8. Property Designation: 10. Field/Pool(s): Steelhead Platform ADL 17594 ~ McArthur River "G" Zone / W. Foreland 11. Present Well Condition Summary: Total Depth measured 14,620' ~ feet Plugs (measured) 14,575' true vertical 10,686' ~ feet Junk (measured) Effective Depth measured 14,575' feet true vertical 10,649' feet Casing Length Size MD TVD Burst Collapse Structural 965 26 80 to 1039 80 to 1001 1346 NA Conductor 1365 16 80 to 1439 80 to 1357 2630 1020 Surface 4150 13 3/8" 81 to 4224 81 to 3361 3090 1540 Production 12173 9 5/8" 81 to 12247 81 to 9386 6870 4750 Scab Liner 151 7 5/8" 4113 to 4264 3282 to 3389 12620 11080 Liner 2620 7 11383 to 14003 8692 to 10831 8160 7030 Liner 755 5 13865 to 14620 10717 to 11341 10140 10490 Perforation depth: Measured depth: See Attached True Vertical depth: See Attached Tubing: (size, grade, and measured depth) 4.5 (Plastic Coated) L-80 11,926' Packers and SSSV (type and measured depth) 11,926' & 11,959' & 11,990' & 13,190' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~- ~I~~~ ~ ~~~~ 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 BPD 0 psi 0 psi Subsequent to operation: 12,650 BPD 50 psi 2,435 psi 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 ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-280 Contact Steve Tyler 263-7649 Printed Name Tim Brandenbur s Title Drilling Manager ~ Signature ~ Phone 263-7657 Date 10/30/2007 Form 10-404 Revised 04/2006 \',Z~ Submit~i~~ p~ yO~ ORIGINAI. .~."~ ~.~~ Perforation Detail • Zone MD Top MD Btm TVD Top TVD Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 9,460' 9,476' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 9,497' 9,551' 66 4-1/2" 4 60 7/1/1992 G-3 12,518' 12,568' 9,605' 9,646' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 9,669' 9,735' 80 4-1/2" 4 60 7/1/1992 G-5 12,830' 12,859' 9,862' 9,886' 29 4-1/2" 4 60 7/1/1992 G-5 12,869' 12,932' 9,894' 9,946' 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-1 13,207' 13,227' 9,596' 9,610' 20 2 7/8" 6 60 9/11/2007 HB-1 13,229' 13,249' 9,611' 9,625' 20 2 7/8" 6 60 9/1112007 HB-3 13,429' 13,499' 10,357' 10,414' 70 12121-27/02 HB-3/4 13,460' 13,490' 10,382' 10,407' 30 12/21-27/02 HB-4 13,520' 13,570' 10,432' 10,473' 50 12/21-27/02 13,599' 13,629' 10,497' 10,522' 30 12/21-27/02 HB-5 13,689' 13,709' 10,571' 10,588' 20 12/21-27/02 HB-5/6 13,758' 13,818' 10,628' 10,678' 60 12/21-27/02 WEST FORE LAND WF-1 13,941' 13,960' 10,780' 10,795' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 10,805' 10,863' 70 2-7/8" 6 60 7/211992 WF-2 14,071' 14,136' 10,887' 10,941' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 10,947' 10,998' 62 2-7/8" 6 60 7/2/1992 WF-4 14,244' 14,360' 11,030' 11,126' 116 2-7/8" 6 60 7/2/1992 WF-5 14,384' 14,430' 11,145' 11,183' 46 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 11,233' 11,256' 28 2-7/8" 6 60 7/2/1992 ~I Chevron -Alaska SWW Daily Operations Summary (Well Name Field Name - 'API/UWI - Lease/Serial IM-30 MCARTHUR ii507332043000 ADL0017594 { Pnmary Job Type 'Primary Wellbore Affected Perforating Main Hole --- - - - Jobs Primary Job Type Job Category A EF No (Objective Perforating Completion I R7038 Daily Operations 9/5/2007 00:00 - 9/6/2007 00:00 Operations Summary LRU Slickline. RIH w/ MPLT to 14,450'. Make passes up to 12,350'. Make additional ~ 9/11 /2007 00:00 - 9/12/2007 00:00 _ _ Operations Summary RU Eline Lubricator. Made (2) gun runs w/ 2 7/8" Power Jet Omega pert gun. 6 SPF, & [13,207'- 13,227'] all guns fired. Elev (ftKB) 160.0 (Actual Start '.End Date Q EC EC nc 9/5/2007 ~ L_ M-3° CURRENT S teelhead Platform Field: Tradin Ba API#: 50-773-20430-00 RIGINAL RIG LEVATIONS Le B-1 Well Classificaton: In'ector Slot: 9 Total De the 15,271' Surface Location: PB7D: 14,575' ~.._ X: 214,138' Tubin 4-%", 12.6#, L-80, IBT-M 74.40' ~' Y: 2,ass,535' Prod Pkrs: Baker FAB 11,959'; Baker SABL3 11,990' Well Status: SI Baker F-1 13,190' ' ~ Operator: Chevron Ownership: Chevron/PE BHP: G :4162 si Spud Date: 4/3/1992 ~ HK: 4496 psi Other: WO 10/21/96 WF: 4674 si WO 10/1 2/07 Tbg CO. Added a pkr. ~,HT 18n° ~ UA91NC; 3. lulfinq ~ ~ 1,039' Descri lion Wei ht Grade Conn ID Len th Top __ Hrs Btm TOC Drive Pie 26 Weld 965' 80' 1,039' Driven 55.0 h 1,439' Conductor 16 75.0# K-55 BTC 15.124 1,365' 80' 1,439' Surf 78.0 h 13 3/8" 61 0# 515 2 297 81' 12 371' 2 ' Surface . K-55 BTC , . , Est 3x3.5 t 1 665 13 3/8" 68.0# 12.415 1,853' 2,371' 4,224' 4,224' 95/8" 47.0# 4,086' 81' 4,167' ECP Buttress 2' 4,167' 4,169' Production 9 5/8" 47.0# L-80 8681 2,140' 4,169' 6,309' 3.750' Est 200.0 t 9 5/8" 47.0# Mod BTC 858' 6,309' 7,167' 95/8" 53.5# BTC 8.535 5,080' 7,167' 12,247' Liner 7 29.0# N-80 TKC 6.184 2,620' 11,383' 14,003' 11,aaa'est 52.5h Liner 5 18.0# N-80 AB FLAS 4.276 755' 13,865' 14,620' 1a,ass ea 35.0 h Scab 75/8" 39.0# P-110 FL-4S 6.63 151' 4,113' 4,264' NA NA Tubing 41/2" 12.6# L-80 Hydril533 3.958 11,852' 74' 11,926' Rl~gscoatedw/ca 12,247 - `~ WH 33 I J ' S ' ' ~ 1 d' 2 3 it ~~ 4 ~~ ~ 5 ~ 11 6 - '3 ~ 7 ~~ .,! 12 " 8 3 t ' 9 ia' to ~~ ~ 11 15 12 13 '~ 14 _ _ _ 15 _ tt77 ~~ ~~~~ 17 J -? 18 1rt 19 _ ~ ,':'~_-~ I s-- __ ~ - - - - u= -- ~_ ~- 14,003' c ~,cc 3 14,620' rwb lry Descri lion Depth Len th ID OD Tbg Hanger, TC-IA-EN, SS, i6" w/CI W 4 type H BPV profile. 4-%" CS top x Hyd 563 bt 74' 0.83' Baker CPH Liner Pkr, 7-5/8" x 9-5/8" 4,113' 9.55' 6.625" 8.375" 3 Joints of 7-5/8", 39#, P-110 w/ FL-4S 4,123' 131.24' 6.625" 7.625" Baker H o 3D Liner Hn r Pkr, 7-5/8" x 9-5/8" 4,254' 10.50' 6.625" 8.437" K-22 Anchor Tubin Seal Ass 4.75" Plastic Coated . 1.3e' ~~ per 11,926' 0.71' 3.875" 5.500" Baker 85SA647 X 40 Prod. Pkr w/ MOE w/ XO to 4-%" Butt. 11,926' 10.69' 4.000" 5.860" "XN" Nipple 4 1/2" Bult Box X Pin W/ 3.75" Profile 11,947' 1.21' 3.813" 5.250" Baker K-22 Anchor Seal Ass W/O Latch Or Seals 11,958' 0.71' 3.875" 5.500" Baker 85FA6-47 Ret Production Pkr w/ MOE 11,959' 9.17' 4.000" 5.860" Otis X Ni ple 11,977' 1.74' 3.813" 5.250" Baker'K-22' Locator Seal Assembl w/o seals 11,989' 0.78' 3.875" 5.560" Baker'SABL-3' Packer, 85SAB47X40. 11,990' 4.49' 3.875" 5.875" Baker MOE, w/ XO 5" LTC x 4-%" Butt 11,994' 6.53' 4.590" 5.000" Baker'F' Nlpple, 3.75" rofile. 12,033' 1.28' 3.750" 5.250" Baker'F' NI le, 3.75" profile. 12,055' 1.27' 3 750" 5.250" Baker H drotrip Sub w! WLEG 12,066' 1.46' 3.937" 5.600" Baker'F-1' Packer, Size 85-40. 13,190' 3.950" Baker MOE w/ XO 5" LTC P x 4-112" Butt 13,194' 4.590" Baker'F' Nipple, 3.68" profile. 13,235' 3.680" Baker'R' Nip le, 3.68" / 3.625" w/ WLEG 13,270' 3.625" P orloret cns Zone Top Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 20 4-1 /2" 4 60 71111992 G-2L 12,386' 12,452' 66 4-1 /2" 4 60 7/1/1992 G-3 12,518' 12,568' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 80 4-1/2" 4 60 7/1/1992 G-5 12,830' 12,859' 29 4-1/2" 4 60 71111992 G-5 12,869' 12,932' 63 4-1/2" 4 60 7NN992 HEMLOCK HB-1 13,207 13,227 20 2-%" 6 60 °fJ111/2007 HB-1 13,229' 13,249' 20 2-'/." 6 60 911112007 HB-3 13,429' 13,499' 70 12/21-27102 HB-3/4 13,460' 13,490' 30 12121-27102 HB-4 13,520' 13,570' 50 12121-27102 13,599' 13,629' 30 12/21-27/02 HB-5 13,689' 13,709' 20 12/21-27/02 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND WF-1 13,941' 13,960' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 70 2-7/8" 6 60 7/2N 992 WF-2 14,071' 14,136' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 62 2-7/8" 6 60 71211992 WF-4 14,244' 14,360' 116 2-7/8" 6 60 712/1992 WF-5 14,384' 14,430' 46 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 28 2-7/8" 6 60 712N 992 As completed on 10/12/07 Prepared B : Steve T ler . ~1f~1fŒ (ID~ ~~~~ælA\ . AIA~1iA OIL AlQ) GAS CONSERVATION COMMISSION l J SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279·1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519-0247 Re: McArthur River Field, GjW. Foreland Oil Pool, M-30 Sundry Number: 307-281 i qf-' Orot.{ Dear Mr. Brandenburg: SCANNED S E P 0 7 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this i!1 day of August, 2007 Encl. . , . . . Chevron =- Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com August 24, 2007 RECEIVED AUG 2 4 AlaSka 011 & 2001 Gas Cons. C ' Anchorage tHnl11lssion John Norman Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Steelhead M-30 Application for Sundry Approval Dear Commissioner Norman, Attached for your approval is an Application for Sundry Approval (Form 10-403) for the above referenced well. The proposed work will be undertaken to change out the tubing ý~ string for the Steel head M-30 well. M-30 was last worked over in October 1996 to repair a leak in the 9-5/8" Production Casing (communication to the 13-3/8") with a 7-518" scab liner assembly (4113' to 4264'). A pressure test of 3000 psi on the 9-5/8" PC, post scab installation, lost 83 psi over a 32 minute period. M-30 has passed subsequent MIT tests during its service. On March 22,2007, Tubing by Casing communication was observed and the well was shut- in. Chevron proposes to change out the tubing string to a 4-1/2", 12.75#, L-80 Plastic Coated Tubing wi Hydril 533 connections. If you have any questions, please call me at 263-7657 or Mr. Steve Tyler at 263-7649. Sincerely, -^ "'_. -Z~~C c~ ~ Timothy C. Brandenburg Drilling Manager Attachment TB:sk Cc: Well File Steve Tyler Union Oil Company of California I A Chevron Company http://www.chevron.com c' DT3 .r-/'<'7) 7 ) \t:l,I::IVI::U . I STATE OF ALASKA ~,~.-O.. Y ALASKA OIL AND GAS CONSERVATION COMMtlON ~~~ AUG 2 42007 APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Cammission 20 MC 25.280 " , 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate[] Waiver D -~... Other D Alter casing D Repair well ~ tIf¡$~1 Plug Perforations D StimulatE[] Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Unocal Development D Exploratory D 91-64 3. Address: Stratigraphic D Service 0 6. API Number: PO BOX 190247 Anchorage, AK 99519-0247 50-733-20430 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? D 0 M-30 Yes No 9. Property Designation: .J:O. KB Elevation (ft): 11. Field/Pool(s): Steel head Platform ~f)l... /7>1¥ ~Zl' 160' KB above MSL McArthur River "G" Zone I W. Foreland 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,620' , 10,686' ,- 14,575' 10,649' 14,575' Casing Length Size MD TVD Burst Collapse Structural 965' 26 " 80.0' to 1,039' 80.0' to 1,001' 1,346 psi NA Conductor 1,365' 16 " 80.0' to 1,439' 80.0' to 1,357' 2,630 psi 1,020 psi Surface 4,150' 133/8" 81.0' to 4,224' 81.0' to 3,361' 3,090 psi 1,540 psi Production 12,173' 9 5/8" 81.0' to 12,247' 81.0' to 9,386' 6,870 psi 4,750 psi Scab Liner 151' 7 5/8" 4,113' to 4,264' 3,282' to 3,389' 12,620 psi 11,080 psi Liner 2,620' 7 " 11,383' to 14,003' 8,692' to 10,831' 8,160 psi 7,030 psi Liner 755' 5 " 13,865' to 14,620' 10,717' to 11,341' 10,140 psi 1 0,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: ITubing Grade: Tubing MD (ft): See Attached See Attached 41/2" L-80 11,958' Packers and SSSV Type: Baker FAB; Baker SABL3; Baker F-1 Packers and SSSV MD (ft): Baker FAB @ 11.959'; Baker SABL3 @11 ,990'; Baker F-1 @ 13,190' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch 0 Exploratory D Development D Service 0 15. Estimated Date for ~1t5-()" ~~'""' 16. Well Status after proposed work: Commencing Operations: ~ . Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenbu~g Title Drilling Manager Signature Z:-A ~one 263-7657 Date 8/24/2007 - /:;./ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (~'1'" r9.ß' Plug Integrity D BOP Test ~ Mechanical Integrity Test ~ Location Clearance D Oth"~O\(>\ W\'> ~~? ~\C1"~. .\N~ ~,\ ú-~,~",,~.ct>\,,\t ~,\.~~ rv. \) \ 'i''''''-o..~ o~r ""\, 0...,. \ '" " fC>~"" II\. \ <J s : Subsequent Form Required: l{C)L\ RBDMS BFL AUG 3 0 2007 tI ~ r¡/ APPROVED BY Date: ß,~?,Dr Approved by: /..... OMMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 llKl ~+Nt .1:: _AJJ $',27'67 Submit in Duplicate ./ ", . . Peñoration Detail Zone I MD Top MD Btm TVD Top TVD Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 9,460' 9,476' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 9,497' 9,551' 66 4-1/2" 4 60 7/1/1992 G-3 12,518' 12,568' 9,605' 9,646' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 9,669' 9,735' 80 4-1/2" 4 60 7/1/1992 G-5 12,830' 12,859' 9,862' 9,886' 29 4-1/2" 4 60 7/1/1992 G-5 12,869' 12,932' 9,894' 9,946' 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-3 13,429' 13,499' 10,357' 10,414' 70 12/21-27/02 HB-3/4 13,460' 13,490' 10,382' 10,407' 30 12/21-27/02 HB-4 13,520' 13,570' 10,432' 10,473' 50 12/21-27/02 13,599' 13,629' 10,497' 10,522' 30 12/21-27/02 HB-5 13,689' 13,709' 10,571 ' 10,588' 20 12/21-27/02 HB-5/6 13,758' 13,818' 10,628' 10,678' 60 12/21-27/02 WEST FORELAND WF-1 13,941' 13,960' 10,780' 10,795' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 10,805' 10,863' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 10,887' 10,941' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 10,947' 10,998' 62 2-7/8" 6 60 7/2/1992 WF-4 14,244' 14,360' 11,030' 11 ,126' 116 2-7/8" 6 60 7/2/1992 WF-5 14,384' 14,430' 11,145' 11,183' 46 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 11,233' 11,256' 28 2-7/8" 6 60 7/2/1992 , ' ~. ~ . . 1 Slickline gauge tbg. Tag for fill. 2 Mobe Steel head Rig. Build Pit volume with KWM. 3 NO Tree. NU BOPE. Test same 1>ÖGa ~\ \;)~,fè~ \. <:øJ ";><:6/ PU Land joint. RU APRS. RI cut tbg @ top of first full'jt while pulling on pipe, above K 4 22 Anchor. POOH. RD APRS. CBU change over to KWM 5 PU LO tbg hngr. POOH. LO completion string. PU RIH w/ overshot and fish BHA on 3-%" OP. RIH latch tbg stub. Rotate anchor 6 form pkr @ 11,959'. 7 POOH w/ fish. LO same. 8 LO OP. PUMU Baker redressed K anchor. MU to 4-%" PCT completion string. RIH w/ 9 completion tbg string. Prior to stabbing into pkr. Circulated/annulus with Pkr fluid. Space-out stab into pkr. 10 Pressure test to 2000 psi. Land tbg hngr. 11 NO BOPE. NU tree. Pressure test same. 12 Oemobe from M-30. Release rig to M-17. Steel head M-30 WO Summary . . ~,' I " ating Upper well Bay Floor 74.40' 38.84' 6.75' 23.47' 12.51' Top of 16-3/4" 5 M Tbg Spool 59.76' . . , "RIGINAL RIG Field: T 50-773-20430-00 B-1 Injector ~ ELEVATIONS n: 01#: 9 Total Depth: 15,271' Surface Location: PBTD: 14,575' / ~ X: 214,138' Tubing: 4-%", 12.6#, L-80, IBT-M 74.40' I Y: 2,499,535' Prod Pkrs: Baker FAB @ 11,959'; Baker SABL3 @11,990' s: SI Baker F-1 @ 13,190' Operator: Chevron Ownership: Chevron/PE BHP: G : 4162 psi Spud Date: 4/3/1992 HK: 4496 psi Other: WO 10/21/96 WF: 4674 psi 180" 1,039' Wei¡:¡h! ID Lella!h 101:¡ Btm Drive Pipe 26 " Weld 1,365' Œ 1,039' 1 ,439' Conductor 16 " 75.0# K-55 BTC ~124 1 ,439' 78.0 hrs " 61.0# 12.515 2,297' 81' 2,371' Surface K-55 BTC 1,885' E 393,5 hrs " 68.0# 12.415 1,853' 2,371' 4,224' 4,224' 95/8" 47.0# Buttress 8.681 6,235' 81' ,309' Production 9 518" 47.0# L-80 Mod BTC 858' 6, 3,750' Est 200.0 hrs 95/8" 53.0# BTC 8.535 5,080' 7, Liner 7 " 29.0# N-80 TKC 6.184 2,620' 11,383' 14,003' ~" 18.0# N-80 AB FLAS 4.276 755' 13,865' 14,620' Scab 5/8" 39.0# P-110 FL-4S 6.6~ 4,113' 4,264' NA NA 1/2" 12.6# L-80 IBT-M 3,95 74' 11,958' NA I NA - . Depth Length ID OD 12,247' WH FMC Tbg Hanger w/CIW 4" type H BPV profile 74' 0.83' 1 Baker 'X" Nipple, 3.813" profile 531' 1.20' 3,750" 2 Baker CPH Liner Pkr, 7-5/8" x 9-5/8" Biiii 3 (3) Joints of 7-5/8",39#, P-110 wI FL-4S 7,625" 4 Baker Hyflo 3D Liner Hngr Pkr, 7-5/8" x 9-5/8" 4,254' 10.50' 6.625" 8.437" 5 Baker 'K-22' Anchor Seai Assembly. (1.38' in pkr) 11, 0.76' 3.875" 5,500" 6 Baker 85FAB-47 Ret Production Pkr wI MOE 11,959' 9.17' ~ 7 Otis X Nipple 11,977' 1.74' 8 ~'K-22' Locator Seal Assembly wlo seals 11,989' 0.78' 5.560" 9 'SABL-3' Packer, 85SAB47X40. 11,990' 4.49' 3.875" 5.875" 10 MOE, wI XO 5" LTC x 4-%" Butt "" 11 Baker 'F' Nipple, 3.75" profile. 12, .750" 5.250" 12 Baker 'F' Nipple, 3,75" profile. 12, 5.250" 13 Baker Hydrotrip Sub wI WLEG 12,066' 1.46' 5.600" ::::: 14 Baker 'F-1' Packer, Size 85-40. 13,190' 3.950" 15 S"" MOE wi XO 5" LTC P ,.. 112" S,. 13,194 "590'l 16 1 T S"" 'R' N;"I., 3.68" I 3.625" wi WLEG '3,625" Btm Amt Gun Size SPF Date G-ZONE G-2 12,340' 12,360' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 66 4-1/2" 4 60 7/1/1992 = G-3 12,518' 12,568' 50 4-1/2" 4 60 7/1/1992 G-4 ~12" 4 60 7/1/1992 G-5 12,830' 12,85 4-1/2" 4 60 7/1/1992 G-5 112,869'1 12,932' 63 1/2" 4 60 7/1/1992 HEMLOCK HB-3 13,429' 13,499' 70 - 12/21-27102 14,003' HB~3/4 13,460' 13,490' 30 . HB-4 13,520' 13,570' . 50 ....,..... ...~''''... .",,, '·""v" 13,599' 13,629' I 30 12/21-27/02 HB-5 13,689' 13,709' 20 12/21-27102 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND WF1 ~9 2-7/8" 6 60 7/2/1992 WF-1 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 65 2-7/8" 6 60 7/2/1992 I " 14,620 14,206 62 14,360' 116 14,430' 46 14,518' 28 2-7/8 2-7/8" 2-7/8" 2-7/8" 6 6 6 6 7/2/1992 7/2/1992 7/2/1992 7/2/1992 Current Sketch Post WO on 10/96 Prepared By: Steve Tyler ,'t ~, . 74.40' 1,039' 1 ,439' 4,224' 12,247' 14.003' 14,620 (. II r\RIGINAL RIG ~ ELEVATIONS L \ I -... ILeg: Slo1#: Trading Bay B-1 9 15,271 ' 14,575' 4_%", 12,6#, L-80, IBT-M Baker FAB @ 11,959'; Baker SABL3 @11,990' BakerF-1 @ 13,190' Ownership: Chevron/PE Spud Date: 4/3/1992 !Other: WO 10121/96 I :::: 30-00 Well Classificaton: Total Depth: PBTD: 214,138' Tubing: 2,499,535' Prod Pkrs: SI r T Surface Location: ~ Well Status: ator: Chevron G : 4162 psi HK: 4496 psi WF: 4674 psi : 1800 """M'" Conn II) length Top Btm Drive Pipe 26 " Weld 965' 80' 1,039' ,0 hrs Conductor 16 " 75.0# K-55 BTC 15,124 1,365' 80' 1,439' Surf 78,0 hrs Surface 13 3/8" 61,0# K55 BTC 12.515 2 81' 2,371' - 1,885' Est 393,5 hrs 133/8" 68.0# 12.415 1,853' 2,371' 4,224' 9 5/8" 47.0# Buttress 8.681 6,235' 81' 6,309' Production 95/8" 47,0# L-80 Mod BTC 858' 6,309' 7,167' 3,750' Est 200.0 hrs 95/8" 53.0# BTC 8,535 _5,080' 7,167' 12,247' 7 " 29.0# N-80 TKC 6.184 2,620' 11 11,38 hrs 5 " 18,0# N-80' AB FLAS 4,276 755' 1 5t 35.0 hrs 75/8" 39.0# P-110 FL-4S 6.63 151' NA NA 41/2" 12.6# L-80 Hyd 533 3.958 1 NA NA P: Liner Liner Scab ITubing WH 1 2 3 6,625" 8,375" 6,625" 7.625" 6.625" 8.437" Baker CPH Liner Pkr, 7-5/8" x 9-5/8" (3) Joints of 7-5/8", 39#, P-110 wI FL-4S Baker Hyflo 3D Liner Hngr Pkr, 7-5/8" x 9-5/8" 4,113' 9,55' ~31,24' ~0.50' 4 Baker 'K-22' Anchor Seal Assembly (Plastic Coated). (138' in pkr) 5 Baker 85FAB-47 Ret Production Pkr wi MaE 6 Otis X Nipple 7 Baker 'K-22' Locator Seal Assembly wlo seals 8 Baker'SABL-3' Packer, 85SAB47X40. 9 Baker MOE, wI XO 5" LTC x 4-W Butt 10 Baker 'F' Nipple, 3.75" profile. 11 Baker 'F' Nipple, 3.75" profile. 12 Baker Hydrotrip Sub wi WLEG 11,958' 0.76~ 11,959' 9.17~ _,7 5.250" 0.7 ".~90' 449' 3.875" 5: .53' 4.590" 5.RQQj 12,033' 1.28' 3.750" 525ëïl 12,055' 1.27' I 3,750" 5,250" 12,066' 1.46' 3.937" 5,600" 13 Baker 'F-1' Packer, Size 85-40. 14 Baker MaE wI XO 5" LTC P x 4-1/2" Butt 15 Baker 'F' Nipple, 3.68" profile. 16 Baker 'R' Nipple, 3.68" I 3,625" wI WLEG 13,190' 13,194' 13,235' 13,270' 4.590" 3.680" 3.625" -i Zone Top Btm Amt Gun Size SPF Phase G-ZONE G-2 12,340' 12,360' 20 4-112" 4 60 7/1/1992 G-2L 12,386' 12,452' 66 4-1/2" 4 60 == 7/1/1992 = G-3 12,518' 12,568' 50 4-112" 4 60 7/1/1992 G-4 12,596' 12,676' 80 4-1/2" 4 60 7/1/1992 G-5 12,830' 2,859' 29 4-1/2" 4 60 7/1/1992 G-5 12, 2,932' 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-3 13,429' 13,499' 70 12/21-27/02 HB-314 13,460' 13,490' 30 12/21-27/02 HB-4 13,520' 13,570' 50 12/21-27/02 13,599' 13,629' 30 12/21-27/02 HB-5 13,689' 13,709' 20 12/21-27/02 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND WF-1 1~~ 13,960' 19 2-7/8" 6 60 7/2/1992 WF-1 13 70 2-7/8" 6 60 7/2/1992 WF-2 14,071'114,136' 65 2-7/8" 6 60 7/2/1992 WF-3 I <A <.."I . 4,206 62 2-7/8 " 6 60 7/211992 WF-4 4,360' 116 2-7/8" 6 60 7/2/1992 WF-5 14,430' 46 2-7/8" 6 60 7/2/1992 WF-6 14,518' 28 2-7/8" 6 60 7/2/1992 . Page 1 of 1 . Maunder, Thomas E (DOA) From: Tyler, Steve L [tylersl@chevron.com] Sent: Tuesday, August 28, 2007 9:56 AM To: Maunder, Thomas E (DOA) Subject: RE: M-3&(18t..-.; 1. The M-30 injector has energized our near wellbore sands. Current SITP is 200 psi which equates to a 8.87 ppg. We will be using a 9.5 NaCI brine as our workover fluid. This may change with Hal's test injection. 2. Proposed BOPE is in a 5k configuration we propose a test pressure of 3k. 3. Current plan is to use 3-1/2" DP to fish the anchor out of the pkr. Yes we will change rams after we LD tbg, for the DP and change them again before we run our 4-1/2" PCT. From: Maunder, Thomas E (DOA) (mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 28,20078:53 AM To: Tyler, Steve L SUbject: RE: M-30 (191-064) 5GANNED SEP 0 7 2007 Steve, Following up, I am reviewing the workover sundry application. 1. You use "KWM" to describe the workover fluid. What is the SITP on the well and what will the weight of the KWM be? 2. What is the proposed BOP test pressure? 3. The tubing is 4-1/2" and you plan to use 3-1/2" DP. I presume that rams will be changed to accommodate the different pipe sizes since I don't believe VBRs are available. Thanks in advance. Look forward to your reply. Tom Maunder, PE AOGCC --_.._---~-,- From: Maunder, Thomas E (DOA) Sent: Tuesday, August 28, 2007 8:06 AM To: 'Tyler, Steve L' Subject: M-30 (191-064)Perforate Request Hi Steve, Received the sundry to perforate HB 1 in M-30. Hal Martin had been calling with regard to doing an injectivity test and had mentioned that it is planned to workover the well. Is there additional work planned? Call or message with any questions. Tom Maunder, PE AOGCC 8/28/2007 . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 28, 2007 8:06 AM To: 'Tyler, Steve L' Subject: M-30 (191-064)Perforate Request Hi Steve, Received the sundry to perforate HB 1 in M-30. Hal Martin had been calling with regard to doing an ínjectivity test and had mentioned that it is planned to workover the well. Is there additional work planned? Call or message with any questions. Tom Maunder, PE AOGCC VQ.' =.\ \ Ç-.-.;, "'- ") ~" ~ .\ '-N; '1 '>~ ~ ...:., ~ "ð d- '>. ~ ~ t-\C=,:> <;, \ ~ 1>-.)0',"-"'" ~ \c>',,",,'NêJ $.(C\'O-\Ü. ~\I' ./£0/1 ~ I;;> 'b' ~CANNED AUG 2!) 2007 .*.,~.. 8/28/2007 . ~1T~1TŒ (ID~ ~~~~æ~ . A.I,.-,SBA. OIL AlQ) GAS CONSERVATION COMMISSION / SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519-0247 SCANNED AUG 292007 Re: McArthur River Field, GjW. Foreland Oil Pool, M-3.0 '-I L Sundry Number: 307-280 . ..". ,q \ _ Ðv-r Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisJ,$ day of August, 2007 Enc!. ~ . Cf}~þ~-,oß OT5õ/~/? STATE OF ALASKA . r ALASKA Oil AND GAS CONSERVATION COM SION ;::rq¡' . APPLICATION FOR SUNDRY APPROVALS ;r<?; 20 MC 25.280 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: Unocal 3. Address: PO BOX 190247 Anchorage, AK 99519--0247 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Suspend D Repair well D Pull Tubing D Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Perforatf2]" Waiver D Stimulat{] Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 91-64 ' 6, API Number: Other D Exploratory D Service [] 50-733-20430 " 8. Well Name and Number: Casing Structural Conductor Surface Production Scab Liner Liner Liner ,[ Yes D No [] A 10. KB Elevation (ft): 11. Field/Pool(s): A1>t- /7~9t/ ».21.07 160' KB above MSL McArthur River "G" Zone / W. Foreland PRESENT WELL CONDITION SUMMARY rTotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10,686' . 14,575' 10,649' 14,575' Length Size MD TVD Burst Collapse 965' 26" 80.0' to 1,039' 80.0' to 1,001' 1,346 psi NA 1,365' 16" 80.0' to 1,439' 80.0' to 1,357' 2,630 psi 1,020 psi 4,150' 133/8" 81.0' to 4,224' 81.0' to 3,361' 3,090 psi 1,540 psi 12,173' 9 5/8" 81.0' to 12,247' 81.0' to 9,386' 6,870 psi 4,750 psi 151' 7 5/8" 4,113' to 4,264' 3,282' to 3,389' 12,620 psi 11,080 psi 2,620' 7" 11,383' to 14,003' 8,692' to 10,831' 8,160 psi 7,030 psi 755' 5" 13,865' to 14,620' 10,717' to 11,341' 10,140 psi 10,490 psi Perforation Depth TVD (ft): rTUbing Size: rTUbing Grade: rTUbing MD (ft): See Attached 41/2" L-80 11,958' Baker FAB; Baker SABL3; Baker F-1 Packers and SSSV MD (ft): Baker FAB @ 11,959'; Baker SABL3 @11 ,990'; Baker F-1 @ 13,190' M-30 ' Spacing Exception Required? 9. Property Designation: Steelhead Platform 12. Total Depth MD (ft): 14,620' ~ Junk (measured): Perforation Depth MD (ft): See Attached Packers and SSSV Type: 13. Attachments: Description Summary of Proposal [] Detailed Operations Program D BOP Sketch D 15, Estimated Date for 1-Aug Commencing Operations: 17. Verbal Approval: Commission Representative: Date: 14. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: Oil D Gas D Plugged WAG D GINJ D WINJ Service [] " D Abandoned [] ( WDSPL D D 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager Signature '~/j ~hone /7 263-7657 Date 1.~./:lQQ7 ~ -2~-o-:¡' COMMISSION USE ONLY ..... Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2:/:),- 0160 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other:\w<c\\ "H"-~\~"?~"-~ ~\ è}() ~~'-d-S;-\ d-~'l RECEIVED AUG 2 4 2007 Subsequent Form Required: \.-\0 L \~~ræ' 0 \~ ~ IÎ"''' \J'-..\C)' ltt>~I~Irfl1j & G. as Cons. Commission -, ~ ~ ~'\ J .r\nchorage ( I.~ APPROVED BY ~ ð "'1--- Approved by: -, ~ MMISSIONER THE COMMISSION Date: 0- PI - ()7 Form 10-403 Revised 06/2006 O~ \ G rN' J\ _ - RBDMS BFl AUG 2 9 20D7 su~ d!~~:~ 0:>7 . . Peñoration Detai I Zone MD Top MD Btm TVD Top I TVD Btm Amt Gun Size SPF Phase Date G-ZONE G-2 12,340' 12,360' 9,460' 9,476' 20 4-1/2" 4 60 7/1/1992 G-2L 12,386' 12,452' 9,497' 9,551' 66 4-1/2" 4 60 7/1/1992 G-3 12,518' 12,568' 9,605' 9,646' 50 4-1/2" 4 60 7/1/1992 G-4 12,596' 12,676' 9,669' 9,735' 80 4-112" 4 60 7/1/1992 G-5 12,830' 12,859' 9,862' 9,886' 29 4-1/2" 4 60 7/1/1992 G-5 12,869' 12,932' 9,894' 9,946' 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-3 13,429' 13,499' 10,357' 10,414' 70 12/21-27/02 HB-3/4 13,460' 13,490' 10,382' 10,407' 30 12/21-27/02 HB-4 13,520' 13,570' 10,432' 10,473' 50 12/21-27/02 13,599' 13,629' 10,497' 10,522' 30 12/21-27/02 HB-5 13,689' 13,709' 10,571 ' 10,588' 20 12/21-27/02 HB-5/6 13,758' 13,818' 10,628' 10,678' 60 12/21-27/02 WEST FORELAND WF-1 13,941' 13,960' 10,780' 10,795' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 10,805' 10,863' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 10,887' 10,941' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 10,947' 10,998' 62 2-7/8" 6 60 7/2/1992 WF-4 14,244' 14,360' 11,030' 11,126' 116 2-7/8" 6 60 7/2/1992 WF-5 14,384' 14,430' 11,145' 11,183' 46 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 11,233' 11,256' 28 2-7/8" 6 60 7/2/1992 . . 1 Slickline gauge tbg wI dummy perf guns 2 RU Eline. 3 RIH perforate Hemlock HB-1 ."." 4 RD Eline. Demobe same Steel head M-30 Eline Summary 74.40' Chevron 50-773-20430-00 Injector 15,271' 14,575' 4-'h", 12.6#, L-80, IBT-M Baker FAB @ 11,959'; Baker SABL3 @11 ,990' Baker F-1 @ 13,190' Ownership: Chevron/PE Spud Date: 4/3/1992 Other: WO 10/21/96 Icaton: Total Depth: PBTD: 214,138' Tubing: 2,499,535' Prod Pkrs: 81 1,039' Drive Pipe 26 965' 80' 1,439' Conductor 16 75. 1,365' 80' Surface 13 3/8" 61.0# 2,297' 81' 133/8" 68.0# 1 ,853' 2,371' 4,224' 9 5/8" 47.0# Buttress 6,235' 81' Production 9 5/8" 47.0# L-80 Mod BTC 858' 6,309' 95/8" 53.0# BTC 8.535 5,080' 7,167' Liner 7 29.0# N-80 TKC 6.184 2,620' 11,383' Liner 18.0# N-80 AB FLAS 4.276 755' 13,865' 39.0# P-110 FL-4S 6.63 151' 4,113' 12.6# L-80 IBT-M 3.958 11,884' 74' ~ Baker 'X" Nipple, 3.813" profile 531' 1.20' 3.750" Baker CPH Liner Pkr, 7-5/8" x 9-5/8" 4.113' 9.55' 6.625" 8.375" (3) Joints of 7-5/8",39#, P-110 w/ FL-4S 4,1 1.24' 6.625" 7.62 Baker Hyflo 3D Liner Hngr Pkr, 7-5/8" x 9-5/8" 4,254 , 25" Baker 'K-22' Anchor Seal Assembly. (1.38' in pkr) 11,958' 0.76' 3.875" 5. Baker 85F AB-4 7 Ret Production Pkr w/ MOE 11,959' 9.17' 4 Otis X Nipple 11,977' 1.74' Baker 'K-22' Locator Seal Assembly w/o seals 5.560" Baker'SABL-3' Packer, 85SAB47X40. 4.49' 3.875" 5.875" Baker MOE, w/ XO 5" LTC x 4- 'h" Butt 11,994' 6.53' 4.590"1 5.000" Baker 'F' Nipple, 3.75" profile. 12,033' 1.28' 3.7 ' Baker 'F' Nipple, 3.75" profile. 12,055' 1.27' 3.750" 5.250" Baker Hydrotrip Sub w/ WLEG 12,066' 1.46' 3.937" 5.600" Baker 'F-1' Packer, Size 85-40. 113'190' 3~ Baker MOE w/ XO 5" LTC P x 4-1/2" Butt ,194' 4.590" Baker 'F' Nipple, 3.68" profile. 5' 3.680" Baker 'R' Nipple, 3.68" / 3.625" w/ WLEG 13,270' 3.625" ~ G-lONE G-2 ffi40' 12,360' 20 4-1/2" :=RÞ 7/1/1992 G-2L 12,386' 12,452' 66 4-1/2" 7/1/1992 G-3 ~ 50 4-1/2" 7/1/1992 G-4 80 4-1/2" 4 60 7/1/1992 G-5 12,859' 29 4-1/2" 4 60 7/1/1992 G-5 12,869' 12,932' I 63 4-1/2" 4 60 7/1/1992 HEMLOCK HB-3 13,499' 70 I 12/21-27102 HB-3/4 13,460' 13,490' 30 12/21-27/02 HB-4 ~ 13,570' 50 'M~' ~_'AA 13,629' 30 12/21-27/02 HB-5 13,709' 20 .A'A. A_'AA HB-5/6 13,758' 13,818' 60 12/21.27/02 WEST FORELAND WF-1 13,941' 13,960' 19 2-7/8" 6 60 7/2/1992 WF-1 13,972' 14,042' 70 2-7/8" 6 60 7/2/1992 WF-2 14,071' 14,136' 65 2-7/8" 6 60 7/2/1992 WF-3 14,144' 14,206' 62 2-7/8" 6 60 7/2/1992 WF-4 14,244' 14,360' 116 2-7/8" 6 60 7/2/1992 WF-5 14,384' 14,43Olli 2-7/8" 6 60 7/2/1992 WF-6 14,490' 14,518' 2-7/8" 6 60 7/2/1992 12,247' WH 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 14,003' 14,620' Current Sketch Post WO on 10/96 Prepared By: Steve Tyler " . 74.40' 1,039' 1 ,439' 4,224' 12,247' 14,003' f"\RIGINAL RIG ~ ELEVATIONS / ~ I '~ ::::: = ::::::4 = Field: Leg: Slot#: Surface Location: X: Y: 50-773-20430-00 Injector 15,271 ' 14,575' 4_%", 12.6#, L-80, IBT-M Baker FAB @ 11,959'; Baker SABL3 @11 ,990' Baker F-1 @ 13,190' Ownership: Chevron/PE Spud Date: 4/3/1992 Other: WO 1 0/21/96 lassificaton: Total Depth: PBTD: 214,138' Tubing: 2,499,535' Prod Pkrs: SI B-1 9 Well Status: perat HP: Chevron , G: 4162 psi HK: 4496 psi WF: 4674 psi BHT: o ade Corm 10 Lenath Top Btm Weld --L 965' 80' 1,039' Driven 55.0 hrs K-55 BTC 15~ 1,365' 80' 1,439' Surf 78.0 hrs 1 K-55 BTC 12.515 2,297' 81' 2,371' 1.885' Est 393.5 hI's 133/8" 68.0# 12.415 1,853' 2,371' 4,224' 95/8" 47.0# Buttress 6,235 81' 6,309' 8.681 Production 95/8" 47.0# L-80 Mod BTC 858' 7, 95/8" 53.0# BTC 8.535 5, 12,247' 7 " 29.0# N-80 TKC 6.184 2,620' 4,003' 11.383' Est 52.5 hrs 5 " 18.0# N-80 AB FLAS 4.276 755' 14,620' 13,865'Est 35.0 hrs 7 5/8" ~ P-110 FL-4S 6.63 151' 1 4,113' 4,264'~ 41/2" T12.6# L-80 IBT-M 3.958 11,884' 1 74' 111,958'~ WH 1 Baker 'X" Nipple, 3.813" profile 531' 1.20' 3.750" Surface 3.750' Est 200.0 hI's Liner Liner ~ 2 3 4 Baker CPH Liner Pkr, 7-5/8" x 9-5/8" (3) Joints of 7-5/8",39#, P-110 w/ FL-4S Baker Hyflo 3D Liner Hngr Pkr, 7-5/8" x 9-5/8" 4,113' 9.55' 4,123' 131.24' 4,254' 10.50' ~ ~ 5 Baker 'K-22' Anchor Seal Assembly. (1.38' in pkr) 6 Baker 85FAB-47 Ret Production Pkr w/ MOE 7 Otis X Nipple 8 Baker 'K-22' Locator Seal Assembly w/o seals 9 Baker'SABL-3' Packer, 85SAB47X40. 10 Baker MOE, w/ XO 5" LTC x 4- Yz" Butt 11 Baker 'F' Nipple, 3.75" profile. 12 Baker 'F' Nipple, 3.75" profile. 13 Baker Hydrotrip Sub w/ WLEG 11, 0.76' 3.875" 5.500" 11, 4.000" 5.860" 1 4.49' 11,994' 6.53' 12,033' 1.28' . 12,055' 1.27' 3.750" 5.250" 12, 1.46' 3.937" 5.600" 14 Baker 'F-1' Packer, Size 85-40. 13,190' 15 Baker MOE w/ XO 5" LTC P x 4-1/2" Butt 13,194' 16 Baker 'F' Nipple, 3.68" profile. 13,235' 17 Baker 'R' Nipple, 3.68" /3.625" w/ WLEG 13,270' 3.625"1 ~I G-ZONE G-2 12,340' 12,360' G-2L 12,386' 12,452' G-3 12,518' 12,568' G~ 12,676' \.:J~12,859' G-5 12,869' 12,932' HEMLOCK HB·1 13,207' 13,227' 20 HB-1 13,229' 13,249' 20 ~ 20 66 50 80 29 63 4-1/2" 4-112" 4-1/2" 4-1/2" 4-1/2" 4-1/2" 60 60 60 60 60 60 7/1/1992 7/1/1992 7/1/1992 7/1/1992 7/1/1992 7/1/1992 4 4 4 4 4 4 : 1 60 l HB-3 13,429' 13,499' 70 12/21-27/02 HB-3/4 13,460' 13,490' 30 12121-27/02 HB-4 13,520' 13,570' 50 12/21-27/02 13,599' 13,629' 30 12/21-27/02 HB-5 13,689' 13,709' 20 12/21-27/02 HB-5/6 13,758' 13,818' 60 12/21-27/02 WEST FORELAND 1~ 2-7/8" 6 60 7/2/1992 14,620 WF-1 13,972 , 2-7/8 " 6 60 7/2/1992 WF-2 14,071' 2-7/8" 6 60 7/2/1992 WF-3 14,144 2-7/8" 6 60 7/2/1992 WF-4 14,244' 2-7/8" 6 60 7/2/1992 WF-5 14,384' 2-7/8" 6 60 7/2/1992 WF-6 14,490' 2-7/8" 6 60 7/2/1992 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \~ÇJ. -2.J ( P.I. Supervisor f\,e11 '"14' D6' DATE: Monday, February 28, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA M-30 TRADING BAY UNIT M-30 \q \--O~Y' FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -TS¿ Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT M-30 Insp Num: mitLG050226215302 Rei Insp Num: API Well Number: 50-733-20430-00-00 Permit Number: 191-064-0 Inspector Name: Lou Grimaldi Inspection Date: 2/25/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M-30 Type Inj. S TVD 8787 IA 400 2320 2300 2300 P.T. 1910640 TypeTest SPT Test psi 2196.75 OA 10 10 10 10 Interval 4YRTST P/F P Tubing 2650 2650 2650 2650 Notes: lA checked for fluid to surface. SCANNE[) MAR 11 2005 Monday, February 28, 2005 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: - 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 160' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska 99519-6247 Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 974' FNL, 520' FWL, Sec. 33 9N-13W-SM M-30 At top of productive interval 9. Permit numbedapproval number 1,264' FSL, 1,830' FWL, Sec. 21 9N-13W-SM 91-64 At effective depth 10. APl # 2,763' FSL, 2,092' FWL, Sec. 21 9N-13W-SM 50-733-20430-00 At total depth 11. Field/Pool MgAdhur River "G" Zone / W. Foreland 12. Present well condition summary Total depth: measured 14,620' feet PBTD 14,575' true vertical 10,686' feet Effective depth, measured 14,575' feet Junk (measured) true vertical 10,649' feet Casing Length Size Cemented Measured depth True vertical depth Structural 959' 26" DRIVEN 1,039' 1,039' Conductor 1,359' 16" 1866 Sx 1,439' 1,436' Surface 4,148' 13-3/8" 2423 Sx 4,229' 3,717' Intermediate 12,170 9-5/8" 2375 Sx 12,247' 8,950' Production 2,620 7" 650 Sx 14,003' 10,176' Liner 655' 5" 350 Sx 14,520' 10,596' Perforation depth: measured SEE ATTACHED true vertical Tubing (size, grade, and measured depth) 4.5" 12.6# L-80 Buttress AB Mod from surface to 12,083' & 4.5" 12.6~ from 13,190' to 13,271'. Packers and SSSV (type and measured depth) Baker permanent packers at 11,959', 11,990', & 13,190'. 13. Stimulation or cement squeeze summary ~E~) 0 ~' 2005 none Intervals treated (measured) Ale. Ska Oil & Gas Cons, Commissmr none Anchorage Treatment description including volumes used and final pressure none 14. Representative Daily Avera,qe Production or injection Data Od-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7740 BPD 340 3600 Subsequent to operation 11400 50 2700 15. Attachments: 16. Status of well classification as: Water Injector Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: R 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: L ~., [= ! V k ~ (J Alaska 0il & Gas ~ons. 60,,amlsslo ~..~.../~ ~.NNED F E B 1 (~ 2003 - Anchorage Form 10-404 Rev 0E, 5/88 FEB 6 2003 DUPLICATE Date 12/21/02 12/22/02 12/23/02 12/24/02 12/25/02 12/26/02 12/27/02 Daily Report of Abandonment Well Operations M-30 E-Line Operations to Add Perforations AFE #157644 12/21/02 - 12/27/02 Summary MIRU E-Line equipment. RIH & Fired gun #1 & perforated from 13,788' - 13,818' total 30'. RIH & Fired gun #2 & perforated from 13,758' - 13,788' total 30'. RIH & Fired gun #3 & perforated from 13,689' - 13,709' total 20'. RIH & Fired gun #4 & perforated from 13,599' - 13,609' total 30'. Shut down operations for holidays. Shut down operations for holidays. RIH & fired gun #5 & perforated from 13,550' - 13,570' total 20'. RIH & fired gun #6 & perforated from 13,520' - 13,550' total 30'. RIH & fired gun #7 & perforated from 13,460' - 13,490' total 30'. RIH & fired gun #8 & perforated from 13,429' - 13,449' total 20'. Well mined over to Production. &C;ANNED FEB 1 0 2003 MARATHON OIL CDHPANY TRADING BAY UNIT At[ mea~uremen~ ~pe RKB ~o ~op oF equipnen~. Cc~sln.q De±of( 16' 75# K-55 BO' ~439~ 13-3/8' 61~ K-55 81' 2,37U 13-3/8' 68~ K-55 ~371' 4,~4' 9-5/8' 47ff N-80 77' 1~,~47' 7' ~9~ N-80 11,383' 14,003' 5' 18~ N-BO 13,865' 14,6~0' Compl. e't ion ~ring, O' - 1~,068' 505' ILgOg' IL990' 11,994' 1~,033' 12.055' 12,066' [[06B' 4-1/2' 1EL6#, L-BO HMS 3u~ Tb9. IPC w/ TK-99 FMC H~ngep TCIAEN 4-1/E~' CS HYD Tx~ B~ke~ 'F' Nipple, 3.75' P~o~l[e )~ke~ ~K-22' Anchor Se~I Asse~bty B~kep 'SABL-3' P~cker, 85gABa7X40 B~ke~ H1Roui Exiens~on 5' LTC PxP B~k~p 'F' Nipple, 3.75' PPoCR~ Bcker 'F' Nipple, 3.75' PpoCRe ~kep Hydpoi¢ip Sub BokeP ~lreUn~ Entry 6uide Isola'tion P~cker 13,190' 13, i99~ 13,235' i3,~70' t3,271' Baker 'F-[' P~cker, Slze 85-40 Baker Mlttou~c Extension 5' LTC PxP X-O lo 4-1/~ 1;~.6~% L-80 HHS Butt Boker 'R' Nipple 3.68'/3.6~5' G-ZONE G-2 G-2L G-3 G-4 G-5 G-5 PERFDRATIDNS_ In't erval. FT Gun ~lze SPF Ph0.se_ D~li;e 12,340' - 1~,360' 20' 4-1/2' 4 60' 7/1/92 12,518' - 1~,568' 50' 12.596' - 1~,676' 80' 12,830' - ,1~,8~9~ 1~869' - 12,932' 63' 4-I/~' 4 60' 7/1/92 ~EST FORELAN~ 13,94I' - t3,960' 19' 8-7/8' 14,071' - 14,136' 65' t4,144' - t4,206' 6~' 14,~44' - 14,360' 116' 14,384' - 14,430' 46' 14,490' - 14,518' 28' 2-7/8' 6 60' ~/Fwl ~/F-1 ~/F-3 WF-4 WF-5 WF-6 71~192 PBTD e 1~575' TD e 1~71' SGANNED FEB t 0 2003 Revision Date~ 8/19/9~ Revised By, JCM/evo Reason, New Comp[etion Previous Reviston~ ' Well M-30 12/21/02 - 12/27/02 Perforations Added ZONE HB6 HB5 HB4 HB4 HB3 HB3 TOP 13,758 13,689 13,599 13,520 13,460 13,429 BOTTOM 13,818 13,709 13,629 13,570 13,490 13,449 Total SCANNED FEB 1 0 2003 FEET 60 20 30 5O 30 20 21o STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Oil Company of California (UNOCAL) Development:~ ,,,,~ 160' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: ,X ~ Trading Bay Unit 4. Location of well at surface 8. Well number 974' FNL, 520' FWL, Sec. 33 9N-13W-SM M-30 At top of productive interval 9. Permit number 1,264' FSL, 1,830' FWL, Sec. 21 9N-13W-SM 91-64 At effective depth 10. APl number 2,763' FSL, 2,092' FWL, Sec. 21 9N-13W-SM 50- 733-20430-00 At total depth 11. Field/Pool McArthur River "G" Zone / W. Foreland 12. Present well condition summary Total depth: measured 14,620' feet Plugs (measured) PBTD 14,575' true vertical 10,686' feet Effective depth: measured 14,575' feet Junk (measured) true vertical 10,649' feet Casing Length Size Cemented Measured depth True vertical depth Structural 959' 26" DRIVEN 1,039' 1,039' Conductor 1,359' 16" 1866 Sx 1,439' 1,436' Surface 4,148' 13-3/8" 2423 Sx 4,229' 3,717' Intermediate 12,170 9-5/8" 2375 Sx 12,247' 8,950' Production 2,620 7" 650 Sx 14,003' 10,176' Liner 655' 5" 350Sx 14,52~ E DLO,596' Perforation depth: measured ATTACHED ( EIVE true vertical ATTACHED NOV 2 22002 Tubing (size, grade, and measured depth) 4.5" 12.6# L-80 Buttress AB Mod from surface to 12,083' & 4.5" 12.6# from 13,190' to 1~ 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage Baker permanent packers at 11,959', 11,990', & 13,190'. 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 12/2/2002 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,~, '~ ~'~~~~--~' Title: Workover Foreman / Engineer Date: 11/22/2002 - Steve Tyler J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness'l,~,pproval No. Plug integrity.~ BOP Test Location clearanceI ~ ~" Mechanical Integrity Test Subsequent form required lo- 'CANNEDDEC 1 ~ 2002 Approved by order of the Commissioner M L. ~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NOV 2 7 2O02 Perforations to be Added ZONE TOP BOTTOM HB6 13,758 13,818 HB5 13,689 13,709 HB4 13,599 13,629 HB4 13,520 13,570 HB3 13,460 13,490 HB3 13,409 13,449 Total FEET 60 20 30 50 30 40 230 SCANNED DEC 1 ~ 2002, MARATHON OIL COMPANY TRADING t~AY UNI]; ~ELL At( meo`zupemen.ts ore RKB .to .top of equipmen~ 16' 75# K-55 BO' ~439' 13-3/8' 13-3/8' 68~ K-55 ~371' 4,~4' 9-5/8~ 47ff N-80 77' 1~,~47' 7' ~9~ N-80 11,383' 14,003' 5' 18W N-80 13,865' 14,6E0' Co~pl, ei:!on O' - le,068' 4-1/~' 1~.6#, L-80 ~M~ 3u~ Tb9. IPC w/ TK-99 74' FMC Honger TC]AEN 4-1/~' CS HYD 505' 3¢kep 'F' Nipple, 3.75~ 1~,990' ~ker 'S~BL-3' P~ckep, 85~AB47X40 ID994' B~kep MiRou~ Extension 5' LTC PxP 1~,033' ~k~r 'F' NipPle, 3.75' 1~055' Boke~ 'F' Nipple, 3.75' i~066' ~ker Hy~ro~rip Sub 1~068' Boke~ WlreU~e Entry 6ul~e Isolol:ion P0~c h:er I30190' Bnke. r 'F-I' Po`cke.r, ~ize. 85-40 t3.,194' Boker Hillou-t Ex-I;ensJor~ 5' LTC PxP : 13,199' X-t:] 'to 4-1/2', 1~.6~., L-80 NMS Bu't't 13,~35' B<iker 'F' Nipple. 3.68~ Pro-f Re 13,~70' ]~0. ker 'R' Nipple 3.68"/3.625' 13,271' Bo. ke.y' Wir"eUr're £n'l;ry Guide' WEST FORELAND WF-! 13,941' - 13,960' WF-I 13,97~' - i4,04~' WF-2 14,071' - 14,136' WF-3 14,144' - 14,206' WF-4 14,~44' - 14,360' WF-5 14.384' - /4,430' WF-6 14,490' - 14,518' PE_RFORA___T__!!3N~ 20' 66' 50" 80' 63' Gun S~ze ~PE Phase D~l.te 4-//~' 4 60' 7/1/9~ 4-I1~" 4 60' 711/9R 19' 70' 65' GE' 116' 46' 28' ~.-7/8' G 60* 7/i3/92 2-718' 6 60 Re.vision I)<l't e~ 8/19/9~ Revised :By, JCH/evo PBTD e 14,575' Re(is:on, New Cor,,pie'l;ion ' CANNED 2002 TD 15,~71' ~r~Ge~ouz Revistonm RE: M-30 Hemlock Perforations Subject: RE: M-30 Hemlock Perforations Date: Tue, 26 Nov 2002 09:28:37 -0800 From: "Tyler, Steve L" <tylersl@unocal.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> Hey Tom This is what we have for the history. Steve Tyler Workover Foreman / Engineering Tech Unocal Alaska (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder~.admin.state.'ak, us] Sent: Monday, November 25, 2002 5:02 PM To: Steve Tyler Subject: M-30 Hemlock Perforations Steve, I was looking at your proposal. Has there been any work done on this this well recently?? Last think I show in the file was a workover in 96. I presume that all the G zone and West Foreland perfs are still there as well. Thanks. Tom M-30 Hist 2-5-97 doc Type' WINWORD File (application/msword)i! /Encoding' base64 DEC 1 9 200 1 of 1 11/26/2002 8:48 AM LAST WORK: Date 1992 4/2 6/2O 7/1-2 7/5-7 9/1 10/6-7 1994 1995 1996 STEELHEAD PLATFORM APl # 50-733-20430-00 TBU M-30 WELL HISTORY 2~5~97 Action Spud Perforated from 12,997-12,999' and squeezed 3.5 bbls. of cut. into perfs. Perforated G-Zone, 4HPF, with 4 1/2" TCP Guns: G-2 12,340-360' 20' G-2 12,386-452' 66' G-3 12,518-568' 50' G-4 12,596-676' 80' G-5 12,830-859' 29' G-5 12,869-932' 63' 308' Perforate West Foreland, 6HPF, with 2 7/8" TCP Guns: WF-1 WF-1 WF-2 WF-3 WF-4 WF-5 WF-6 13 941-960' 13 972-042' 14 071-136' 14 144-206' 14 244-360' 14 384-430' 14.490-518' 19' 70' 65' 62' 116' 46' 28' 406' Ran 4 1/2" 12.6# L-80 tbg. to 12068' with Baker SABL-3 pkr. set at 11990' and Baker isolation F-1 pkr. set at 13190. Completed as a water injection well. As a result of injection profiles run in October 1992, the injection allocations were revised. Resv. Prior Allocation New Allocation G-Zone 43% 19% W. Foreland 57% 81% Tagged Fill @ 14,537' Ran Injection profile log of G-zone/W Foreland. DEC 1 ~ 2002 6/3O 10/22-30 O - Well shut in due to casing annuli communication. High pressures were recorded in both the 13-3/8" X 9-5/8" and the 9-5/8" x 4-1/2" annulus. WO - Mechanically repair the leak from 13-3/8" X 9-5/8" annulus with an non- cemented scab liner assembly across leaking external csg pkr from 4,113' - 4,265'. Replaced the 4-1/2" tbg. 1997 1/26 GR - RIH W/3.50" GR and sat down at 11,966'. Worked tool pass restriction and tagged BTM @ 14,350' WLM. 2/5 SR - Water Injection Profile. Schlumberger Profile: Injection Profile at Surface Conditions: Perforated Water Water Interval Zone Interval BPD Cut % Percent G-2 12,340'-12,360' -0085 100 4.0 G-2L 12,386'-12,425' -0520 100 25.0 G-3 12,518'-12,568' -0185 100 9.0 G-4 12,596'-12,676' -0030 100 2.0 G-5 12,830'-12,859' -0110 100 5.0 G-5 12,869'-12,932' -1140 100 55.0 Total Surface Injection -2,095 100 100.0 During injection a pressure of 7,253 psi and temperature of 99 deg F was measured in "G" Sand @ 12,600 MD. The surface injection pressure measured during the survey was 3,377 psi with a rate of 6,960 BPD. During the shut-in survey a pressure of 5000 psi and a temperature of 108 deg F was measured in the "G" Sands at 12,600 MD. No Cross flow was detected during shut-in survey. Shut-in temperature survey indicated no channeling above or below "G" Zone perfs. Injection Profile at Surface Conditions: Perforated Water Water Interval Zone Interval BPD Cut % Percent WF-1 13,941 '-13,960 -0100 100 2.0 WF-1 13,972'-14,042' -0140 100 3.0 WF-2 14,071 '-14,090' -0490 100 9.0 WF-3 14,144'-14,206' -0000 100 0.0 WF-4 14,244'-14,290' -0200 100 4.0 WF-4,5,6 14,292'-14,518' -4665 100 83.0 Total Surface Injection -5,610 100 100.0 5GANNED DEC 1 )2002 During injection a pressure of 7,755 psi and temperature of 102 deg F was measured in West Foreland Sands at 14,200 MD. The surface injection pressure measured during the survey was 3,377 psi with a rate of 6,964 BPD. During the shut-in survey a pressure of 5,530 psi and a temperature of 101 deg F was measured in West Foreland Sands at 14,200'. No cross flow or channeling indicated above top perfs. ON OR BEFORE NOVEMBER 2 E E W C:Lo~MF1LNI-DOC THIS M STATE OF ALASKA .... ALASKA O, -AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: 160' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 Anchorage, AK 99519--0247 Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 974' FNL, 520' FWL, Sec. 33 9N-13W-SM M-30 At top of productive interval 9. Permit number/approval number 1,264' FSL, 1,830' FWL, Sec. 21 9N-13W-SM 91-64 At total depth 10. APl number 2,763' FSL, 2,092' FWL, Sec. 21 9N-13W-SM 50-733-20430 11. Field/Pool McArthur G Zone / W. Foreland 12. Present well condition summary ,-.--' Total depth: measured 14,620' feet Plugs (measured) PBTD 14,576' true vertical 10,686' feet Effective depth: measured 14,575' feet Junk(measured) ORIGINAL true vertical 10,649' feet Casing Length Size Cemented Measured depth True vertical depth Structural 959' 26" DRIVEN 1,039' 1,039' Conductor 1,359' 16" 1866 Sx 1,439' 1,436' Surface 4,148' 13-3/8" 2423 Sx 4,229' 3,717' Intermediate 12,170 9-5/8" 2375 Sx 12,247' 8,950' Production 2,620 7" 650 Sx 14,003' 10,176' Liner 655' 5" 350 Sx 14,520' 10,596' Perforation depth: measured ATTACHED true vertical Tubing (size, grade, and measured depth) 4.5" 12.6# L-80 Buttress AB Mod from surface to 12,083' & 4.5" 12.6# from 13,190' to 13,271'. Packers and SSSV (type and measured depth) Baker permanent packers at 11,959', 11,990', & 13,190'. RECEIVED 13. Stimulation or cement squeeze summary Scab liner assembly (Non-Cemented) set across leaking External Casing packer from 4,113' - 4,265'. NOV ,5 1996 Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 011 & Gas Con~. Commission Anchorage 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation BWIPD 8300 1160 3714 Subsequent to operation BWIPD 8210 0 3411 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: /~ G.~ ~,[ ~ Dale Haines Title: Drilling Manager Date: 11118/96 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Saturday, November 02, 1996 STEELHEAD WELL # 30 ~ ! -O 6~[ MIT FOR WATER INJECTION REPORT TEST DATE 10/31/96 PBTD = 14575 (10646tvd) 5"- 18~ N-80 LINER 14620 (I 0682) TO 13865 (10079) 7" 28~ N-80 LINER 14003 (10186) TO 11083 (8222) 9 5/8" 47# N-80 SHOE AT 12247 (8967) 13 3/8" 68# SHOE AT 4224 (3728) INJECTION PACKER SET AT 11~4~dpm (8773) 4 1/2" 12." L-80 MMS BU~ INJECTION STRING z57, ISOLATION LINER INSTALLED DUE TO LEAK IN 9 518" CSNG FROM 4264 TO 4113md PRESSURE TEST FOR 40rain APPLIED PRESSURE TO 9 518 BY 4 1/2 ANNULUS WITH 4 1f2" TUBING OPEN AT SURFACE MONITORED 13 3/8 BY 9 518 ANNULUS WITH PRESSURE GAUGE PRESSURES BEFORE TEST =13 3/8 BY 9 5/8" 175psi , 9 5/8 BY 4 1/2 = 0psi , 4 112' OPEN AFTER PRESSURE UP = 13 3/8 BY 9 5/8 = 590psi. 9 5/8 BY 4 1/2 = 2722psi, 4 1/Z' OPEN AT END OF 40min TEST = 13318BY95/8=610psi,9518BY4112=2715psi,41/2"OPEN CHART OF TEST IS ATTACHED IF MORE INFORMATION IS REQUIRED PLEASE CONTACT MR. DAN WILLIAMSON AT (907) 263-7677 OR MYSELF AT 263-7861 THANKS EVAN K. HARNESS , 1~:35PM GRAMITE PT DRILLIMG ~Y Y'K~ ~bb IMU. rb~ MO¥. ~.1996 RECEIVED MOV. ~. 1~96 1~:36PM GR~MITE PT DRILLTMG ~0'~ '~'K~ I~u. ro~ . MOV. 2.1996 12:37PM GRAM PT DRILLIMG 907 776 . HOV, ~.1996 l~:38PM Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNO .AL Dale Haines Drilling Manager Thursday, October 3, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell' Steelhead Platform M-30 Unocal is submitting a Sundry 10-403 form for well work on Steelhead Platform well M-30. Well M-30 is a G-Zone and West Foreland water injector that has deleloped a leak from the 4-1/2" tubing to the 9-5~8" casing annulus. In addition, pressure was communicated to the 9-518" to 13-318" annulus. The scope of the workover is to identify and mechanically repair the communication from the 9-5~8" to 13-3/8" annulus and replace the 4-1/2" tubing. The well will be returned to injection after the workover. If you have any questions, please contact the undersigned at 263-7660 or Dan Williamson at 263-7677. Sincerely, Dale Haines Drilling Manager GRS/leg RECEIVED OCT 0 8 ~9~ Alaska 0il & G~.s Cons. Commission Anchor~,9~ '-" STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1.' Type of Request: Abandon: Suspend: O[~eration shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tu~ing: Variance: Perforate: Other. 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 160' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO Box 190247 Anchorage, AK 99619-0247 Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 974' FNL, $20' FWL, Sec. 33 9N-13W-SM M-30 At top of productive interval 9. Permit number 1,264' FSL, 1,830' FWL, Sec. 21 9N-13W-SM ~ At total depth 10. APl number 2,763' FSL, 2,092' FWL, Sec. 21 9N-13W-SM 50-733-20430 11. Field/Pool McArthur River "G" Zone I W. Foreland 12. Present well condition summary Total depth: measured 14,620 feet Plugs (measured) PBTD 14,$7p~ E C E IV true vertical 10,686' feet Effective depth: measured 14,675' feet Junk (measured) () C T 0 8 true vertical 10,649' feet · Alaska0il & 6~s Co~s. Commission casing Length Size Cemented ~easureddepthAllCh0r~.gO True vertical depth Structural 959' 26" Driven 1,039' 1,039' Conductor 1,359' 16" 1866 Sx 1,439' 1,436' Surface 4,148' 13-318" 2423 Sx 4,229' 3,717' Intermediate 12,170' 9-518" 2376 Sx 12,247' 8,950' Production 2,620' 7" 650 Sx 14,003' 10,176' Liner 655' 5" 350 Sx 14,520' 10,696' AP;arf~:hr~tei~n depth: measured 0 Ri GIN A L true vertical Tubing (size, grade, and measured depth) 4.6" 12.6# L-80 IPC from sur - 12,093' & 4.$" 12.6# L-80 FROM 13,190' - 13,271" Packers and SSSV (type and measured depth) BAKER PERMANENT PACKERS SET AT 11,990' AND 13,190' 13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: October 21st, 1996 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,~¢.~ ~,~ ~'"~-" Dale Haines Title: Drilling Mangaer Date: 2-Oct-96 FOR COMMISSION USE ONLY Conditions of approval:Plug integrityN°tify Commission ,o representative may witneSS, o, Test [/" Location clearance IAppr~°~'a' '"N°?~' Mechanical Integrity Test Subsequent form required 10- ~ 04 Original Signeo David W. Johnston Approved by order of the Commissioner Commissioner Dat Form 10-403 Rev 06/15188 Apprmred COpy ReturRed SUBMIT IN TRIPLICATE 12,340 - 12.360 12,388 - 12.452 12,518 - 12,568 12,5,96 - 12,676 12,830 - 12,859 12,869 - 12,932 M-30 PERFORATIONS G-ZONE TVD 9,026- 9~34 9,0S6 - 9,097 9,140- 9,171 9,169- 9241 9,341- 9.366 - 9.4,10 Gun Size SPF 4-1/2' 4-1/2' 4-1/2' 4-~/2' 4-1/2' 4-~/2' MD 13,941 - 13,960 13,072 - 14,042 14,071 - 14,136 14,144 - 14,206 14,244 - 14.360 14,384 - 14,430 14,490 - 14,518 WEST FORELAND 10,138 - 10.152 10,162 - 10217 10,240 - 10~92 10,298 - 10~48 10~78 - 10,472 10,492 - 10529 10~79 - 10,601 ~ SPF 2-7/8' 6 2-7/8' 6 2-7/'8' 6 2-7/8" 6 2-7/8' 6 2-7/8' 6 2-7/8' 6 M-30 WorkoVer Procedure 10/2/96 o 10:36 AM Page- 1 PROPOSED WORKOVER STEELHEAD M-30 STEELHEAD platform well M-30 is a Tyonek and West Foreland water injector. The well is shut in due to casing annuli commumcation. On June 30, 1996, high pressure was noted on the 4-1/2" by 9-5/8" annulus and from the 9-5/8" by 13-3/8" annulus. PREP WELL FOR WORKOVER: NOTE: . . . . . . . 10. Check and bleed pressure from 26" x 16", 16" x 13-3/8", and 13-3/8" x 9-5/8" casing annuli. Record pressures and build up information on mormng report. SCSSV should be isolated with an auxiliary pressure source prior to commencing downhole operations to prevent wire cutting in the event of a Platform ESD. Take SCSSV off platform system and isolate with hand pump with control line pressure set at 3,800 psi. Fusible cap to be installed on master manumatic valve. RU slickline. Pressure test to 2,500 psi. Measure up 2.80" gauge ring. RIH gauging tubing to a minimum depth of 12,000'. POOH and RD slickline. Skid rig over well. RU hard lines to casing annulus and line out to choke mainfold. Pressure test to 80% of working line pressure. RU E-Line unit, lubricator, and BOP's. Pressure test to 2,500 psi. Establish UNOCAL's Safeguards for handling explosives, MU 5' of 1-9/16" 4 spf tubing puncher. Record pressure and RIH Perforate the tubing from 11,970' to 11,975'. POOH with tubing punch and verify all shots fired. RD E-line. Circulate kill weight brine down tubing taking returns from the 4-1/2" by 9-5/8" annulus. Hold sufficient back pressure to prevent well from flowing. Monitor well for 20 minutes. Note: BHP is approximately 4,700 psi at 9,450' TVD datum. Equivalent mud weight is 9.56 ppg. RU BPV lubricator. Pressure test to 2,500 psi. Set a 4-1/2" nominal Cameron Type "H" BPV in profile. RD Lubricator. ND production tree and flowlines. Blind flange flowlines per UNOCAL lock out tag procedure. NU BOP's. Pull BPV and set two way check valve. Pressure test BOP high low to 2500 psi/250 psi. Pull two way check valve. Measure up 4-1/2" EUE 8 md landing joint and engage hanger. Back out hanger hold down screws. PU hanger for 200,000 # string weight. Rotate tubing 15 roms to the right at 12,000' to release K-22 anchor seal assembly. Unseat from seal assembly and circulate bottoms up. POOH laying down 4-1/2" 12.6# buttress tubing. Thread protectors to be installed and the pipe send to Tuboscope for inspection. Check tubing for NORM with a Geiger counter. RECEIVED OCT 0 8 iDgG Alaska Oil & ~s Cons. Commission M-30 Workov~r Procedure 10/2/96 - 10:36 AM Page - 2 11. PU 6" junk mill with large TFA and casing scrapers dressed for 7" 29# and 9-5/8" 53.5# in combo. TIH to 7" packer assembly at 11,990'. Circulate HI-VIS sweeps as required to clean hole. POOH. 12. PU a molded seal unit, 10' pup joint, 4-1/2" X-nipple (3.813" PB), 10' pup joint, and a 7" x 4" bore permanent packer dressed for 7" 29# casing on drill pipe with a PX plug and prong installed. 13. RIH and engage molded seal umt in seal bore at 11,990'. Set the permanent packer with the molded seal engaged. Release from the packer and POOH. 14. PU a RTTS packer dressed for 9-5/8" 47# to 53.5# casing. RIH testing casing to 2,000 psi at 4,142' and 4,226' ( 25' above and below ECP). Proceed with testing as required to isolate any casing leaks. NOTE: A USIT from Schlumberger will be utilized as a contingency if casing integrity is of concern. 15. Run Baker JF-3D isolation straddle assembly. a) Pick up Baker Oil Tools 3D liner Hanger / Packer and make up on the bottom of the 1st joint of 7" 29# casing. b) While hanging in the elevators, check movement of slips and cage of the 3D. c) RIH with required amount of casing to cover leak(s). d) Pick up IF Liner / Packer with hold down slips. Make up to last joint of casing and inspect. Note: Running tool has been made up in the Baker shop. e) RIH to depth slowly on drill pipe with sufficient collars to provide 45,000 # slack off weight. At setting depth, rotate the string 1/2 turn to the left at the tool to set the 3D liner hanger packer and slack off 40,000# at the tool to set the pack-off. g) Rotate the string 12 tums downhole to release the setting nut of the C-2 running tool. h) Pick up 7' maximum at the tool to engage the IF setting lock. i) Slack off 25,000# at the tool to set the packoff and engage the slips of the IF packer. Pressure test down work string to test up against bottom packoff of scab isolation liner. Bleed off pressure. Close BOPs or Hydrill and pressure test upper packoff of scab liner. Bleed pressure to 0-PSI. Pick up 8,000# over string weight to release setting sleeve from packer. POOH with drill string and running tool. j) k) 16. 17. 18. 19. Pressure test 9-5/8" casing to 3,000 psi monitoring the 9-5/8" by 13-3/8" annulus. PU the completion assembly as noted On attached proposed well bore completion. RIH with assembly internally pressure testing to 5,000 psi every 5 joints. Establish circulation at minimum rate at 11,970'. RIH with assembly until seal umt engages seal bore as noted by pressure increase. PU assemb .ly 5'. Circulate well to 20 NTU's with no visible settling after 15 minutes. Reverse circulate corrosion inhibitor to seal assembly. OCT 0 8 Alaska Oil & C-~ Co.~s. Commission M-30 Workover Procedure 102 96- 10:36 AM Page ~- 3 20. Space out assembly for neutral string weight with seals fully engaged and make up redressed hanger assembly. Land completion and secure with hold down pins. Pressure test 9-5/8" by 4- 1/2" completion to 3,000 psi and monitor tubing for communication. 21. RU slickline. Measure up 2.80" Gauge ting. RIH and drifting tubing to PX plug and prong. POOH and RD slickline. 22. Set a Cameron 2-way check. 23. ND BOP's and riser. 24. 25. 26. NU adapter flange and tree. Test al1 voids and seals individually to 5,000 psi. Pressure test tree to 5,000 psi. RU slickline and pressure test to 2,500 psi. RIH and pull PX prong and plug set in the X-nipple. RD slickline. Release Drilling rig. Skid rig over M-29. All ~eosuremen~s Gte RKB *o *op of' equipment, CGslnq De*ell 16' 75# K-5§ 80' L439° 13-3/8' 61t K-55 81' E, 371' 13-3/8' 68# K-55 ~,371' 4,224° 9-5/8' 47~ N-O0 77' 1~47' 7' ~9~ N-BO 1~383' 14,003' 5' 18t N-80 13,865' 14,620' Cono(e tlon Strlnq_ ~ 0' - 12.,068' 74' 505' IL989' 11,990' ll,994' IE.033' 1~,055' 12.066' 1~068' 4-1/2' 12.61L L-80 HMS Butt Tbg. IPC w~ TK-99 FMC Hanger TC1AEN 4-1/2' CS HYD TxB B~ker 'F' Nlppie, 3.75' ProfAe ~ker 'K-2E'. Anchor Seol Assen~y~ Boke~ 'SA~-3' Pocke~, BS~AB47X40 ~ker Hitlout Extens~n 5' LTC PxP B~ker 'F' ~ppie, 3.75' Pro,Re B~ker 'F' ~ppie, 3,75' ProfRe 9~kep Hydrot~ip Sub B~ke~ W~et~e Entry O~de lsototlon P~cke~ 13.190' 13.194' 13.199' 13~35' 13,270' 1~271' 6-ZONE 6-E G-EL 6-3 6-4 Baker 'F-I' Packer, Size e5-40 ]~aker Hillout ~x~efls~ 5' LTC PxP ~Qke~ 'F' ~p~e 3.68' B~ker V~elHe Entry 1~,340' - 17360' 20, 1~,386' - 120452' 66' 12o518' - 17,568' 50, 1?.$96' - 17.,676° 80' 1~,830' - 1E,859' 12,869'- 1~93~' 63' ~ SPF_ Phase Da*e 4-1/2° 4 60' 7/1/92 4-1/2' 4 60' 7/1/92 ~/EST FOR£LAND VF-I VF-I VF-2 VF-3 VF-4 VF-5 VF-6 13,941' - 13,960' 13,972' - 14J)42' 14,071' - 14,136' 14,144' - 14~06' 14~44' - 14~60, 14,384' - 14,430' 14,490'- 14,518' 19' 70' 65' 62' 116' 46' 2-7/8' 6 60' 7/2/92 2-7/8' 6 60' 7/2/92 PBTD TD 14,575' 15,271' Revision i~t~, 8/19/92 Revised 9~ JCH/evo Re~sor~ New Coflp(etiofl Previous RevlsiorY Flow Line Hy~rtl 16-3/4' 5000 Type GK Annul&r Kill Line 1 10,000 os" OOUtlleqate C~e.,X Valve Valve Gate Valve PIPe Rems Rams Gate Valve HGR Valve Choke U~. 16-8/4' I0,000 $1nqlegate RECEIVED OCT 0 8 011 & ~,.s Cons. 16-~14' 5000 Oil RItIf STEEL.HEAD PLATFORM Preventer Schematic Ball Valve Wellltealt STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS B~STER TO DERRICK VENT t CHOKE LINE SWACO SECTION AA O CENTRIFUGE MUD CLIANEII PIT O 8UCTION PIT l.tl lib/Ill DEIANDER II1 Bile Cci I.l t 0 0 0 RESERVE PiT '10t Bile Cep 4.11 IIWll/lll MIX PIT II Ibis Cell ~.~ I' PILL PiT I0 Iblo Cop t.Jl Bills DESAHDER PIT 113 Iblo I.ll Ildl/ll MUD CLEANER PIT lOS Ib~. Cop l.OS IWlo/kl 0 ' 0 0 CEHTRIFUGE lilt I00 Ilkfo O.OP OMo/I. SUCTION PIT · I ~2o Bble Cml) ~.O6 Bbl./la MUD RETURN DITGN EOUALIZEN i :. · AGITATOR MUD GUN STEELHEAD PLATFORM MUD PIT LAYOUT PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date: 06/13/94 RUN DATE_RECVD 91-064 BHC/SL/GR 91-064 CBT 91-064 CCBT-VDC 91-064 CET 91-064 CET 91-064 GCT 91-064 GR/CCL 91-064 GR/CCL 91-064 MUD 91-064 MUD 91-064 PIL/SFL 91-064 407 91-064 DAILY WELL OP 91-064 SURVEY 91-064 DRY DITCH 91-064 5377 91-064 5378 L 12294-14328 L 11990-14558 L 11383-13090 L 11300-13680 L 11383-13090 L 0-14515 12000-12250,BLUELINE ONLY 1 13350-13800,BLUELINE ONLY 1 1049-14620, MD 1049-14620, TVD 12234-14362 1 COMP DATE: 07/07/92 04/02/92-07/07/92 0-14575. GCT 1050-14620, SS#849 12102-14440. OH-BCH 1 0-14575, GCT 1 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/08/92 09/10/92 09/10/92 09/08/92 07/23/92 09/08/92 09/08/92 Are dry ditch samples required? yes (n~o/ And received? ~~/~ Was the well cored? yes.Analysis & description received?' '- ~ -~yes~ Are well tests require~es ~Received? yes~ Well is in compliance'-X~\ Initial COMMENTS Unocal North American--~_. Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) October 15, 1992 Alaska Region To: Larry Grant Alaska Oil & Gas Consen/ation Commission From: Kirk Kiloh~ ~/.-- ~¢ {/' In response to your request for sepia copies of CCL-GR Logs run in TBU M-30 on 6-30- 92 and 7-1-92, Unocal, as Unit Operator for TBU, is unable to submit the sepias inasmuch as the films were destroyed shortly after the logs were run. In addition, no backup sepias were even reproduced. For your information, these types of logs are generally run for tie-in purposes when completing a well and have a very short life in our files and at the rig. As for the Nicoli Creek #4 logs, specifically the CCL-GR, Bond Log, and perf record which were run in September 1991, Unocal will be unable to provide sepias of these for the same reason as above; the films were destroyed and no backup sepias were made. In regards to the status of the sepias for MGS 17595 #18 SBT/PDK-100 logs you should contact Ron Kies here at Unocal in Anchorage. Ron is the Development Geologist responsible for that field. KDK:sr RECEIVED 0C~' 1 6 1992. Alaska 0il & Gas C0r~s. Commission Anchorage Unocal North America- Oil & Gas Division · -'~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL, Alaska Region DOCUMENT TRANSMITTAL September 9, 1992 TO: Larry Grant FROM: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION Kirk Kiloh P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION fi?a?-' ,9"~' Transmitting as Follows: Marathon Trading Bay Unit M-7 and M-30 1 blueline and sepia each on a combined 2" and 5" presentation Phasor Induction-GR Natural Gamma Ray Lithodensity Raw Data Dipole Shear-GR and Dipole Shear Image Log Lithodensity - Compensated Neutron-GR Dipole Shear-GR with P & S Delta T Log 1 sepia and blueline each of: Mudlog Meassured Depth Mudlog Tree Neutral Depth 1 LIS Tape and Listing of CDT/CNL/DTE/NGT/DSI 2 GCT Directional Hard Copies 1-3 1/2" floppy of GCT Survey Washed and dried cuttings will be sent to you when Unocal receives such from the suboperator. Trading Bay Unit M-30, Marathon Operated / Requested second hard copy of GCT Survey,-'" PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUME~ TRANSMITTAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED BY: ~~,-~ ~---,_~-' DATED: RECEIVED S£P 11 1992. Alas~ Oil & Gas Cons. Commission Anchorage STATE OF ALASKA, 0RI INAL ALASKA OIL AND GAS CONSERVATION COMMISSIOtt]F/. "WELL COMPLETION OR RECOMPLETION 1. Status of Well OIL F-~ GAS ~ SUSPENDED ~ ABANDONED ~ A ...... ~ W~I~r: ~{~ ~C~]~R ~ " :.N~mg~A~'°(Narathon 01] Co, Sub-operator) '-I~r~5i I~'~mi'-Numb~r~ 3:~ ~2 ~ i~7 Anchorage, AK 99519 pl,f~n,=....~.=,~~.~~ ,. ~oca,~o. o~ ~em, ~,,.~f~e I "9 B], Slot 9 Stee!head ....... 974' FNL, 520' F~L, Sec. 33 9N-13~-SH {~_~/~/~ ~o.--We.,T~"'~LA~,~"~ ~,,__~ ~-~+ ..... ._ At Top Producing Interval 1,264' FSL, 1,830' FWL, Sec. 21 9N-13W-SM 9,7~I' FKm, 9,OQ9' KWL Set 21 9N-~qu-~u 5. ~le~,TioA i~See~ ii~di~ate~B, ~, e~J.f' ' ] ~. L~,s~ D~i~n%t~J~ ~V S~ ~o. McArthur Ri ver "G" Zone/West Foreland 160' KB above MSL ~ ADL 18730 12, DateSpudded ~13. Datel.~.Beached [~4. ~ate¢o~o.,S~s~.orAba~d. ~l[.~ater ~epth, ifoffshore [l¢.S¢,of~omo'otions ~/9/~9 I ~/91 /~9 ~ 7/7/a2 I .~_~*~etus~ I 1 17. TotlI/D~¢t~MD+TVD) 118.PI~a~e~th(M~WD)) 19.~i{e[~io~alSurvey ) 20. Depth where S~J set 21.' Thickness of Permafrost 1~ ~2~m ~ 1~ ~' 1~ ~7~m ~ 1~ ~o,YES~ NO~ { ~/~ feetMD M/A DIL/GR/SONIC/AMS GR/CBT GR/CCL/CET 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 13-3/8" 9-5/8', 7" WT. PER FT. 75// 61/68// 47// GRADE K-55 K-55 N-80 29// SETTING DEPTH MD TOP BOTTOM 80' 81' 77' 1,439' 4,229' 120247' 14,003' 14,~20' N-80 5" 18// N-80 11,383' 13,865' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) HOLE SIZE 22 ii 17.5" 12.5" ,5II CEMENTING RECORD 1866 Sx Cmt , 2423 Sx Cmt 2375 Sx Cmt 650 Sx Cmt 25. SIZE 26. ,5II 4,5" 350 Sx Cmt TUBING RECORD 11 27. SEE ATTACHMENT Date First Production AMOUNT PULLED DEPTH SET (MD) PACKER SET (MD) 0 - 113,190-13;271' 13;lg0 ACID, FRACTURE, CEMENT SQUEEZE, ETC. N/A N/A N7A N/A N/A DEPTH INTERVAL (MD)1 AMOUNT& KIND OF MATERIAL USED 12,g97 - 12,g~g' 160 Sx £mt t' · 07/09/92 Date of Test Hours Tested 07/24/9: 24 Flow Tubing Casing Pressure Press. 3260 270 28. PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR JO, L-BBL I GAS-MCF J WATER-BBL TEST PERIOD J~ N/A N/A g, 780 2q-HOUR RATE N/A , N/A 9,780 CORE DATA ICHOKESIZE JGAS-OIL RATIO N/A NA JolL GRAVITY-APl (corr) · N/A . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVFD .... , Alaska 0il & Gas <;c, ns. Anchorac{~ Submit in duplicate Form 10-407 NAME G-Oil: Sands · Hemlock West Foreland GEOL~OGIC MARKL, ~ MEAS. DEPTH 12,239' 13,144I 13,877' TRUE VERT. DEPTH 9,080' 9,713' 10,251' 30. , ,~,RMATION TESTS Include interval tested, pressure data, ali fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is 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 welt is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 MD 12,340 - 12,360 12,386 - 12,452 12,518 - 12,568 12,596 - 12,676 12,830 - 12,859 12,869 - 12,932 M-30 PERFORATIONS G-ZONE TVD 9,026 - 9,034 9,055 - 9,097 9,140 - 9,171 9,189 - 9,241 9,341 - 9,360 9,366 - 9,410 Gun Size 4-1/2" 4-1/2" 4-1/2" 4-1/2" 4-1/2" 4-1/2" SPF MD 13,941 - 13 13,972 - 14 14,071 - 14 14,144 - 14 14,244 - 14, 14,384 - 14, 14,490 - 14, 960 O42 136 2O6 36O 430 518 WEST FORELAND TVD 10 10 10 10 10 10 10 ,138 - 10 162 - 10 ,240 - 10 ,298 - 10 378 - 10 492 - 10 579 - 10 Gun Size SPF 152 2-7/8" 6 217 2-7/8" 6 292 2-7/8" 6 348 2-7/8" 6 472 2-7/8" 6 529 2-7/8" 6 601 2-7/8" 6 NELL M-30 Cas1 ng Record 16" Casing No Jts. Hanger 32 FL 1 FS 4/16/92 Wt. 75 75 Gr. K-55 K-55 Setting From 80.23 82.98 1394.95 1396.81 1438.28 Depth To 82.98 1394.95 1396.81 1438.28 1439.49 13-3/8" Casinq No Jts. 4/26/92 RKB - Casing Head FMC 13-3/8" Hanger 53 42 Float Collar 2 F1 oat Shoe Wt. 61 68 68 Gr. K-55 K-55 K-55 Setting From 0 78.71 81.47 2370.59 4133.63 4135.23 4222.00 Depth To 78.71 81.47 2370.59 4133.63 4135.23 4222.00 4223.80 9-5/8" Casin.q 5/28/92 No Jts. Wt. Gr. RKB Elevation FMC Hanger 94 47 CTC External Packer (43#) 49 47 21 47 118 47 Float Collar 3 47 Float Shoe L-80 L-80 L-80 L-80 L-80 Setting From 0 77.08 80.81 4167.37 4201.77 6308.62 7167.83 12117.49 12118.40 12245.36 Depth To 77.08 80.81 4167.37 4201.77 6308.62 7167.83 12117.49 12118.40 12245.36 12246.78 H: \wp\920E08\62. EVO Wel 1 )4-30 Casing Record -2- 7" Casing 6/12/92 Setting Depth No Jts. Wt. Gr. From To 1 11382.55 11402.09 14 29 N-80 11402.09 118B/.44 46 29 L-80 11887.44 13922.08 Landing Collar 13922.08 1392~.99 1 29 L-80 13922.99 13951.90 Float Collar 13961.90 13963.~ I 29 L-80 13963.72 14000.~ Float Shoe 14000.10 14003 5" Casing 6/17/92 Setting Depth No Jts. Wt. Gr. From To Hydrohanger 13865.13 138/8.41 16 18 N-80 13878.41 14537.04 Landing Collar 14537.04 14537~B8 i 18 N-80 14537.88 14b-/7.~ Float Collar 18 14577.22 14578.98 i 18 N-80 14578.98 1461781 Float Shoe 18 14617.81 1462D.00 * Verval approval to run 5" liner was given by Blair Wondzel, AOGCC on 6/12/92. H: \wp\920E08\62. EVO RECEIVED OPEI~T'rON S~Y REPOR_ 04/02/92 04/03/92 04/04/92 04/05/92 04/06/92 04/07/92 04/08/92 04/09/92 04/10/92 04/11/92 O4/12/92 04/13/92 04/14/92 I 0 2 0 3 0 4 0 5 0 6 0 7 0 8 0 9 0 10 0 11 1039 12 1039 13 1305 WELL: STEELHEAD N-30 8.400 9.000 9.000 9.000 9.000 9.000 9.000 9.150 PERFUitM RIG REPAIRS~ HAINTAINENCE AND INSPECTIONS.PREPAIR RIG FO~ SKIDDING. PERFORN RIG REPAIRS, HAINTAINENCE AND INSPECTIONS.PREPAIR RIG FOR SKIDDING. PERFORN RIG REPAIRS, HAINTAINENCE AND INSPECTIONS.PREPAIR RIG FOR SKIDDING. REHOVED TOP DRIVE MOTOR FOR REPAIR.PERFORMED RIG REPAIRS. gELDED ON STARTING FLANGE. FINISH WELDING ON STARTING FLANGE. HOVED EQUIPIdENT FROH SW NELL BAY TO NW NELL BAY. CONTINUED REPAIRS AND NAINTAI#ENCE. SKIDDED RIG OVER M-30. RIGGED UP AFTER SKID. INSTALLED TOP DRIVE HOTOR. INSTALLED TOP DRIVE HOTOR.NIPPLED UP DIVERTER SYSTEM . FINISHED NIPPLING UP DIVERTER SYSTEM. FUNCTION TESTED SANE. DIVERTER BAG k~:XJLD NOT CLOSE ON PIPE. P/U DRILL COLLARS AND HWDP. REHOVED LOCKING RINGS ON DIVERTER AND ATTENPTED TO REHOVE DIVERTER HEAD. HADE SEVERAL ATTEMPTS TO PULL HEAD OFF DIVERTER. FABRICATED THINNER LOCK RINGS AND USED HYDRAULIC PRESSURE TO REHOVE HEAD. FOUND RUST AND SCALE AROUND HEAD. NO VISIBLE DAMAGE TO PACKER. CLEANED HEAD, PISTON AND BOOY OF DIVERTER WITH WIRE WHEEL BRUSH. FINISHED CLEANING DIVERTER BOOY AND PARTS. PUT SANE BACK TOGETHER. FUNCTION TESTED DIVERTER. FOUND SC)HE ACCUHULATOR BOTTLES WITH PRECHARGES AND FIXED SANE. FOUND KR REGULATOR VALVE FUNCTIONING WHEN THE REHOTE HASTER BUTTON WAS PUSHED. TROUBLE SHOOT SANE. FOUND PIN CONNECTOR NOT MAKING CONTACT. ATTEMPTED TO FIX SANE SUCCESS. STARTED HARD WIRING THE LINES IN NW JUNCTION BOX. FINISHED HARDWIRING KOOHEY SIGNAL LINES FROM RIG FLOOR TO NW JUNCT ION BOX. FUNTIOR TESTED DIVERTER AND ALL REHOTES. RIH WITH 8 1/2" PILOT BIT AND DRILLED CEMENT PLUGS AND CLEANED OUT TO CBU. POOH. P/U 17 1/2" BIT AND RIH AND STARTED DRILLING CEMENT PLUGS. DRILLED CENENT PLUGS IN 26" CASING TO 567'. RIH, TAGGED CEMENT AT 1006'. CIRCULATED OUT 820 UNITS OF GAS. DRILLED CEMENT 1006' TO 1035 . CSU. POOH. P/U 20# UNDERREANER AND RIH. UNDERREANED CEMENT IN 26" CASING TO 540'. UNDERREAHED CEMENT IN CASING TO 1035'. CBU. POOH. P/U MUDIdOTOR AND DIRECTIONAL BHA. DIRECTZONALLY DRILLED AND SURVEYED ~FROH 1035' TO OPEI~TTON S~Y REPORt. WELL: STEELHEAD #-30 I : 1305'. 04/15/92 14 1452 9.100 DIRECTIONALLY DRILLED AND SURVEYED FROM 1305~ TO 1/~52'. CBU. SURVEY. POOH. P/U 22" UHOERREAtU~R. RIH. UNDERREAMED CEMENT IN CASING ANO OPEN HOLE FROM 1026e TO 131/,'. 06/16/92 15 145;> 9.150 UNDERREAMED 17.5# HOLE TO 22# FROM 131&' TO 1/.52m. MADE kllPER TRIP TO SHO~. CIRCULATED HOLE CLEAM.POOfl. RA# 33 dO%NTS OF 16" CASING.CBU. RA~ STAB IN CEMENTING STRING. 04/17/92 16 1/.52 9.150 RAN STAB IN CEMENTING STRING. CIRCULATEO AND RECIPROCATED CASING. CEMENTEO CASING WITH 1866 SACKS OF CEMENT. HELO PRESSURE ON ANNULUS WHILE klOC.LAYEO OOklg LANOING JOINTS ANO STARTEO N/O OIVERTER. 0/,/18/9;> 17 1452 9.150 NIPPLEO OOkgt OIVERTER SYSTEM. NIPPLEO UP UNIHEAD TESTEO.HIPPLEO UP RISER ANO BOP STACK.TESTEO BOPS. 0/,/19/9;> 18 1809 9.;>00 RIH AND TESTEO CASIHG TO 1850 PSI. DRILLEO OUT 16 I#CH CASING AND TESTEO SHOE TO 13.7' PPG EGUIVILEHT MUD klE%GHT.TRIPPEO FOR 12 1//* INCH BIT AND OIRECTIONAL BHA. DRILLED ANO SURVEYED FROM 1/~>2 TO 1809. 0~/20/92 19 31;>0 9.300 DRILLED AND SURVEYED FROM 1809 TO 29/*1.MADE klIPER TRIP. DRILLED AND SURVEYEO FROM 29/.1 TO 3120. 0~/21/92 ;>0 /*2/*7 9.700 DIRECTIONALLY DRILLED FROM 31;>0 TO /*2/,7. CIRCULATED HOLE CLEAN. TR I PPEO FOR UNDERREA~ER. 04/22/92 21 /*;>/*? 9.800 PICKEO UP 17.5" UHOERREAMER AND RIH TO 16" CAS%HG SHOE. UNDERREANED 1;> 1//*" HOLE TO 17.5" FROM 1/.39~ TO 2350' TAKING SURVEYS EVERY 300'. 04/23/92 2;> 42/*7 9.800 UNDERREAMED 12 1//*~ HOLE TO 17 1/;>'~ FROM 2350' TO 3370', TAKING CHECKSHOT SURVEYS EVERY 500'. 04/26/9;> 23 /*2/*7 9.750 UNDERREANEO 12 1//*" HOLE TO 1i' 1/2" FROM 3370* TO /*2/*7', TAKING CHECKSHOT SURVEYS EVERY 500~. CSU. DROPPED SURVEY. STARTED SHORT TRIP TO SHOE. 0/,/;>5/9;> ;>/* /*;>/*7 9.800 PULLED INTO CA$IHG AND REAMED F/C AND F/S. CBU. SURVEYED. CIRCULATED AND CONDITIONED MUD.POOH. PULLED klEAR BUSSHING, klASHED U#IHEAD. CHANGED PANS TO 13 3/8.SET klEAR SLEEVE.ATTEMPT TO TEST LAND HANGER. klEAR SLEEVE CRIMPED, REPAIRED SANE. TEST LANDED HANGER. R/U AND STARTED RUNNING 13 3/8~e CASING. 04/26/92 25 /*2/*7 9.750 RIH klITH 13 3/8" CASING. CENTRALIZERS HANGING UP. POOH AND REPLACED CE#TRALIZERS. RUN 13 3/8" CASING AND LANDED SANE. CIRCULATED AND CONDITIONED MUD klHILE RECIPROCATING PIPE. PUMPED SPACER. STARTED NIXING CEMEHT. RECEIVED Anchora(~ OPEI~T'rON EIUNNJLRY REPORt. ~/ELL: STEELHEAD M-30 i .:!:ii::::!:!::ii!i ::::.;! . : i '::::::: :::::i;:: :: ..::..;ii::: .. : : ii DA'~:.~i:.iiii: D~T.~ i:' :: ! i i IIll 04/27/92 26 4247 0~/28/92 04/29/92 C~/30/92 05/01/92 05/02/92 05/03/92 05/04/92 05/05/92 05/06/92 05/07/92 05/08/92 05/09/92 05/10/92 05/11/92 05/12/92 9.750 CEMENTED 13 3/8 CASING W/ 242~SX CEMENT. DISPLACED WITH 627 BBLS 14.10 WITH NO RETURNS AFTER 2"90 BBLS PUMPED. SET PACKOFF AT TESTED S/LNE TO 5000 PSI. TESTED BOPS. P/U BHA AND RIH. DRILLED PLUGS, F/C ANO CNT FROM 4130 TO 4139. DRILLED CEMENT, FLOAT SI~3E AND 8' OF FORNATION TO 4255'. CBU. TESTED SHOE TO l&.O PPG ENW. DISPLACED WITH POLYMER NUO. DRILLED FROM &255' TO 5166', SURVEYING WITH DRILLED FROM 5166' TO 5415'. CIRCULATED. TRIPPED FOR BIT. DRILLED 5415' TO 5488'. DRILLED AND SURVEYED FROM 5488' TO 62~3'. CIRCULATED FOR WIPER TRIP CIRCULATED. MAOE WIPER TRIP TO CASING SHOE. DRILLED AND SURVEYED FROM 6233' TO 6765'. DRILLEO TO 6?65'. CBU. MAOE WIPER TRIP TO 5392'. DRILLEO TO 7229'. FIRE ALARM SOLINOEO ANO PLATFORM POWER SHUT DC~ AT 23:25 HRS. CBU ANO STARTEO POOH ON EMERGENCY POKIER. POOH. TESTEO BOPS. RIH TO CASING SHOE AND CIRCULATED WHILE REPAIRING PLATFORM POUER. TRIPPEO FOR OIRECTIORAL ORILLING ASSEMBLY. CIRCULATEO WHILE RESTORING RIG POUER. LOAD TESTED BACKUP POUER TRANSFORNER AND CIRCULATED AT CASING SHOE. CIRCULATEO AT CASING SHOE. RIH. DRILLED ANO SURVEYED FROM 7229' TO 7555'. DRILLEO FROR 7555' TO 78~0'. WIPER TRIP TO 62.TR~'. DRILLED TO DRILLED ANO SURVEYED FROM 78~0' TO 80~'?'. CBU. TRIPPED FOR BIT MUO NO?OR. DRILLED FROR 8077' TO 8095'. DRILLED AND SURVEYED FROM 8095"T0 8691'. DRILLED FRQN 8691' TO 8701'. MADE 20 STAND SHORTTRIP TO 6800'. DRILLED AND SURVEYF. D FROM 8701' TO 90843'. DRILLED FRC~I ~80' TO 909?'. CBU. POD#. TESTED BOP'S. BHA. RIH. DRILLED AND SURVEYED FROR 909?' TO 9225'. DRILLED AND SURVEYED FROM 9225' TO 9398'. MAOE SHORT TRIP TO 77~'. DRILLEO ANO SURVEYED FROM 9398' TO 9529'. ORILLEO ANO SLIRVEYEO FROM 9529' TO 9795'. CBU. POOH. CHANGED BIT, 27 28 29 3O 31 32 33 34 35 36 37 38 39 4O 41 5166 5488 6233 6765 7229 7555 7830 8095 8691 9O8O 9225 9795 9.450 9.650 9.650 9.900 9.950 9.950 9.900 9.950 9.950 9.950 9.850 9.800 9.850 9.850 9.850 OPERATION SUMMARY REPOR'. ~dELL: STEELHEAO M-30 05/13/92 42 10038 9.800 FINISHED RIH. DRILLED AND SURVYED FRON 9795' TO 10,038'. 05/14/92 43 10292 9.800 DRILLED AND SURVEYED FROM 10038' TO 10292'. MADE A WIPER TRIP AT 05/15/92 44 10~39 9.850 POOH. MADE UP NEW BHA AND RIH TO 5023'. REAMED TO 5326'. RIH. DRILLED FRON 10292' TO 10~39'. 05/16/92 45 10730 9.850 DRILLED FROM 10~39' TO 10617'. MADE A WIPER TRIP TO 9645'. DRILLED TO 10730'. 05/17/92 46 10835 9.850 CIRCULATED. POOH. TESTED BOPS. RIH WITH MOTOR. DRILLED FROM 10730m TO 10835'. 05/18/92 47 11130 9.850 DRILLED FROM 10835' TO 11085'. MADE A WIPER TRIP TO 10130'. DRILLED TO 11130'. 05/19/92 48 11306 9.850 DRILLED FROM 11130' TO 11306'. CaLl. POOH. LEFT 3 CONES IN HOLE. RIH WITH MILL TOOTH BIT. 05/20/92 49 11306 9.900 RIH WITH BIT 11223'. REAM TO 11301' t,K)RKING JUNK TO BOTTOM. CBU. POOH. MADE A REVERSE CIRCULATING BASKET RUN. NO RECOVERY. 05/21/92 50 11316 9.900 RIH W/ CONCAVE MILL AND MILLED Off JUNK. POOH. MILL 100~ WORN. HAD 2/3 CUP METAL IN BOOT BASKETS. RIH WITH MILL TOOTH BIT. DRILLED JUNK Ago 10' MEW HOLE TO 11316'. BIT GUIT DRILLING. POOH. 05/22/92 51 11551 9.800 POOH. RECOVERED 3 1/2 CUPS OF IRON. P/U NEW BIT, HUD MOTOR AND RIH. ORILLED Ago SURVEYED FROM 11,316' TO 11,551'. 05/23/92 52 11808 9.800 DRILLED AND SURVEYED FROM 11,551' TO 11,631'. MADE 10 STAND SHORT TRIP. DRILLED AND SURVEYED FROM 11,631' TO 11,808'. 05/24/92 53 11873 9.900 DRILLED AND SURVEYED FROM 11,808' TO 11,831'. POOH. TESTED RIH. DRILLED Ago SURVEYED FROM 11,831' TO 11,87'5'. 05/25/92 54 12149 9.900 ORILLED AgO SURVEYED FROM 11,873' TO 12,067'.~AOE 10 STO SHORT TRIP. ORILLEO Ago SURVEYEO FROM 12,067' TO 12,149'. 05/26/92 55 12291 9.850 DRILLED AgO SURVEYED FROM 12,149' TO 12,291. CBU. POOH. L/D MOTOR Ago Nkk). P/U PACKED BHA ANO RIH TO 3377". STRING UP TO 12 LINES. 05/27/92 56 12291 9.850 FINISHED RIH. CIRCULATED AND CONDITIONED MUD. POOH. CHANGED RAMS. R/U Ago STARTED RUNNING 9 5/8" INTERMEDIATE CASING. 05/28/92 57 12291 9.850 RAN 9 5/8 INTERMEDIATE CASING, LANDED SAME WITH SHOE AT 12,247'. CIRCULATED Ago CONOITIONED MUD. OPEP. ATION SUMMARY REPORT ~ELL: STEELHEAD #-30 05/29/92 58 12291 10.000 CEHENTED 9 5/8" CASING.CHANGED OUT CASING RAJ~S FOR PIPE RAHS. RAN RETRIEVABLE BRIDGE PLUG TO 4220! TO INFLATE ECP. RE STRING BLOCK TO 10 LINES. TESTED BOPS. L/D GRADE E DRILL PIPE. 05/30/92 59 12424 9.900 LAYED DOUN GRADE E DRILL PIPE. TESTED 9 5/8" CASING TO 4000 PSI. RIH PICKING UP GRADED G AHD S'135 DRILL PIPE. DRILLED OUT TO 1Z300~ AND TESTED SHGE TO 16.1 PPG EI~. DRILLED TO 12626~. 05/31/92 60 12739 9.950 DRILLED FRON 12626! TO 12739~. CBU. TRIPPED FOR BIT. 06/01/92 61 13031 9.800 FINISHED RIH TO 12739~. DRILLED FRON 12739! TO 13031~. 06/02/92 62 13152 9.900 CBU. WIPER TRIP TO CASING SHOE. DRILLED FROIq 13031~ TO 13050~. CBU. BiT TRIP. DRILLED TO 13152! 06/03/92 63 13385 9.900 DRILLED FROIq 13152~ TO 13385~. CSU. POOH. PICKED UP NEW BIT AND ADJUSTABLE NEARBIT STAB. RIH. 06/0~/92 64 13520 9.950 RIH. DRILLED FRON 13,385~ TO 13,475~. POOH. CHANGED STAB AND BiT. RIH. DRILLED FRON 13,475~ TO 13,520~. 06/05/92 65 13786 9.900 DRILLED AND .SURVEYED FRON 13,520~ TO 13,786~. CBU. POOH. TESTED BOP~$. 06/06/92 66 13843 9.900 RIH. DRILLED FRON 13,786~ TO 13,843~. TRIPPED FOR BiT. 06/07/92 67 16187 9.850 FINNISHED RIH. DRILLED AND SURVEYED FRC~ 13,843~ TO 16,187~. 06/08/92 68 14370 9.950 CBU.TRIPPED FOR BiT. DRILLED FRON 16,187! TO 16,370~. CIRCULATED AND CONDITIONED Hi. JO RAISING NUD i, rl' FRON 9.9 PPG TO 10.1 PPG. 06/09/92 69 14370 10.100 CIRCULATED AND CONDITIONED HUO. SHORT TRIPPED TO SHOE. CBU. POOH. RIH WiTH DIL/GR/SONIC/AHS AND LOGGED 16,368~ TO 12,247~. H/U BIT AND STARTED RiH. 06/10/92 70 146~0 10.200 RIH. DRILLED FRON 16,370~ TO 16,620~. CBU. PULLED 5 STANDS, HAD TO REAJq ALL 5 STAIID$. RIH. CIRCULATED RAISING HUD WT FRON 10.2 PPG TO 10.4 PPG. ., 06/11/92 71 146~0 10.650 CIRCULATED AND RAISED NUD WEIGHT TO 10.6 PPG. POOH WITH 5 STANDS OF DRILL PIPE. HOLE SWABBING. CIRCULATED AND CONDITIONED NIJD. NADE WIPER TRIP TO SHOE. CBU. POOH. STARTED RUNNING 7" LINER. 06/12/92 7'2 14620 9.900 FINISH RUN#I#G 7" 29 PPF LINER. RIH WITH LINER ON DRILL PiPE TO 9 5/8# CASING SHOE. CIRCULATED LINER CAPACITY. RIH WiTH LINER TO 16003~. LINER STUCK AND COULD NOT WORK FREE. CIRC AND CUT NUD WEIGHT TO 9.9 PPG. LINER RUNNING TOOL DISENGAGED WHILE WORKING PIPE. POOH. OPEI~TTON S~Y REPORT ~ELL: STEELHEAD M-30 i i LINER IdlTH 650 SACKS OF CEMENT. CIRCULATED. POOH. 0~/14/92 74 14.~.0 9.~00 TESTED BOPS. RIH gXTH 8.5n BIT TO 10,970~. DRILLED CEMENT TO 11383~. CIRCULATED. TESTED LINER T~ A~ 9 5/8' ~SXNG TO ~ PSI. CIR~TED ~ ~ITI~ ~. ~H. ~/15/92 ~ 1~0 9.~0 ~H. CH~D T~ ~S TO 3.5" AND TESTED. PIC~D UP ~.~. DRILL COL~S A~ ~.5u DRILL P[PE. R[H ~]TH 5u DRILL PIPE. DRILL~ CE~NT AND RETAINER FR~ 11~~ TO 11~13". RZH TO 1~59~. DRILL~ CE~NT ~ RETAINER JUNK TO 135~~. C~. P~H. P/U NE~ BIT AND R[H. ~/16/92 76 1~0 9.~0 R[H. DRILLED CEHENT TO 1~9~~. TESTED 7~ LINER TO ~000 PSI. ~H. P/U BIT AND STABILIZERS. ~/17/92 ~ 1~20 10.]00 R[H. DRILLED CE~NT AND FLT SH~ FR~ 119~ RE~D TO 1~1~~. HOLE T[GHT. P~H TO SH~. ~[SED ~ TO 10.] PPG. ~ASHED TO 1~0~. CBU. ~[PER TRZP TO SH~. C~. ~H. RUN 5n L[NER. ~/18/92 78 1~0 10.~00 FINN[SHED P/U 5n LINER AND RIH ~]TH S~ ~ DP TO 1~,620;. CEHENTED LINER ~[TH ]50 SX CEHENT. P~H ~ STANDS AND CZR~T~. P~H. ~/19/92 ~ 1~0 10.500 FZN[SHED ~H. P/U 6" BIT AND DRILLED CEHENT FR~ 1~627~ TO T~ OF 5n L[NER AT 13,~5~. C~. TESTED LINER L~ TO ~0 PS[(17.6 E~). P~H. STARTED P/U B~ TO CL~ ~T 5u LZNER. ~/20/92 ~ 1~0 10.500 P/U 3 1/8n DC~S. LOST DC SLIP DIE IN HOLE. STAND BACK DC~S. R[H ~[TH 5.5u ELECTRIC ~GNET, UNABLE TO GET [N 7" LINER. P~H. ZNSTALLED CENT~L[ZER AND R[H ~/ ~GNET TO T~ OF 5u LINER AT 1],~5~. ~, NO RE~RY. RZH ~]TH 2 1/8" ELECTRIC ~GNET, UNALBE TO GET IN 5u LINER. P~H, NO RE~RY. R[H ~ITH CEHENT H~LL. TAG~D CEHENT AT 1~50~. DRILLED CEHENT TO ~/21/92 81 1~5~ 10.500 DRILLED CEHENT IN 5" LINER TO 1~,5~;. C~. TESTED CASING TO ]~OPS[ F~ 30 MIN. P~H. R[H ~[TH 5" AND 7u ~SING SC~PERS. C~. ~H. ~/22/92 82 1~5~ 10.~0 F~N[SHED ~. R/U E LINE. R[H ~TH GR CBT AND L~GED 15,~7~ TO 1~,855~ ~[TH 2~0 PSI. (T~ ~ ATTEHPTS TO GET INSIDE 5" LINER). R[H ~[TH GR CBT AND L~ FR~ 13,855~ TO 11,985~ ~ITH 20~ PSI. R[H ~[TH RATE GYRO. ~/~/92 ~ 1~5~ 10.~0 ~ RATE GYRO FR~ 1~,570 TO ~RFACE.~N CET FR~ 1~,~ TO 11,~~ ~LN. R[H ~ITH CEHENT RETAINER ~ ~/L AND SET S~ AT 1~,100~. R[H PERF ~NS AND SHOT S~EEZE PERF~S FR~ 12,~7 TO 12,~~. ~H, R/D ~/L. H/U 7" RETAINER AND RIH ~[TH DP. ~/2~/92 ~ 1~5~ 10.500 FINISHED R[H ~[TH RETAINER. SET S~E AT 12,9~ OPER~TTON S~Y WELL: STEELHEAD H-30 06/25/92 06/26/92 06/27/92 06/28/92 06/29/92 06/30/92 07/01/92 07/02/92 07/03/92 07/04,/92 07/05/92 07/06/92 85 87' 9O 91 92 95 96 1457~ 14575 14575 14575 14575 14575 14575 14575 14575 14575 14575 14575 10.500 10.500 10.500 10.500 8.400 8.400 8.400 8.400 8.400 8.400 8.400 8.400 T'.~O_DP VOLLIIIES. POOH. TESTED BOP'S. M/U NEW BIT AND RIH TO 11,350'o CIRCULATED AND WAITED ON CEHENT. WOC. RIH. DRILLED CENENT AND RETAINER FRON 12916'T0 1310~'. CBU. TESTED PERFS TO 3200 PSI. BLED TO 2g~.O PSl IN 30 NINS. POOH. RIH WITH 7" AND 9 5/8# CASING SCRAPERS. CBU AT 13072'. POOH. POOH. RAN CBT/CET FRON 1310~' TO 11383'. POOH. RIH OPEN ENDED. SPOTTED CENENT FRON 1310~'T0 1258~'. POOH TO 112/~'.SGUEEZED 3.5 BBLS. OF CENENT INTO PERFS AT 129~?' TO 12~99' WITH ~00 PSi. POOH. POOH. RIH WITH 6# BIT TO 12300'. CIRCUU~TED AND WAITED ON CENENT. RIH AND TAG CEHENT AT 126~5'. DRILLED CEHENT TO 1310~'. CmJ. TESTED PERFS TO 3200 PSI. BLED TO 2800 PS] IN 30 HINUTES. POOH. POOH. RZH WITH 6" BIT AND DRILLED RETAINER AT 1310~'. PUSHED RETAINER JUNK TO 138~2'. DRILLED ~0 13865'. CBU. POOH. RIH WITH CASING SCRAPERS TO 14575'. CIRCULATED. CBU. DISPLACED HUO WITH WATER. ROLJND TRIPPED CASING SCRAPERS. CIRCULATED AROUND SWEEPS. DISPLACED WATER WITH FILTERED 8.4 PPG KCL. CIRCULATED AND FILTER CONPLETION FLUID. CIRCULATED AND FILTERED CONPLETION FLUID. POOH. HADE UP PERF GUNS. RIH WITH TCP GUNS. RIH WITH TCP GUNS. SET PACKER AT 13823' AND PERF FRON 13941' TO 14518' WITH 6 SPF. FLOUED WELL FOR 30 HINUTES. REVERSED OUT. SPOTTED PILL TO CONTROL LOSES. POOH AND L/D SPENT GUNS. P/U TCP GUNS. RIH WITH TCP GUNS. SET PACKERa 12290'. PERFORATED 12,932' TO 12,340' WITH 4 SPF. FLOUED WELL FOR 30 HINUTES, WITH STRONG BLOU TO SURFACE. REVERSED OUT 1 1/2 DP VOLUNES. POOH, L/D PERF GUNS. P/U 4 1/8# HILL AND CASING SCRAPERS AND RIH. RIH WITH HILL AND SCRAPERS. CIRCULATED AND FILTERD 2% KCL. P/U ISOLATION PACKER ASSE#BLY AND STARTED RIH WITH SANE ON DP. ., RIN WITH ISOLATION PACKER ASSENBLY AND SET SAI4E AT 13,190' DPN. POOH L/D 56 STD 5" DP AND 22 STDS 3 1/2" DP. R/U AND RUN PACKER ASSEPlBLY AND & 1/2# PRODUCTION TUBING. RUN IN HOLE WITH PACKER ASSENBLY AND 4 1/2" PROOUCTION TUBING. REVERSE CIRCULATE AND SPOT CORROSION INHIBITED FLUID. FINISHED SPOTTING CORROSION INHIBITED FLUID. P(X)H W/ 500' OF TUBING TO REPAIR FL~J~ED TEFLON SEALS. R/U SLICKLINE AND RIH TO 2~'20' WITH 3.7" SWEDGE. UNABLE TO GET DEEPER. RIH WITH TUBING CH/UJGING OUT SEAL AND LANDED SAME. DROPPED BALL AND ~T P~ AT OPEI~ATION S~MMARY REPORT WELL: STEELHEND #-30 · :':::::::'::::' '::'::::':':: :::::::::::::::::':'::'}":':':::::::~::::~::: :::i ,::: :::::::::': ::::': ::::::::?:'.:i:;:::iii::: .i:::ii:i'.: · : ' :: :. ¥:::::: :::i:i:::i ::"::i:::::i:: ::::::::::::::::::::::: :'::!':'::: !:i::E!:iiiii:!}i::.: ' :':!:!:T:!::::!: :: :'.~q<<¥::~.~ 11,989m. SET ~ THROUGH PLUG. SET TWO CHECK VALVE. N/D BOPS. SET TREE. 07/07/92 97 14575 #%PPLED UP AND TESTED TREE. PULLED TWO WAY CHECK VALVE. R/U S/L AND PULLED PUNP THROUGH PLUG. PREPARE TO SKID. RELEASED RIG TO WELL ~-7 AT 1800 #RS 7-6-92. TRAIHN~ BAY UNIT Cc,.~teted 7/7/~p All ~tOll/'ff. nl;S OrE, RKB 'to to~ of equ~:men'L 16' 7511 K-55 ElO' L439' 13-3/8° 611 K-55 81' P.371' 13-3/8' 68S K-55 ~371' 4~4' 9-5/8' 471 N-~ 77' 1~47' 7' ~9~ N-~ ]L~3' 14~ 0° - 74' 505' 1L~c)4· I?~033' 1P~066' 4'1/2' 12Jl. L'BO !1~ Butt TIcH~ IPC ./ TK-99 FHC H~nger TCIAEN 4-1/E' CS HYD TxB Baker ~" l~lN~e. :~75° Profge Baker lC-22' AnChO~ SWOt Asse~i~y ~ker 'SA~-3' Packer. 85~B47X40 Baker ~l~t Ext~ 5' LTC PxP ~kffr 'F' ~ff, ~75~ ~oFRff ~kffr Vf~ Entry ~ I solatJo~ Pg~;k~ 13.190' 13.194' 13.199' 13.~.3~' 13.270' 13.~.71' BGker q~-I' Packer, $;ze 85-40 Baker )lllo~t [xtenslm ~' LTC PxP ~kffr ~' ~ff ~ Profle ~kffr ~ ~ff ~'/~' Baker V~ Entry ~ d~ ~ lnte~vGI G-2 12,340'- 12,360' G-2t. 12,3~6' - IP...4 ~' G-3 12~18' - G-4 1~,~96' - 12,676' G-5 1P,830'- 12,859' G-~5 12,869,- IP,932' PBTD @ 14,~57~' TD e 1~..71' 4-1/2' 8~ 29, 63' 19' 7O' 62' 116' 28' 4 60' 60* 6 60' 7/!/9~ 7/I/92 7/2/92 7/2/92 OCT DI~ECT!ONAb SURVEY CUSTOMER bi:STING FOR MARATHON OIL COMPANY TSU M-30 SURVEY DATE: 2~-JUN-9~ EkGINEER: T. S,~ITH ~ETHODS OF CO~PUTA?ION TOOL LOCATI(~N: TAhGE~TIAL- hveraQed deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: MORIZ. DIST. PROJECTED ONTD A TARGET AZIMUTM OF NORTM 9 DEG 54 MIN EAST GCT DIRECTIONAL SURVEY CUSTO~E~ LISTING FOR MARATHON OIL COMPANY T~U M-30 ~CARTHUR RIVER KE~]AI, AbASKA SURVEY DATE: 22-0UN-92 E~GINEMR: T. SMITH METHODS OF C[~PUTATION TOOL bOC~TIO~: TAhiGENTIa!,- averaged deviation and azlmutn VERTICAL S~CTIO~i: ~ORIZ, DIST, PROJECTE[~ O~TO A TARGET AZIMUTH OF NORTH 9 DEG 54 SIN EAST COHPUTATIO~ DATE: 21-0Ub-92 PAGE rBu ~-30 KE~!, DATE OF SURVEY~ 22-JU~-92 KELLY BUMMING EhEVAT~ON~ ~6..000 FT ENGINEER: T, SMITH INTERPOLATED V~LUE$ FOR EVEN iO0 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MASURFD VERTICAL VERTICAL DEVIATION AZIMUTH DEPT~ DEPTH DEPT~ DEG ~IN DEG ~I~ YERTICAL DOGLEG RECTANGULAR coORDINATES HOR!Z, DEPARTURE 'SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST' AZIMUTH F.~.EI DEG/iO0 FEET FEET FEET DEG SIN 0 O0 lO0 00 200 O0 3OO O0 4O0 O0 50O O0 600 O0 700 DO 800 O0 900 O0 0,~ -160.00 o 0 u 0 0 E 100,~ ~60,00 0 lo S 85 33 ~ 00,00 40,00 0 !5 S 10 10 w ~00.00 t40,00 0 15 $ 20 4, E 400,00 240,00 0 47 M 53 27 E 500.00 340,00 0 58 E 37 51. E 600,00 440,00 0 47 ~ 3 21. W 700.00 540.00 I 46 M 41 53 W 799 97 63g.q7 2 1.4 M 50 29 W 899:90 739'90 2 1 N 47 3 W 0,00 -0.3i -0.50 -0,95 -0 95 ,97 ~,4~ 7.46 0,00 0,50 0 20 0 00 1 18 0 37 1 04 1 27 0,00 o;65 0,00 N 62 S 1:;08 S 1.'~7 S 0. 4 N ,24 N 5,?O N 8,20 N E O..~4 E i ~ E 2 17E 2 98 E i 96 E 0 75 W 3 58 W 0,00 iN 0 0 E 0;72 S 54 52 E 0;89 S 46 12 g I~27 $ 31 44 E ~,65 $ .45 12 g 2,37 N 89 42! E 3;33 N 63 E 5 75 N' . w 8'95 N 23 ~6 W 1200 1300 140~ 150 1800 1900 00 999 86 839.86 1 37 O0 I099:79 939.79 3 5 00 11.99,53 !039.53 4 41 00 1299,1.3 1139,13 5 48 00 1308,39 1238,39 8 1 00 I497 2~ 1337,22 9 30 0C 1595:5! 1435,5! ~1. 45 00 1693i06 1533,06 13 30 00 1790 01 1630,0! 1.4 51 O0 1886.44 !726,4~ 15 56 a 45 40 w 9.24 N 35 29 w 11.33 N 21 41 w 17.05 N 13 7 w 24.99 ~ 3 9 W 36.50 N ! 33 W 51,39 N 2 39 E 69.56 ~ 5 31 E 91.40 ~ 8 42 E 115.86 N 10 22 E 142,35 o,00 3 33 0 86 2 43 i 78 1,68 2.38 1.46 1,13 1.03 10 38 N 1~ 93 N 1 29 N 27 82 N 39 77 N 54 98 N 73 39 N 95 29 N 119 60 N i45 71 ~ 5,75 8.,23W 1,1'34 ~4'09 5'55 ~6,15 11,87 N 29 0 W 15'33 N 32 28 W 22 '38 N 30 28 W 3~,,v N 21 ,i:O 1 4 w 96'36 N 8 34 W 120',1,4 N 5 26 W 145,87 N 2 43 W 2000 O0 1982 34 1822,34 17 5 21o6:00 2077:38 1917,3~ 19 11 2200001 2171,26 2o11,2t, 21 3 2300 00 2264,11 2~.04,11 22 34 2.400 O0 2355.~5 2195,85 24Im`8 2500 00 2446,41 2286,41 25 50 2600 00 ~535,79 2375,79 27 40 2700:00 ~6~3,59 2463,59 29 31 2500,o¢ 2709,73 2549,73 31. 31. 2900,00 2794,17 263~,17 33 23 N lO lB E 170.67 ~! 9 46 E 201.75 N 9 52 E 236,21 N 9 ~ g 273,32 N 7 14 E 313,09 N 7 0 E 355.44 M 7 48 E 400.23 N ~ 26 E 445.06 ~ 8 36 F 498.83 ~ 9 0 E 552.39 2.05 2 31 2:.13 2,02 !.16 1,06 2 93 1~60 1,56 1.93 173 57 N 204 !8 N 238 3 N 274 ~2 N 314 10 N 356 19 N 400 67 N 448 02 N 498 25 N 551 18 N i:,o 57 E 20 48 E 238 21,30 E 314 26'48 E 357 32;18 E 401 39°03 E 449 46'55 E 500 54.77 E 553 58 N 0 36 W 21 N I 0 E 32 N 2 17 E 17 N 3 16 E 82 N 3 53 g 17 N 4 !5 E 96 N 4 36 E 72 N 4 59 E 42 N 5 20 E 90 N 5 40 E 3000 00 2876.84 2716.84 35 3 3!00:00 2957.s7 2797.87 36 47 3200,00 3036.73 2876.73 39 6 3300 00 3113,15 2953,15 41 13 3400:00 3187.29 3027.29 43 13 3500 00 3258,73 3098,73 45 38 3600 00 3327.15 31.67,15 47 46 3700 O0 3393.42 3233.42 48 51 3800 00 3459 28 3299.28 49 5 3900 O0 3523:99 3363.99 49 51 ~. 9 !7 E 608,63 ~ 9 55 E 667.23 N 9 48 g 728.7C N 9 24 E 793.19 N 9 26 E 860.29 N 918 E 930.24 ~ 9 51 E 1003.!7 ~i 10 21 g 1078,05 ~ I0 0 E 1153,30 N 9 ~2 E 1229,54 0.85 1.66 1,88 1.63 2,39 3.26 2.10 0.32 1.60 0.80 606,72 N 664,50 N 725,05 N 788.64 N 854,84 N 923,86 N 995,79 ~ 1069.49 N 1143.53 N 1218,65 N 63,66 E 610 05 N 5 59 E 73,45 E 668 55 N 6 18 g 84,03 E 729 91 N 6 37 E 94.76 E 794 32 N 6 51E 105.74 E 861 36 N 7 3 E 117 11E 931 26 N 7 13 E 129~15 E 1004 13 N 7 2~ E 142 44 E 1078.93 N 7 35 E 55~86 E 1154,10 N 7 46 E ~68,84 E 1230,29 N 7 53 E CO;iPUTATIO.~ DATE: 21-dUL-92 gAR~TNON OIL COMPANY TBU ~-30 ~CARTHUR RIVER KENAI, ALASKA DATE OF SURVEY: 22-JUN-92 KELLY BUS~ING EbEVATION~ 160.00 FT ENGINEER: T, SNITH I~dTERP[]LATED VALUES FOr{ EVEN 100 FEET OF MEASURED DEPTH TRUE SUM-SEA COURSE EAS!.!RFD VERTICAL gR~!CAL. DE¥'IATIO~i AZI~UTf~ DEPT~ DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE ECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 4~00 4300 4400 4500 4600 4700 4800 4900 O0 3588,76 3428,76 49 00 3653,56 3493,56 · 50 0 O0 3717,64 3557.64 50 12 O0 3781.18 362!,18 50 41 O0 3a44.45 3684.45 O0 3908.06 · 3748.06 50 1 00 ~97~,7~. 3811,7! 50 49 O0 4035.51 3875,51 49 52 O0 4099.92 3939,92 50 2 00 4163.8~ 4003,88 50 ~7 ~ 9 49 E 1305.73 N 9 30 E 1381,89 N 9 31 E 1458,66 N 9 25 E 1535,87 ~ 9 9 E 16 ~ 30 18 44'56 ~ 8 45 E N 8 2~ E ~921,04 0 38 0 90 0 O1 0 56 0 95 ! 57 i 82 I 51 0 67 0 43 1444 ~520 ~597 1673 8'2 N 14 55 N 207 71N 219 13 N 232 31 ~' 244 50 N 256 60 N 268 29 N 2 459 I E 1536 39 E 1613 68 E ~69! 66 E 1768 40 E 1845 87 E 45 N 8 0 E N 8 10 E 53 N 8 14 E 95 N 8 17 E 1.0 N 8 19 E 5000 O0 a227 75 4067.75 50 10 5100 O0 4291:86 4131'86 50 7 5200 O0 .4356'15 4196,15 49 59 5300 O0 4420 36 4260.36 50 7 5400 O0 4485 17 4325,17 49 27 5500 O0 4549 78 4389,78 49 36 5600 O0 4614 96 4454.96 ~9 4 5700 O0 4680 71 4520.7! 49 7 5800 O0 4746 35 4586.35 48 .~8 5900 O0 48!1,94 465~.94 49 ~5 5i 8 37 g 2074.80 ~ 8 41E 2151'53 ~{ 8 44 E 2228.11 N 8 35 E 2304 76 ~ 8 ~4 g 2380:88 ~i 8 0 E 2457,17 ~!' ~ ~I E 2532,98 N 8 40 E 2608.29 ~.~ 9 7 F 2683.72 N 9 .45 E 2759.21 39 ,16 29 29 18 ,:84 2 88 N 8 24 E 3 313 2280 76 N 13 E 2305 2356 08 N 34832 E 2381 2431.64 ~ 359 07 g 2458 2506,.72 N 369 80 E 2533 2581.~2 N ~I 05 g 2609 2655, 7 N 59 E 2684 2730,25 N 404 88 E 2.760 54 N 8 24 E 69 N 8 25 g 01 N 8 24 E 85 N 8 24 E 19 N 8 24 E 63 N 8 25 E 11 N 8 26 E 6000 O0 ~876 80 47!6.80 49 43 6100:00 ~.941:73 4781.7.3 49 21 6200i~0 5006 43 4846.43 49 50 6300 O0 5070 61 49~0.61 50 6 6400 00 5134 81 4974.8! 49 54 6500 O0 5199 29 5039.29 49 49 6600 O0 5263 44 5103.44 50 20 6700 00 5326 99 5166.99 50 51 6800 O0 5390.28 5230.28 50 33 6900 O0 5453,70 5293,70 50 36 N 9 57 g 2835 ~ 10 28 E ~987.61 ~ 1! 12 E J064,29 ~ 11 27 ~ 3140 93 ~ 11 24 E 3217~34 ~ ,1 ~0 E 1294.03 · 11 45 F 3448.59 k 11 53 E 3525.87 0,59 0,32 1,58 0,48 0,63 0,34 0,29 0 89 0~53 0.67 2805,23 N 417, 2880,13 N 431,18 g 2912 2955 19 N 444'56 E 2988 3030:47 N 459.18 E 3065 3105,64 N 474 24 E 3141 3180,57 N 489 39 E 3218 3255,75 N 504 61E 3294 3331,41N 520 02 E 3371 3407.23 N 535 65 E 3449 3482'91N 551 51 E 3526 92 E 2836 19 N 8 28 E 22 N 8 31E 44 N 8 33 g 06 N 8 37 E 64 N 8 41E O0 N 8 45 g 63 N 8 49 E 75 ~ 8 52 E 08 N 8 56 E 30 N 9 0 E 7000 O0 5517.27 5357,27 50 23 71.00'00 5581 2~ 5421.21 49 48 7200:00 5645;7~ 5485.71 ~9 36 7300 00 57X0.73 5550,73 49 3~ 7400 00 5775,87 5615.87 48 58 7500 00 584!.9~ 5681,98 48 ~6 7600 00 5908.98 5748,95 47 55 7700 O0 5975.03 5~15.03 49 ~ 7800.00 6040.33 5880.33 49 22 7000.0o 6105,45 s~vL.a~ 49 ~9 N !2 15 ~: 3679.84 k 12 29 ~ 3756.19 N 12 38 g 3832.09 ~: 12 27 F 3907.87 ~ 1! 36 ~ 3982.84 E 10 1g E 4057.07 ~ 10 6 g 4132.14 ~: 10 ~ E 4207.8~ ~i 10 5 E 4283.77 0.41 0,57 1,15 0.62 0.90 1.34 1.39 0.33 0,84 1,34 3558,4! N 567.56 E 3603.39 N 9 4 E 3633,59 N 583,70 E 3680,18 N 9 8 E 3708,25 N 600,01E 3756'48 N 9 11E 3782.41N 616,54 E 3832'33 N 9 15 E 3856,45 N 633 09 E 3908,06 N 9 19 E 3929 81N 648:83 E 3983,0! N 9 23 E 4002:73 N 662 74 E 4057.22 N 9 24 E 4076,63 N 675i97 E 4132 29 N 9 25 ~ 4151,18 N 689 30 E 4208:02 N 9 26 E 4225.89 N 702 63 E 4283,91 N 9 26 E MARITWON OIL COMPANY TBU ~30 KEN'I, ALASKA DATE OF SURVEY: ~i~JgM'92 ~ELbY BUSHING ELEVATION: . .0 FT ENGINEER~ T. SMITM VALUES F[i!~ EVEN !00 MET OF t~4EASbPFD DEPTH TRUE SU~-SEA COUkSE E~&$!]R~D VERTICAL VERTICAL. DEVIATION AZII~UTH DEP'!'~ DEPTH DEP .:H .DEG VERTICAL DOGLEG ~ECTANGUbAR COORDINATES HORIZ. SECTIO~-:~ ~,EYERITY NORTM/$OUTH EAST/WEST DIST, FEET DEG/100 FEET FEET FEET DEPARTURE AZIMUTM DEGMIN 000 O0 100 O0 8200 8~00 8400 8500 8600 8700 8800 8900 ~,~ 6009 99 49 43 , 6074:69 50 00 6298,7~ 6138,72 50 12 oo 636~.3~ 6202.33 sc) ~ O0 6425,68 6265,68 50 31. O0 6489,26 6329'26 50 34 O0 6552,67 6392,67 50 36 O0 66i6,12 6456,!2 50 30 O0 6679,74: 65i. 9,74 50 !8 O0 6744.36 6584,36 49 3~ N 10 ~0 E 4360.15 N' 10 0 E 4436' 0 ~; 10 6 E 451.3.21 ~ 10 I E 4590.37 N 10 13 E 4667 75 N !0 24 E 4744~93 ~ !o 53 E ~82~ 25 N 11 24 E =899:53 11 i5 E 505:93 0,66 4301 1,~8 4376 0.69 445~ 0,45 452 O, 97 4603 0,28 46'79 0.99 4755 1,13 4831 1,15 4907 1,30 4982 .14 N 9. 36, N 28 E 6 N 74~,00 E 45~3,34 N 9 29 E 4 N 756,45 E 4590 49 N 9 29 E 92 N 769,99 E 4667 87 N 9 30 E 85 N 783.8, E 4745 04 N 9 30 E 87 N 798,0, E 4822 35 N 9 ~2 E 70 N' 812,97 E 4899 62 N 933 E 29 N 828,38 E 4976 72 N 9 ~5 E 09 N 843.53 E 5053 O0 N 9 37 E 9200 9300 9.40 O 9500 9600 970~ O0 6809 27 6649,27 49 4 O0 6875 42 67!5.42 48 18 O0 6942 07 6782,07 48 O0 7009 10 6849,10 47 43 O0 7076 71 6916.71 47 7 00 7144 87 6984,87 47 10 O0 7212 80 7052,80 47 30 O0 7280,46 7120,46 47 12 O0 7349.24 7189.24 45 50 9900.00 7418,65 7258,65 46 30 ~: !1 8 E 5128.98 ~ 11 46 g 5203'95 N 11 41 g 5278.4~ N 11 58 F 5352,63 ~ 1! 47 E 5426'27 N !t 30 E 5499,41 N 11 37 E 5572,76 N 1! 5 E 5646.37 ~ 10 38 g 5718.94 ~ 10 $ E 5790.93 0,76 ,32 ,42 ,79 5275 0,41 5347 ,39 5419 1,I3 5491 1.36 5563 1,92 5634 0,85 5705 5056 74 N 858 18 E 512 5130 '.222 N 878.~ 216 E 5201 5203 ] 2 N 8 7 E 5278 903 59 E 5352 84 N 96 N 918 64 E 5426 64 N 933 36 E 5499 1 M 948 19 E 5572, ~2 N 962 57 E 5646 97 N 976 46 E 5718 83 N 989,14 E 5790 04 N 9 38 E 0 N 9 40 E 0 N 941E 29 N 9 45 E ~ N 9 46 E N 9 48 E ]7 N 9 49 E 94 N 9 50 E 93 N 9 50 E 0000 O0 7487 46 7327.46 46 33 0100 O0 7556:21 7396,21 46 20 0200 0300 040O 0500 060O 07O0 o800 0g00 O0 7624.44 7464.44 47 29 O0 7692 12 7532.!2 47 O0 7760 54 7600.54 46 43 O0 7829 26 7669.26 46 12 O0 7898 63 7738,63 45 51. O0 7968 89 7808.89 45 20 O0 8037.64: 7977.64 47 46 OO ~104.39 7944.39 48 32 N 10 30 E 5863.49 ~ 10 52 E 5936.!0 ~ 10 15 f 6009.20 ~ 10 10 E 6082.8~ ~ 10 51. K 6155,74 N 1! 11 E 6228.37 b 11 42 E 6300.37 ~ ~2 13 E 637!,48 N 10 40 E 6444.04 ~i 10 30 ~ 6518.50 25 5848, 8 N 1015 054 5920,4~ N 1029 0~52 5992,90 N 1042 0 91 6064 61N 1055 0:49 6135]90 M 1069 120 6206:51 N 1083 1:47 6276 12 N 1098 1,58 6347 22 N 1112 0,75 6420:44 N 1126 1002 13 E 5863,49 N 9 50 E 58 E 5936,11 N 9 51E O1 E 6009,20 N 9 52 E O~ E 6082,82 N 9 52 E 27 E 6155,74 N 9 52 E 28 E 6228'37 N 9 53 E 48 E 6300~7 N 9 54 E 23 E 6371,48 h 9 56 E 90 E 6444,05 N 9 57 E 41 E 6518,50 N 9 57 E 1.000 O0 8170,36 8010.36 4~ 12 1100'00 R235.42 8075,42 4~ 14 .0C, 8300 4!. 8j4G.41 49 26 1300 O0 8364.98 g204.98 39 50 1400:00 8429.2~ ~09.2~ 5() 5 !500~00 ~493.30 g333.30 50 25 1600 00 ~556.7~ 8396.7~ 50 31 17OO O0 8619.57 8459.87 50 59 1800100 8682.9~ 85~9.9~ 50 53 1900,00 ~746.76 8556.76 50 t3 hi 10 44 E 6593.65 a 11 3 E 6669.58 N i1 36 E 6745.55 N 1! 1 E 6821.88 N 10 50 E 6898.49 N 9 55 E 6975.28 N 914 E 7052.50 N 9 19 E 7130.12 K 8 54 E 7207.69 M 8 27 E 7284.69 2,01 0.49 0,57 1,52 3,71 1 50 0~71 0.91 1,22 0.56 6494 31N 1140,22 E 6593 65 N 9 57 E 6568 87 N 1154,69 E 6669:58 N 9 58 E 6643 40 N 1169,54 E 6745'56 N 9 59 E 6718 25 N 1184.64 E 6821,89 N 10 0 E 6793 53 N 1198,92 E 6898,51 N 10 1E 6869 00 N 1213,11E 6975,30 N 10 1E 6945 25 N 1225,84 E 7052,60 N 10 1E 7021 76 N 1238,44 E 7130'14 N 10 0 E 7098 36 N 1250,72 E 7207.70 N 10 0 E 7174,50 N 1262,28 E 7284,70 N 9 59 E ~ARATHON' OIL COHPAP.~Y ~CART}~UR RIVER KF~AI, ALASKA CONPUTATIOL DATE: 21-d!Jb-92 ' PAGE 4 DA:TE OF SI..RVEY~ 2~ JUN-92 KELLY BUSHING ELEVATION: 160,00 FT ENGINEER~ T. SMITH INTERDULATED VALUES F~R LVEh ~00 ~E....T OF MEASURED DEPTM EASI.!RFD VERTICAL VERTICA! .... DEVIA. TIO~ AZIMUTH ...... ' DEPT!~ DEPTH DEPTH D..~G 2000 ~0 88t0 52 S650.52 50 30 2100:..0- 8874 08 ~714:.0~ 50 40 2200:00 8937 33 8777,33 50 34 2300 00 9001 13 8841.!3 50 41 2400 O0 9064 4:0 ~904.40 50 48 2500 O0 9~28 05 8968,05 50 !8 ~600 O0 9~9~ 84 903!,84 50 15 2700 O0 9255 93 9~95.93 49 47 2800 O0 93~0 81. 9160,8~. 49 15 2900 O0 9306 45 9226,45 4~ 44 3000,00 9453.03 9293.03 47 2~ 3~00 O0 9521,07 9~6~.07 4641. 3~00100 9590,48 9~30,48 455~ 3300 O0 966028 9500,2S 4544 3400 O0 9730135 9570,35 4454 3500 O0 9fi0~,49 9642.49 4~ 51 ~-80. O0 ~002~,0! 906~.0~ 39 3~ 3900 O0 10~05.32 9945,32 3~ 43 4000 O0 ]0].~3 7610023.76 3744 4100 O0 ~0262:95 ~010~,95 3716 4~00 O0 103430410~83.04 36 30 4300 4400 O0105045710344,57 35 23 4500 O01058693 ~0426.93 3340 4575,P6106491410489,14 3339 VERTICAL DOGLEG RECTA ULAR COORDINATES HOR Z, DEPARTURE SECTION SEVERITY NORTH/ OUTH EAST/WEST DIST AZIMUTH FEET DEG/!O0 FEET FEET FEET DEG ~ 758 g 736~,69 ~ 752E 7438,85 N 756 E 7516,26 a 811E 7593.23 ~. 8 9 E 7670'63 ~ 756 E 7747'71. M 759E. 7824'68 M 758 E 790~.'40 8 842 ~ 8052,89 M 8 46 E 8127.48 ~:, 9 37 E 8200.76 ~ 946 E 8272.74 35 ~ lO 38 E ~484,91 ~ 1023 E ~552,32 N 1121E ~89~.1o ~ 13 7 E ~988.20 N 12 26 E 9046.71 ~ 1t !3 E 9~03,38 N 10 26 E 9145.09 0,13 7250 1,09 7327 ~,62 7403 ,68 7480 0,65 7556 58 7785 1,44 7860 0,50 7935 1,07 1,66 0,80 0,40 2,34 1,68 ~,23 0,92 0,68 1,12 0.63 1,62 0,45 O, 42 0,00 8009 8O8 815~ 8223 8293 76 N 1273,24 E 7361,70 N 9 58 E 2 1N 1283~:;93 E 7438,85 N .956 E 93 N 1294;6! E 75~6;.26 N 9 55 E 18 N 1305,35 E 759~,2~ ~ 9 54 E 47 N 1337,80 E 7824,68 N 9 5X E 79 N 1359.39 E 7977'47 N 9 49 g 14 N 1381,96 g 8127 44 g 133 .909 E 8200 40 ~ 140605 E 8272 08 N 1417 53 E 8344 58 N 142843 E 8415 49 N 947 E 77 N 947 E 76 N 947 E 37 N 947 E 70 N 946 E 836183 ~ 1440 842.'108 N 1452 849 N 1 855~,99 464 ,32 N 1475 8618,62 N 1487 8 ,25 8797,71 8855,61 891262 8968:13 9009.17 09 E 8484 93 N 9 46 E 48 g 8552 34 N 9 47 E 32 E 8618 30 N 9 47 g 98 E 868269 N 9 47 E 89 E 8746,1! N 9 48 E 1500,05 E 8808:1~ sl2. o s869 1525,28 E 8928;~ 1538,64 E 8988,28 1551,80 E 9046,71 !56~,38 E 9103,]8 1570,83 E 9145,09 N 948 E N 949 E N 950 E N 951 E N 953 E N 953 E N 953 E ..... [;,..,TE 21-alL!b-q2 PAGE 5~ KEI, bY BUSHING E'LEVATIONI 60 0., 0 FT INTERPOI~,ATED VAt, UES F"O~ EVE~ lO00 FEET OF aEAS~RED DEPTH TRUE SUB-SEA COURSE EASIlP~D VERTICAL VERTICAL DEVIATION AZIMUTH DEPT~ DEPTH DEPT~ DEG ~ I ~ DEG 0 O0 -160,00 0 0 999 86 B39,86 I 37 O0 1982 34 1~22,34 17 5 oO 2876 84 2716.84 35 3 OD 3588.76 3428.76 49 28 00 .4227.75 4067.75 50 !0 O0 41t76 80 ~716.:80 49 43 00 5517:27 5357.27 50 23 OO 6169.99 6009.99 49 43 O0 6809.27 6649.27 49 4 0 O0 1000 O0 3000 6000 7000 8000 9000 0000 O0 7487 46 7327.46 46 33 100~ O0 0170!36 ~010'36 4g 12 3000 00 9453,03 9293.03 47 28 40 .00 O0 10183,76 10023.76 37 44 4575,00 10649,14 10489,1a 33 39 VERTICAL DOGLEG SECTIO~i SEVERITY FEET DEG/iO0 ~ 0 0 E 0.00 E 45 40 W 9.24 ~i !0 18 g 170.67 ~ 9 i7 E 608.63 N 9 49 E 1305,73 ~ 8 37 E 2074.80 t~ 9 57 E 2835.32 ~ !2 6 E 3603,0l ~ 10 iO g 4360,15 ~ 11 8 E 5128,98 0 O0 0 O0 2 O5 0 85 0 38 0 39 0 59 0 41 0.66 0,76 ~ 10 30 E 5863.49 N 10 44 E 6593.65 M 7 58 E 73~ 69 ~ 11 21E 8808.10 M 10 26 E 9145.09 0,62 2,01 0,13 1,07 0,63 0,00 RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET PEG ~4!N 10 173 606 2805 3558 ~301 5056 57~7 6494 7250 8009 8679 9009 O0 N 0,00 E 0,00 N 0 0 E 38 N 5,75 W 11.;87 N 2.9 0 W 72 N 63,66 E 610,05 N 5 59.E 74 N 181,77 E 306 N 8 39 N 302;33 E 075 N 23 N 417'92 E ~836;19 N 8 28 E 41N 567;56 E 3603,~9 N 9 4 E 08 N 716.10 E 4360'29 N 9 27 E 74 g 858,18 E 5129,.04 N 9 38 E 1002'13 E 586~,49 N 9 50 E 22 N E .14 N ~381.,96 E 8127.;49 N 9 47 E 44 ~ 1500,05 E 8808."11 N 9 48 E 17 N 1570,'83 E 9145'09 N 9 53 E TBU TRUE SU~:-SE~ COURSE ~ASURED VMRTICAL VERTICAL 5EVI~TIOr~. AZI~UT}i DEPT~ DEPTH [>EPTH DEG ~I!} DEG ~IN 0 00 ~60 OO ~60 O0 360 00 460 O0 56O 00 660 O0 760 00 860 07 960 ~3 0,00 160.00 260 O0 360 00 460 O0 560' 660,00 760,00 860.()0 960.00 ENGINEE~ T,' S~IT~ I~TE~POL~ED vAI..,UES F[!~ EVEN 100 FEET OF SUB-SE~ DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,' AzimUtH FEET DEG/IO0 FEET FEET FEET DEG MIN -1.60.00 0 0 N 0 0 E 0.00 0.00 0,00 0 9 $ 4 9 w -0.36 0,28 lO0,OO 0 16 S 5 3~ E -0,78 0 O0 200,00 o 20 $ 68 41 E -1.15 2:36 300.00 1 I N 45 16 E -0.14 0,00 400'00 0 51 ~ 16 56 E 1.40 0'76 500,0C; I !6 N 3.3 22 W 2,83 1,22 600.00 2 1,2 N 49 15 W 4.7! 0,37 700.00 2 10 N 47 28 W 6.67 0,31 ~00,00 ! 42 N 43 28 w 8.57 0,40 ~ 46 56 ~ 10,23 1,50 N 24 3t W !4,43 1,58 ~3 !7 25 W 21,59 1,69 a 5 32 W 31,51 2,80 a 2 10 ~ 45.48 1,42 N I 16 E 62,50 2,86 k 4 30 E 83,65 1,45 N 7 34 E 1.08.01 1,66 N 10 6 E 134,88 1,38 N 10 24 E 163.89 1.I9 1060 ~!7 1,060 O0 90(),00 2 ! ~26 69 t260,00 i ! O0. OC..'. 5 1.3 1361 ~6 1360 O0 l?O0.OO 7 1~ 1462 ~9 1460:00 m~O0.O0 n sg 17 S186=7~ OS 1760,00 1600.00 14 27 ~; 9 ~4 E 195 77 2.5~ ~ 9-4 r 231:89 1.76 ~ 9 13 E 271.61 2 18 N 7 10 E 3i4.95 0:84 N 7 2 E 362.02 1.24 N 8 8 E 413.07 1.34 N 8 30 E 469,01 2,30 N 8 52 E 530.24 2,14 ~ 9 g E 596.90 1,83 N 9 55 E 668.82 1,66 21o.:04. 2160~00 20t,~O.OO 20 48 2295 54 2260 06 21o0 O0 22 2. 2404~55 2360:00 2200,00 24 22 25151 ~0 2460.00 2300.00 26 2627 ~] 2560,00 2400.00 28 13 ~74~0{ 2660,00 2500'00 ~0 20 2859.~ 2760.00 2600.00 32 32 2979.~7 2860 00 2700.00 34 45 3102.66 ~960:00 2~00.00 36 49 N 9 40 E 747.8l N 9 26 E $35.06 N 9 18 E 931.53 ~! 10 19 E 1039.92 N lO 0 E 1.154.14 ~: 9 46 E 1272.01 N 9 27 E 1389.57 M 9 29 E 1509.99 N' 9 9 E 1632.49 ~ 8 50 E 1753.2~ 3230 ~1 3060.00 2900.00 39 42 3362 84 3160.00 3000.00 42 24. 350~ 80 3260,00 3~00,00 45 42 364g 79 3360,60 3200,0~ 48 37 380~ 11 3460.00 3300.00 49 6 3955 69 3560,0() 3400.00 49 37 4!10~o2 3660.00 3500,00 50 4 4266.55 3760.~0 3600.00 50 43 4424 64 3860,0(i 370(i,00 50 48 458}:~7 3960.00 3800.00 50 51 2,34 2,09 3,31 1,27 1,61 0'32 0,51 0,47 0.87 !,63 0,00 0'49 ~.'9o ,,31 0 48 S 0 92 2 41 N 4 .70 N 7,2l 9,57 11 63 N 16 41N 24 2O N 34 64 N 48 95 N 66 27 N 87 54 N I ,36 N 166,89 N 19 9 N i73,03 N 15,95 N 62,73 N 413,.39 N 468'75 N 529,29 N 595,14 N 666'07 N 0 O0 E 0 67 E 0 63 E 0 83 E I 91 E 2, 90 E 2 61 E 0 43 E 2 51W 4 96 W 0,00 N 0 0 E 0'83 $ 54 3 E 1'10 S 34 57 1,55 $ 32 24 E 1'97 S 75 58 E 3,04 N 72 28 E 3,55 N 47 t2 E 4;72 N 5 15 E 7;63 N 19 10,77 N 27 23 W 7 10 W .13,62. N 31 2~ W 10 14 W I9;29 N 31,,~ W 13 09 W ;51 N 3 W 95 W 51;48 N ~8 16 17 W 68,2~ N ~3 4453 1.01 W 166 N 1 2 W ~ 55 E 198 30 N 0 44 E 8 74 E 234 03 N 2 8 E 15 39 E 273 46 N 3 14 g 21 54 E 316 68 N 3 54 E 27 29 E 363 75 N 4 18 E 33 96 E 414 78 N 4 42 E 42 11 E 470 64 N 5 8 E 51:33 E 531 78 N 5 32 E 61;78 E 598 34 N 5 56 E 7],72 E 670 1] N 6 19 E 743 88 N 87,26 E 748,99 N 6 41E 829195 N 101 61E 836.15 N 6 59 E 925,13 N 117 32 E 932"54 N 7 14 E 1031,97 N 135 59 E 1040,84 N 7 29 E 1144,36 N 156 O0 E 1154.94 N 7 46 E 1260 52 N 1~6 03 E 1272.75 ~ 7 57 E 1376:39 h 1-5.84 E 1390,26 N 8 6 E 1495,18 N 2~5,65 E 1510.65 N 8 12 E 1616,01N 235.43 E 1633,07 N 8 17 E 1735.30 N 254.46 E 1753.86 N 8 21E MAR~.THON OIL CO~'~PANY TBU ~30 ~CARTHDR RIVER KENAI, ALASKA CO~"iPUTATION DATE: 2!'JUL'g2 PAGE "J~N~92' KE~SY BUSHING E~EVATION: ENGINEER~ X', S~ITH iNTERPObATE[> VALUES FOR ..... VEN 100 ..EET OF SUB-SEA DEPT~ VERTICAb [OGLEG SECTION' ~EVERITY FEET DEG/IO0 TRUE SUB-SEA COURSE EASURFD VERTICAb VERTICAL DEVIATION DEPT~ DEPTH DEPTH DEG NIN DEG N 8 40 E 1873.56 N 8 16 E !993-19 N 8 42 E ~i13,40 N 843 E 2232"70 ~ ~ 27 ~ 235~ 55 N 8 i E 2469:!2 ~ 8 41 ~ 2584.so N 9 13 S 2699.33 N 9 55 $ 2815.49 N 9 59 E 2932,72 0,75 26 1,01 0 53 0 60 0:60 I 46 4:737,97 4060,0() 3900.00 49 51 4893,91 4!.60 O0 4000,00 50 28 5050.31 4260 00 4100.00 50 7 5~5 0,,,9~ 4360 O0 4200.00 50 0 536t 34 4460 O0 4300,00 49 20 5515 73 4560,00 4,400,00 49 27 566~ ~5 4660,00 4500.0© 48 51 ~74 4760,00 4600.00 48 56 O! 4860,00 470~,00 49 45 6128 10 4960,00 4~00.00 49 32 4900.0(3 50 9 5000.00 40 52 62 5260,00 5~00,00 50 19 . ~ ~ OO 5043 25 5360.00 5~0C:, 92 5460.00 5300.00 50 36 Ol 5560 O0 5400.00 50 11 03 5660:00 5500'01~ 49 26 77 5760,00 5600.00 49 ~1 o~ 5~6o.oo 5700.00 48 3 05 5960.00 5E00.00 49 ~ N 11 !2 E3170 2 3051'858 N 11 27 E N 11 30 E 328 ~i 113~ ~ 34.1~'8969 ~ 12 34 E~ ~z7 :94 N 1.2 34 E 3889.58 N 11 7 E 4002,96 N 10 5 E 4114,80 0,42 062 0 36 046 0 72 154 083 1.05 2,05 0,50 ~83 4~: 5O6O oo u~. 39 O~ 5160:00 6594 6752 6909 7067 7222 7375 7527 7677 7~30 24 6060 O0 5900.00 49 27 7984 54 6160:00 6000.00 49 .49 81.39 52 ~260 O0 6360:0() 6!00.0o 50 15 32 6200,00 50 44 01 6460,00 6300.00 50 3~ 55 6560.00 6400.00 50 35 O0 6660,00 6500.00 5032 15 6760.0© 6600.00 4945 02 6E60.0o 6700,00 4820 ~J. 6960'00 680~.00 48 ~ N 10 7 g 4230.84 N 10 11 g 4348.36 N 10 8 g 4466.76 N 10 0 E 4587.53 N 10 19 E 4709,32 N 10 59 E 4831.17 N 11 34 E 4952,76 N 11 7 E 5071.33 N 11 44 E 5186.65 N 11 49 E 5298.38 0,81 0.33 0,93 0.51 1,13 0.79 0,70 1,24 0,45 0,66 8296 8453 8611 8769 8924 9Q76 9226 N 1144 g 540~.22 N 1136 E 5515.70 N !1 6 E 5624.20 N 1023 E 5730.01 h 10 19 g 5834.52 N 10 51E 5940.09 N l.O 10 K b048.01 N 10 50 E 6155.17 N 1118 E ~260.36 N 12 10 E 6362.51 0,48 0.48 0.41 1,79 0.32 0.59 0,87 0,92 0,49 0,90 9375 40 7060 O0 6qO0.O(, 47 21 9527~74 7~60~0~ 7600.0fi 47 7 9669.~3 7260'()0 7100,00 47 24 98!5.~4 7360.©0 7200.00 45 43 9960 09 7460.00 7300.00 46 3! 0!05~51 7560.00 7400.00 46 23 025~164 7660.00 75(:)0.00 472'! 039q.~2 7760.00 7600.00 46 42 0544 37 7860.00 7700.00 46 6 0687:37 7960,00 7800.00 45 !,2 RECTAN~U NORTH/~oLAR COORDINATES HORIZ. DEPARTURE UTH EAST/WEST DiST" AZIMUTM FEET FEET FEET DEG ~IN' 1854,:27 N 272 80 E !874,23 N 822 E 1972,65 N 290 35 E 2091~57 ~ 308 ~5E 2993~90 N 8 114.;.15 N 8 23 E 2443;48 N 360 74 E 246,9;9? U 8 ~4 2557,.69 N 3~? 46 ff 2585,)9 N B 24 27B5,70 N 414 50 E 2816.'37 N B 28 E 2901,15 N 434 89 E 2933,;56 N 8 32 E 3134,93 N 480 I ,,. .49 N 8 43 E 3251,70 N 503 78 E 3 ~ 49 N 8 48 E 3371,08 N 528 15 E 3412 20 N 8 54 E 3490,4! N 55~ 09 E 353~ 96 N 9 0 94 9 3608,89 N 578 ,6 E 3654 N 6 E 37 24,62 N 603 65 E 3773 22 N 9 ~2 E 3838'58 N 629:13 E 388979 N ,9 18 E 3 949;54 N 652 79 E 4003 12 N 9 23 E 4059,55 ~ 672 93 E 4114 95 N 9 25 E 4173,79 N 6.93,34 E 4230 99 N 9 26 E 4289'47 N 714,02 E 4348149 N 9 27 E 4406,03 N 734;85 E 4466:88 N 9 28 £ 4524,93 N 755'95 E 4587 65 N 9 29 E 4644'83 N 777,41E 4?09,44 N 9 30 E 799.70 4831,27 N 9 32 E 4764'63 N E 4883,88 N 823 58 E 4952,84 N 9 34 E 5000,~4 N 847:10 E 507~,$9 N 9 37 E 5113 27 N 869:64 E 5~86,69 N 9 39 E 5222:73 N 892 33 E 5298,41 N 9 42 E 5330.28 N 914 96 E 5408.24 N 9 44 E 5435 61N 9~6 62 E 5515 7~ N 9 47 E 5541:96 N 958 30 E 5624 20 N 9 49 E 5645 85 N 978 48 E 5730 0! N 9 50 E 5748:73 N 996 89 E 5834 53 N 9 50 E 5852.50 N 1016 33 E 5940 ~0 N 9 51E 5958.64 N ~035 88 E 6048 0~ N 9 52 E 6064.05 N 1055.17 E 6155 ~7 N 9 52 E 6167 29 N 1075.51E 6260 36 N 9 54 E 6267:34 N 1096,34 E 6362,51 N 9 55 E TBU ~"30 MCA'RTHI]R RIVER KENAI, ALASKA TRUE SUB-SEA COURSE ~ERTICAL YERTICAL DEVIATION' COMPUTATION DATE: 21-jUL-92 PAGE 8 DATE OF SURVEY~ 22-juN-g2 KELLY BUSHING EbEVATION~ ~60.00 FT EMGINEER: T, SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAl, DO~LE.~ RECTANGULAR COORDINATES HORIz, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,~ AZIMUTH DEPTD DEPTH DEPTH ~;83~i 33 ~060 O0 7900,00 47 59 . :~ .~16o oo 8o0o.oo 4s 56 .3775 8260 O0 8100.00 49 ~9~:~6 8360 O0 8200,0() 49 54 1447 87 8460 O0 8300,00 50 !5 1605 15 ~560.00 84OO'00 50 31 1763 56 8660.00 850o,00 5() 53 ~9~9 71 8760'00 8600,00 50 18 077 81 8860.00 8700.00 50 ~35 5~ 8960,00 2393 04 9060.00 8900,00 50 49 2~50 ~8 9160.00 9000.00 50 24 276 344~ 54 q760 O0 ~600,00 43 59 3577 96 9860~00 ~700,00 42 ii 3711.!~ 9960,00 9800,00 40 32 3841 60 1.0060,00 990().00 39 41 3969~a8 ~0160.00 10000'00 38 !2 4096 39 ~0260 O0 10100.00 37 42 4~2~4 10360~00 10200,00 3~ 40 4345 ~8 10460.00 !0300.00 35 5~ 4467:57 ~.0560.00 ~040(),00 ]4 4575,00 10649.14 ~U489,14 33 DEG SIN FEET OEG/100 EET FEET FEET DEG ~IN N 10 22 E b468,76 N !0 39 E 6581.6~ N !1 I0 E 6698.2~ N I1 5 E 6815,96 ~ 10 48 E 6935,1~ N 9 15 E 7056,57 ~ 9 4 E 7179,4! ~ 8 19 E 7300,61 ~ 7 55 E 7421,71 ~ 7 58 E 75~3 N 8 12 E 7665 23 N 7 5~ E 7786:39 N 8 0 E 7~906 22 ~ 8 50 E 8022,64 ~ 8 56 E 8135,06 N a 54 E 8 44~07. ~ 9 2q E 8444.76 N !0 34 F 8709 27 N ~1 i8 E 8789:58 N 11 29 E ~867,05 N 12 47 E 8941.55 N 13 4 E 9014.82 bt 1! 38 E 9085,31 N 10 26 E 9!45.09 0,60 1.78 0'99 !,30 !,32 0,77 15 1,01 0,66 1,78 1,91 0,69 1,25 0,43 0,41 2,35 0,75 1.06 2.17 0.59 0 10 0~56 1.02 2.!7 0,00 6371 :~ N ~1!7 40 E 6468 6482N 137 99 E 658t 6596 98 N t:160 20 E 6698 6712:44 N 1183.50 E 6815 6829 55 N 1205 69'5 6949 N 1226 ~ ~ 7056 7070 .42 N t246 30 E 7179 7190 25 N 1264,61E 7300 7431,01N 12~.8,39 7543 77 N 9 57 E 22 N 9 58 E 97 N 10 0 E 19 N 10 I E 58 N i0 I g 62 N E 72 N 9 57 E 59 N9 .55 F~ 7551 46 N 1315 75 E 7665,23 N 139 Ol 6'23 8016 63 N 1383 14 E 8 ~,07 70 E 82 ;:08 N 9 '53 E N 9 51 E N 9 49 E N 9 48 E N 9 47 E N 9 47 E 21 42 N !4 8122 @ N 14 o 8322 30 N 1433 8413 57 N 1449 8500,14 N 146'5 8582 47 N 8661 28 N 8737 24 N 8810 02 N 8881 50 N 8950,42 N 9009,17 N 49 E 8344 N 9 47 E 05 E 8444'79 N 9 46 E :80 E 8537,56 N 9 47 E 63 E.8625,57 N 9 47 E 1480,81 E 8709'28 N 9 47 E 1496,40 E 8789,59 N 9 48 E 1511,75 E 8867~06 N 9 49 E 15~8,07 E 8941~56 N 9 50 E 1544,67 E 9014,82 N 9 52 E 1559,77 E 9085'31 N 9 53 E 1570,83 E 9145,09 N 9 53 E KE~iA!, ALASKA 16" CASIN(; 9,6~5" CASING L~ST READING CCT D~ ! I, [,FIR S T D Cf3~P~TTA. TION DA.E: 21-dUb-g2 PAGE 9 DATE ~F SURVEY: 22-JUN-g2 KELLY BUSHING EbEVATION: 160.00 FT ENGINEER~ T. SMITH iNTERP[]LATED VALUES FOR CDOSEN HORIZONS SU}~FACE LOCATION = 967' FNb & 520' FWd, SEC3~ TDN RI~W MEASURED DEPTH TV[) BEt, OW KB FRO~ KB SUB-SEA RECTANGUSAR COORDINATES NORTH/SOUTH EAST/WEST 1439 O0 1436 .9~ !2:76.98 45,40 N 15'81 4223~00 3732~3 3572,33 !462'00 N 210,10 1,2247~00 8967.36 8807.36 7439,74 N 1299~61 1451.5.6© 10599.69 10439"69 8976;80 N ~564,$7 14575.00 10649.!4 10489.14 9009117 N i570~83 MARATMON OIL C MCA~TNUR RIVER KENAi, ALASKA KEbbY BUSHING E~EVATION: 16...000 FT ENGINEER~ T. SMITH ~*********** STRAT!GRAPHIC SUMMARY ************ SURFACE LOCATION : 967' FNL & 520' FWL, 8EC33 TgN R~3W ~EA, SLiRED DEPTH r,iO BEbOW K~ FRO~ KB SUB'SEA 1439,00 1436,98 1~'76,98 4223,00 373233 ~572,33 12247,00 8967~36 8807'36 4515,60 10599.69 10439'69 4575,00 10649.14 i0489,14 RECTANGUbAR COORDINATES NORTH/$OUTM EAST/WEST 1445'406~, N _15..8,. W ;oo N o. 8976', 80 N 1564' g 9009.' ~ N 1570,~7 3E FINAL WELL bOCATION AT TD: TRUE SUB-SEA MMASUR~ VERTICAL VERTICAL DEPTH DEPTH DEPTH ~ORIZONTAL DEPARTURE DISTANCE .AZIMUTH FE~T DEG !4575.00 10649,~,4 10489.!4 9145.09 N 9 53 E ORIGINAL I SUB - S URFA CE DIRECTIONAL ~'~ UIDANCE r~ ONTINUOUS F~ OOL RECEIVED 1992 Alaska 0il & Gas Cons. Commission Anchorage Company MARATHON OIL COMPANY Well Name TBU M-.30 (967'FNL,520'FWL,SEC 33,T9N,R13W) Field/Location MCARTHUR RIVER~ KENAI~ ALASKA Job Reference No. 92437 Logqed By: T. SMITH RECEIVED SEP O 8 1992 Alaska 0il & Ga~ Cons. Commission Anchorage Date 22-JUN-1992 Computed By: R. KRUWELL I I I · SCHLUMBERGER . GCT DIRECTIONAL SURVEY CUSTOMER LISTING -) FOR MARATHON 0IL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA SURVEY DATE' 22-JUN-92 ENGINEER' T. SMITH METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimu%h INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 9 DEG S4 MIN EAST COMPUTATION DATE: 21-JUL-92 PAGE I MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY: 22-JUN-92 KELLY BUSHING ELEVATION' 160.00 FT ENGINEER' T. SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 200 300 400 500 600 70O 800 900 0.00 -160 O0 0 0 N 0 0 E O0 100 O0 -60 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 799 O0 899 O0 40 O0 140 O0 240 O0 340 O0 440 O0 540 97 639 90 739 O0 0 10 S 85 33 E O0 0 15 S 10 10 W O0 0 15 S 20 4 E O0 0 47 N 53 27 E O0 0 58 N 37 51E O0 0 47 N 3 21W O0 I 46 N 41 53 W 97 2 14 N 50 29 W 90 2 1 N 47 3 W 0 O0 -0 31 -0 50 -0 95 -0 95 0 45 1 97 3 53 5 48 7 46 0 O0 0 5O 0 2O 0 O0 1 18 0 37 1 O4 1 27 0 O0 0 65 0.00 N 0.42 S 0 62S 1 08S 1 17S O04N 148N 324N 570N 8 20N 0.00 E 0.59 E 0.64 E 067 E 117 E 237 E 298 E 1 96 E 075W 3 58W 0.00 N 0 0 E 0.72 S 54 52 E 0.89 S 46 12 E 1.27 S 31 44 E 1 65 S 45 12 E 2 37 N 89 2 E 3 33 N 63 41 E 3 79 N 31 6 E 5 75 N 7 33 W 8 95 N 23 36 W 1000 O0 ggg 86 839.86 1 37 N 45 40 W 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1099 O0 1199 O0 1299 O0 1398 O0 1497 O0 1595 O0 1593 79 939 79 3 5 N 35 29 W 53 1039 53 4 41 N 21 41W 13 1139 13 5 48 N 13 7 W 39 1238 39 8 1 N 3 9 W 22 1337 22 9 30 N 1 33 W 51 1435 51 11 45 N 2 39 E 06 1533 06 13 30 N 5 31E O0 1790 O0 1886 9 24 11 33 17 05 24 99 36 50 51 39 69 56 91 40 O1 14 51 N 8 42 E 115.86 44 15 56 N 10 22 E 142.35 O1 1630 44 1726 0 O0 3 33 0 86 2 43 I 78 I 68 2 38 I 46 I 13 I O3 10 38 N 12 19 27 39 54 73 95 119 145 5 75 W 11 87 N 29 0 W 93 N 8 29 N 11 82 N 14 77 N 15 98 N 16 39 N 15 29 N 14 60 N 11 71N 6 23 W 15 34 W 22 og W 31 55 W 42 15 W 57 92 W 75 37 W 96 38 W 120 92 W 145 33 N 32 28 W 38 N 30 28 W 19 N 26 51W 70 N 21 22 W 30 N 16 22 W 10 N 12 14 W 36 N 8 34 W 14 N 5 26 W 87 N 2 43 W 2000 O0 1982.34 1822 34 17 5 N 10 18 E 170.67 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2077.38 1917 O0 2171.26 2011 O0 2264.11 2104 O0 2355.85 2195 O0 2446.41 2286 O0 2535.79 2375 O0 2623.59 2463 O0 2709.73 2549 O0 2794.17 2634 38 19 11 N 9 46 E 201.75 26 21 3 N 9 52 E 236.21 11 22 34 N 9 8 E 273.32 85 24 18 N 7 14 E 313.09 41 25 50 N 7 0 E 355.44 79 27 40 N 7 48 E 400.23 59 29 31 N 8 26 E 448.06 73 31 31 N 8 38 E 498.83 17 33 23 N 9 0 E 552.39 2. OS 2.31 2 13 2 O2 1 16 1 O6 2 93 1 60 1 56 1 93 173.57 N 1.80 W 173.58 N 0 36 W 204.18 N 3.57 E 204.21 N I 0 E 238.13 N 9.48 E 238.32 N 2 17 E 274.72 N 15.66 E 275 17 N 3 16 E 314 10 N 21.30 E 314 82 N 3 53 E 356 19 N 26.48 E 357 17 N 4 15 E 400 67 N 32.18 E 401 96 N 4 36 E 448 02 N 39.03 E 449 72 N 4 59 E 498 25 N 46.55 E 500 42 N 5 20 E 551 18 N 54.77 E 553 90 N 5 40 E 3000 O0 2876.84 2716 84 35 3 N 9 17 E 608 63 3100 3200 3300 34OO 3500 3600 3700 3800 3900 O0 2957.87 2797 O0 3036 73 2876 O0 3113 15 2953 O0 3187 29 3027 O0 3258 73 3098 O0 3327 15 3167 O0 3393 42 3233 O0 3459 28 3299 O0 3523 99 3363 87 36 47 N 9 55 E 667 73 39 6 N 9 48 E 728 15 41 13 N 9 24 E 793 29 43 13 N 9 26 E 860 73 45 38 N 9 18 E 930 15 47 46 N 9 51 E 1003 42 48 51 N 10 21 E 1078 28 49 5 N 10 0 E 1153 99 49 51 N g 42 E 1229 23 7O 19 29 24 17 O5 3O 54 0 85 1 1 1 2 3 2 0 1 0 606 72 N 63.66 E 610 05 N 5 59 E 66 664 88 725 63 788 39 854 26 923 10 995 32 1069 60 1143 80 1218 50 N 73 45 E 668 05 N 84 64 N 94 84 N 105 86 N 117 79 N 129 49 N 142 53 N 155 65 N 168 03 E 729 76 E 794 74 E 861 11E 931 15 E 1004 44 E 1078 86 E 1154 55 N 6 18 E 91 N 6 37 E 32 N 6 51E 36 N 7 3 E 26 N 7 13 E 13 N 7 23 E 93 N 7 35 E 10 N 7 46 E 84 E 1230.29 N 7 53 E COMPUTATION DATE: 2Z-JUL-92 PAGE 2 MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY' 22-JUN-92 KELLY BUSHING ELEVATION' 160.00 FT ENGINEER' T. SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3588 76 3428 76 49 28 N 9 49 E 1305 73 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3653 56 3493 O0 3717 64 3557 O0 3781 18 3621 O0 3844 45 3684 O0 3908 06 3748 O0 3971.71 3811 O0 4035.51 3875 O0 4099.92 3939 O0 4163.88 4003 56 50 0 N 9 30 E 1381 64 50 12 N 9 31 E 1458 18 50 41 N 9 25 E 1535 45 51 I N 9 9 E 1613 06 50 I N 9 8 E 1690 71 50 49 N 8 47 E 1767 51 49 52 N 8 45 E 1844 92 50 2 N 8 28 E 1921 88 50 27 N 8 16 E 1997 0.38 1293 74 N 181,77 E 1306 45 N 8 0 E 89 0.90 1368 66 0.01 1444 87 0.56 1520 30 0.95 1597 46 1.57 1673 58 1.82 1749 56 1.$1 1825 04 0.67 1901 88 0.43 1977 82 N 194.57 E 1382 55 N 207.17 E 1459 71 N 219.91 E 1536 13 N 232.39 E 1613 31N 244.68 E 1691 50 N 256.66 E 1768 60 N 268.40 E 1845 23 N 279.87 E 1921 29 N 291.03 E 1998 58 N 8 5 E 33 N 8 10 E 53 N 8 14 E 95 N 8 17 E 10 N 8 19 E 23 N 8 21E 23 N 8 22 E 72 N 8 22 E 59 N 8 22 E 5000 O0 4227.75 4067.75 50 10 N 8 37 E 2074 80 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4291.86 4131.86 50 7 N 8 41E 2151 O0 4356.15 4196.15 49 59 N 8 44 E 2228 O0 4420.36 4260.36 50 7 N 8 35 E 2304 O0 4485.17 4325.17 49 27 N 8 14 E 2380 O0 4549.78 4389.78 49 36 N 8 0 E 2457 O0 4614.96 4454.96 49 4 N 8 21 E 2532 O0 4680.71 4520.71 49 7 N 8 40 E 2608 O0 4746.35 4586.35 48 48 N 9 7 E 2683 O0 4811.94 4651.94 49 15 N 9 45 E 2759 53 11 76 88 17 98 29 72 21 0 39 2053.39 N 302 33 E 2075 53 N 8 23 E 16 2129.26 N 313 29 2204 97 N 325 29 2280 76 N 337 18 2356 08 N 348 84 2431 64 N 359 41 2506 72 N 369 27 2581 22 N 381 92 2655 77 N 392 04 2730 25 N 404 91E 2152 56 E 2228 13 E 2305 32 E 2381 07 E 2458 80 E 2533 05 E 26O9 59 E 2684 88 E 2760 28 N 8 23 E 88 N 8 24 E 54 N 8 24 E 69 N 8 25 E 01 N 8 24 E 85 N 8 24 E 19 N 8 24 E 63 N 8 25 E 11 N 8 26 E 6000 O0 4876 80 4716 80 49 43 N 9 57 E 2835.32 6100 62O0 6300 64O0 6500 6600 6700 6800 6900 O0 4941 O0 5006 O0 5070 O0 5134 O0 5199 O0 5263 O0 5326 O0 5390 O0 5453 73 4781 43 4846 61 4910 81 4974 29 5039 44 5103 99 5166 28 5230 70 5293 73 49 21 N 10 1E 2911.37 43 49 50 N 10 28 E 2987.61 61 50 6 N 11 12 E 3064.29 81 49 54 N 11 27 E 3140 93 29 49 49 N 11 24 E 3217 34 44 50 20 N 11 30 E 3294 03 99 50 51 N 11 33 E 3371 21 28 50 33 N 11 45 E 3448 59 70 50 36 N 11 53 E 3525 87 7000 O0 5517 27 5357 27 50 23 N 12 6 E 3603 O1 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5581 O0 5645 O0 5710 O0 5775 O0 5841 O0 5908 O0 5975 O0 6040 O0 6105 21 5421 71 ,5485 73 5550 87 5615 98 5681 98 5748 03 5815 33 5880 45 5945 21 49 48 N 12 15 E 3679 71 49 38 N 12 29 E 3756 73 49 31 N 12 38 E 3832 87 48 58 N 12 27 E 3907 98 48 16 N 11 36 E 3982 98 47 55 N 10 19 E 4057 03 49 8 N 10 6 E 4132 33 49 22 N 10 8 E 4207 45 49 29 N 10 5 E 4283 84 19 09 87 84 07 14 88 77 0 59 2805 23 N 417 92 E 2836 19 N 8 28 E 0 32 288O 1 58 2955 0 48 3030 0 63 3105 0 34 3180 0 29 3255 0 89 3331 0.53 3407 0.67 3482 13 N 431 19 N 444 47 N 459 64 N 474 57 N 489 75 N 504 41N 520 23 N 535 91N 551 18 E 2912 56 E 2988 18 E 3065 24 E 3141 39 E 3218 61E 3294 02 E 3371 65 E 3449 51E 3526 22 N 8 31E 44 N 8 33 E 06 N 8 37 E 64 N 8 41 E O0 N 8 45 E 63 N 8 49 E 75 N 8 52 E 08 N 8 56 E 30 N 9 0 E 0.41 3558.41 N 567 56 E 3603 39 N 9 4 E 70 E 3680 O1E 3756 54 E 3832 09 E 3908 83 E 3983 74 E 4057 97 E 4132 30 E 4208 63 E 4283 0.57 3633.59 N 583 1 15 3708.25 N 600 0 62 3782.41 N 616 0 90 3856.45 N 633 1 34 3929.81 N 648 1 39 4002.73 N 662 0 33 4076.63 N 675 0 84 4151.18 N 689 1 34 4225.89 N 702 18 N 9 8 E 48 N 9 11 E 33 N 9 15 E 06 N 9 19 E O1 N 9 23 E 22 N 9 24 E ~ o: o r'r'l 29 N 9 25 E ~ ~ c,~ _,._ 02 N 9 26 E ~.~? ~ 91 N 9 26 E c3 cD MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI , ALASKA COMPUTATION DATE: 21-JUL-92 PAGE 3 DATE OF SURVEY: 22-JUN-92 KFLIY BUSHING ELEVATION: 160.00 FT ENGINEER: T. SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6169 99 6009.99 49 43 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6234 O0 6298 O0 6362 O0 6425 O0 6489 O0 6552 O0 6616 O0 6679 O0 6744.36 6584 69 6074.69 50 2 72 6138.72 50 12 33 6202 33 50 44 68 6265 68 50 31 26 6329 26 50 34 67 6392 67 50 36 12 6456 12 50 30 74 6519 74 50 18 36 49 32 N 10 10 E 4360.15 N 10 10 E 4436.40 N 10 6 E 4513.21 N 10 I E 459O 37 N 10 13 E 4667 75 N 10 24 E 4744 93 N 10 53 E 4822 25 N 11 24 E 4899 53 N 11 36 E 4976 64 N 11 15 E 5052 93 66 28 69 45 97 28 99 13 1,5 30 4301.08 N 716.10 E 4360.29 N 9 27 E 4376 14 N 729.49 E 4436.53 N 9 28 E 4451 4527 4603 4679 4755 4831 4907 4982 76 N 743.00 E 4513.34 N 9 29 E 74 N 756.45 E 4590.49 N 9 29 E 92 N 769.99 E 4667.87 N 9 30 E 85 N 783.81 E 4745.04 N 9 30 E 87 N 798.01 E 4822.35 N 9 32 E 70 N 812.97 E 4899.62 N 9 33 E 29 N 828.38 E 4976.72 N 9 35 E 09 N 843.53 E 5053.00 N 9 37 E go00 O0 6809.27 6649 27 49 4 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 6875.42 6715 O0 6942.07 6782 O0 7009.10 6849 O0 7076.71 6916 O0 7144.87 6984 O0 7212.80 7052 O0 7280.46 7120 O0 7349.24 7189 O0 7418.65 7258 42 48 18 07 48 1 10 47 43 71 47 7 87 47 10 80 47 30 46 47 12 24 45 50 65 46 30 N 11 8 E 5128 98 N 11 46 E 5203 N 11 41E 5278 N 11 58 E 5352 N 11 47 E 5426 N 11 3O E 5499 N 11 37 E 5572 N 11 5 E 5646 N 10 38 E 5718 N 10 8 E 5790 95 46 63 27 41 76 37 94 93 0 76 0 32 0 42 0 79 I 41 0 39 I 13 I 36 I 92 0.85 5056 74 N 858 18 E 5129 04 N 9 38 E 5130 5203 5275 5347 5419 5491 5563 5634 5705 22 N 873 22 N 888 84 N 903 96 N 918 64 N 933 51N 948 72 N 962 97 N 976 83 N 989 16 E 5204 27 E 5278 59 E 5352 64 E 5426 36 E 5499 19 E 5572 57 E 5646 46 E 5718 14 E 5790 O0 N 9 40 E 50 N 9 41E 66 N 9 43 E 29 N 9 45 E 42 N 9 46 E 77 N 9 48 E 37 N 9 49 E 94 N 9 50 E 93 N 9 50 E 10000 O0 7487.46 7327 46 46 33 10100 10200 10300 10400 lO500 10600 10700 10800 10900 O0 7556 21 7396 O0 7624 O0 7692 O0 7760 O0 7829 O0 7898 O0 7968 O0 8037 O0 8104 44 7464 12 7532 54 7600 26 7669 63 7738 89 7808 64 7877 21 46 20 44 47 29 12 47 11 54 46 43 26 46 12 63 45 51 89 45 20 64 47 46 39 7944.39 48 32 N 10 30 E 5863.49 N 10 52 E 5936.10 N 10 15 E 6009.20 N 10 10 E 6082.81 N 10 51 E 6155.74 N 11 11E 6228.37 N 11 42 E 6300.37 N 12 13 E 6371.48 N 10 40 E 6444.04 N 10 30 E 6518.50 O. 62 0.25 0.54 0 52 0 91 0 49 I 20 I 47 1 58 0 75 5777.22 N 1002 13 E 5863.49 N 9 50 E 5848.58 N 1015 58 E 5936.11 N 9 51E 5920.44 N 1029 01E 6009.20 N 9 52 E 5992.90 N 1042 01 E 6082.82 N 9 52 E 6064 61N 1055 27 E 6155 74 N 9 52 E 6135 90 N 1069 28 E 6228 37 N 9 53 E 6206 51N 1083 48 E 6300 37 N 9 54 E 6276 12 N 1098.23 E 6371 48 N 9 56 E 6347 22 N 1112.90 E 6444 05 N 9 57 E 6420 44 N 1126.41 E 6518 50 N 9 57 E 11000 O0 8170 36 8010 36 49 12 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 8235 42 8075 O0 8300 41 8140 O0 8364 98 8204 O0 8429 24 8269 O0 8493 30 8333 O0 8556.72 8396 O0 8619.87 8459 O0 8682.98 8522 O0 8746.76 8586 42 49 14 41 49 26 98 49 50 24 50 5 30 50 25 72 50 31 87 50 59 98 50 53 76 50 13 N 10 44 E 6593 65 N 11 3 E 6669 N 11 36 E 6745 N 11 i E 6821 N 10 50 E 6898 N 9 55 E 6975 N 9 14 E 7052 N 9 19 E 7130 N 8 54 E 7207 N 8 27 E 7284 58 55 88 49 28 59 12 69 69 2 01 0 49 0 57 I 52 3 71 I 5O 0 71 0 91 I 22 0 56 6494 31 N 1140.22 E 6593 65 N 9 57 E 6568 6643 6718 6793 6869 6945 7021 7098 7174 87 N 1154 69 E 6669 40 N 1169 25 N 1184 53 N 1198 O0 N 1213 25 N 1225 76 N 1238 36 N 1250 50 N 1262 54 E 6745 64 E 6821 92 E 6898 11E 6975 84 E 7052 44 E 7130 72 E 72O7 58 N 9 58 E 56 N 9 59 E 89 N 10 0 E 51 N 10 1E 30 N 10 I E 60 N 10 I E 14 N 10 0 E 70 N 10 0 E 28 E 7284.70 N 9 59 E ) COMPUTATION DATE- 21-JUL-92 PAGE 4 MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY: 22-JUN-92 KELLY BUSHING ELEVATION' 160.00 FT ENGINEER' T SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12000 O0 8810 52 8650.52 50 30 12100 12200 32300 12400 12500 12600 12700 12800 12900 O0 8874 O0 8937 O0 9001 O0 9064 O0 9128 O0 9191 O0 9255 O0 9320 O0 9386 O8 8714 08 50 40 33 8777 33 50 34 13 8841 13 50 41 40 8904 40 50 48 05 8968 05 50 18 84 9031 84 50 15 93 9095 93 49 47 81 9160.81 49 15 45 9226.45 48 44 N 7 58 E 7361 69 N 7 52 E 7438 85 N 7 56 E 7516 N 8 11E 7593 N 8 9 E 7670 N 7 56 E 7747 N 7 59 E 7824 N 7 58 E 7901 N 8 37 E 7977 N 8 42 E 8052.89 26 23 63 71 68 40 46 0 13 1 09 1 62 0 68 0 65 1 85 0 57 1 58 1 44 0 5O 7250 76 N 1273 24 E 7361.70 N 9 58 E 7327 7403 7480 7556 7633 7709 7785 7860 7935 21N 1283 93 N 1294 18 N 1305 81N 1316 19 N 1327 47 N 1337 51 N1348 79 N 1359 36 N 1370 93 E 7438.85 N 9 56 E 61E 7516.26 N 9 55 E 35 E 7593.23 N 9 54 E 52 E 7670.63 N 9 53 E 21 E 7747.71 N 9 52 E 80 E 7824.68 N 9 51 E 35 E 7901.41 N 9 50 E 39 E 7977.47 N 9 49 E 89 E 8052.90 N 9 48 E 13000 O0 9453 03 9293.03 47 28 13100 13200 13300 13400 13500 13600 13700 13800 13900 O0 9521 O0 9590 O0 9660 O0 9730 O0 9802 O0 9876 O0 9951 O0 10028 O0 10105 07 9361.07 46 41 48 9430.48 45 58 28 9500 28 45 44 35 9570 35 44 54 49 9642 49 42 51 35 9716 35 42 0 51 9791 51 40 39 O1 9868 O1 39 38 32 9945 32 38 43 N 8 46 E 8127 48 N 9 37 E 8200 N 9 46 E 8272 N 8 54 E 8344 N 8 52 E 8415 N 10 38 E 8484 N 10 23 E 8552 N 10 22 E 8618 N 10 31E 8682 N 11 11E 8746 76 74 35 67 91 32 28 67 09 1 07 1 66 0 80 0 40 2 34 1 68 1 23 0 92 0 68 1 12 8009.14 N 1381 96 E 8127 49 N 9 47 E 8081.44 N 1393 8152.40 N 1406 8223.08 N 1417 8293.58 N 1428 8361.83 N 1440 8428.10 N 1452 8492.99 N 1464 8556.32 N 1475 90 E 8200 05 E 8272 53 E 8344 43 E 8415 O9 E 8484 48 E 8552 32 E 8618 98 E 8682 8618.62 N 1487.89 E 8746 77 N 9 47 E 76 N 9 47 E 37 N 9 47 E 70 N 9 46 E 93 N 9 46 E 34 N 9 47 E 30 N 9 47 E 69 N 9 47 E 11 N 9 48 E 14000 O0 10183 76 10023 76 37 44 14100 O0 10262 95 10102 95 37 16 14200 O0 10343 04 10183 04 36 38 14300 O0 10423 47 10263 47 36 11 14400 O0 10504 57 10344 57 35 23 14500 O0 10586 93 10426 93 33 40 14575 O0 10649 14 10489 14 33 39 N 11 21E 8808 10 N 12 4 E 8869 13 N 12 47 E 8928 95 N 13 7 E 8988 28 N 12 26 E 9046 71 N 11 13 E 9103 38 N 10 26 E 9145 09 0 63 1 62 0 45 0 42 2 16 2 31 0 O0 8679 44 N 1500.05 E 8808 11 N 9 48 E 8739 25 N 1512 30 E 8869 14 N 9 49 E 8797 71 N 1525 28 E 8928 95 N 9 50 E 8855 61N 1538 64 E 8988 28 N 9 51E 8912 62 N 1551 80 E 9046 71 N 9 53 E 8968 13 N 1563 38 E 9103 38 N 9 53 E 9009 17 N 1570 83 E 9145 09 N 9 53 E o -', o O:D ._.. o rtl COMPUTATION DATE' 21-JUL-92 PAGE MARATHON OIL COMPANY 'rBu M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY: 22-JUN-g2 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER. T. SMITH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 30O0 4000 5000 6000 7000 8000 9000 0 O0 -160 O0 0 0 N 0 0 E O0 999 86 839 O0 1982 34 1822 O0 2876 84 2716 O0 3588 76 3428 O0 4227 75 4067 O0 4876.80 4716 O0 5517.27 5357 O0 6169.99 6009 O0 6809.27 6649 0.00 86 I 37 N 45 40 W 9.24 34 17 5 N 10 18 E 170.67 84 35 3 N 9 17 E 608.63 76 49 28 N 9 49 E 1305.73 75 50 10 N 8 37 E 2074,80 80 49 43 N 9 57 E 2835.32 27 50 23 N 12 6 E 3603.01 99 49 43 N 10 10 E 4360.15 27 49 4 N 11 8 E 5128.98 0 O0 0 2 0 0 0 0 0 0 0 0 O0 N O0 10 05 173 85 606 38 1293 39 2053 59 2805 41 3558 66 4301 76 5056 0 O0 E 38 N 5 57 N 1 72 N 63 74 N 181 39 N 302 23 N 417 41N 567 08 N 716 74 N 858 000 N 0 OE 75 W 11 8O W 173 66 E 610 77 E 1306 33 E 2075 92 E 2836 56 E 3603 10 E 4360 18 E 5129 87 N 29 0 W 58 N 0 36 W 05 N 5 59 E 45 N 8 0 E 53 N 8 23 E 19 N 8 28 E 39 N 9 4 E 29 N 9 27 E 04 N 9 38 E 10000 O0 7487 46 7327 46 46 33 N 10 30 E 5863.49 11000 O0 8170 36 8010 36 49 12 N 10 44 E 6593.65 12000 O0 8810 52 8650 52 50 30 N 7 58 E 7361.69 13000 O0 9453 03 9293 03 47 28 N 8 46 E 8127.48 14000 O0 10183 76 10023 76 37 44 N 11 21E 8808.10 14575 O0 10649 14 10489 14 33 39 N 10 26 E 9145.09 0 62 5777 22 N 1002.13 E 5863 49 N 9 50 E 2 01 6494 31N 1140.22 E 6593 65 N 9 57 E 0 13 7250 76 N 1273.24 E 7361 70 N 9 58 E I 07 8009 14 N 1381.96 E 8127 49 N 9 47 E 0 63 8679 44 N 1500.05 E 8808 11 N 9 48 E 0 O0 9009 17 N 1570.83 E 9145 09 N 9 53 E COMPUTATION DATE' 21-JUL-g2 PAGE 6 MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY- 22-JUN-92 KELLY BUSHING ELEVATION- 160.00 FT ENGINEER- T. SMTTH INTERPOLATED VALUES FOR EYEN 1OO FEEl' OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 160 260 360 460 560 660 760 860 960 0.00 -160.00 0 0 N 0 0 E O0 160.00 0.00 0 9 S 4 9 W O0 260.00 100.00 0 16 S 5 31E O0 360.00 200.00 0 20 S 68 41 E O0 460.00 300.00 I 1 N 45 16 E O0 560.00 400.00 0 51 N 16 56 E O0 660.,00 500.00 1 16 N 33 22 W O0 760.00 600.00 2 12 N 49 15 W 07 860.00 700.00 2 10 N 47 28 W 13 960.00 800.00 I 42 N 43 28 W 0 O0 -0 36 -0 78 -1 15 -0 14 I 40 2 83 4 71 6 67 8 57 0 O0 0 28 0 O0 2 36 0 O0 0 76 I 22 0 37 0 31 0 40 0.00 N 0.00 E 0.49 S 0.67 E 0 0,90 S 0.63 E 1 1.31 S 0.83 E 1 0.48 S 1,91 E 1 0.92 N 2.90 E 3 2.41 N 2.61 E 3 4.70 N 0.43 E 4 7.21 N 2.51 W 7 9.57 N 4.96 W 10 0 O0 N 0 OE 83 S 54 3 E 10 S 34 57 E 55 S 32 24 E 97 S 75 58 E 04 N 72 28 E 55 N 47 12 E 72 N 5 15 E 63 N 19 13 W 77 N 27 23 W 1060.17 1060 O0 900 O0 2 1 N 46 56 W 1160.34 1160 O0 1000 1260.69 1260 O0 1100 1361.26 1360 O0 1200 1462.29 1460 O0 1300 1563.78 1560 O0 1400 1666.03 1660 O0 1500 1768.98 1760 O0 1600 1872.53 1860 O0 1700 1976.65 1960 O0 1800 10.23 O0 4 18 N 24 31W O0 5 13 N 17 25 W 21 O0 7 15 N 5 32 W 31 O0 8 55 N 2 10 W 45 O0 10 56 N 1 16 E 62 O0 12 58 N 4 30 E 83 O0 14 27 N 7 34 E 108 O0 15 37 N 10 6 E 134 O0 16 43 N 10 24 E 163 14 43 59 51 48 50 65 O1 88 89 1.50 1.58 1.69 2.80 1.42 2.86 1.45 1.66 1.38 1.19 11 63 N 7 10 W 13 62 N 31 24 W 16 41 N 10 14 W 19 29 N 31 42 W 24 20 N 13 09 W 27 51 N 28 25 W 34 64 N 15 19 W 37 82 N 23.40 W 48 95 N 15 95 W 51 48 N 18 3 W 66 27 N 16 17 W 68 21 N 13 43 W 87.54 N 15 05 W 88.82 N 9 45 W 111.83 N 12 49 W 112.52 N 6 22 W 138.35 N 8.24 W 138.61 N 3 25 W 166.89 N 3.01W 166.92 N I 2 W 2081.61 2060.00 1900 O0 18 45 N 9 44 E 195.77 2187.94 2160.00 2000 2295.54 2260.00 2100 2404.55 2360,00 2200 2515.10 2460.00 2300 2627.41 2560.00 2400 2742.01 2660.00 2500 2859.28 2760.00 2600 2979.47 2860.00 2700 3102.66 2960.00 2800 O0 20 48 N 9 54 E 231 89 O0 22 29 N 9 13 E 271 O0 24 22 N 7 10 E 314 O0 26 0 N 7 2 E 362 O0 28 13 N 8 8 E 413 O0 30 20 N 8 30 E 469 O0 32 32 N 8 52 E 530 O0 34 45 N 9 9 E 596 O0 36 49 N 9 55 E 668 61 95 02 07 01 24 90 82 3230.11 3060 O0 2900 O0 39 42 N 9 40 E 747 81 3362.84 3160 3501.80 3260 3649 29 3360 3801 11 3460 3955 69 3560 4110 02 3660 4266 55 3760 4424 64 3860 4581 47 3960 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 42 24 N 9 26 E 835 O0 45 42 N 9 18 E 931 O0 48 37 N 10 19 E 1039 O0 49 6 N 10 0 E 1154 O0 49 37 N 9 48 E 1272 O0 50 4 N 9 27 E 1389 O0 50 43 N 9 29 E 1509 O0 50 48 N 9 9 E 1632 O0 50 51 N 8 50 E 1753 06 53 92 14 O1 57 99 42 21 2.52 I 76 2 18 0 84 1 24 I 34 2 30 2 14 1 83 1 66 2 34 2 O9 3 31 1 1 0 0 0 0 1 198 29 N 2.55 E 198.30 N 0 44 E 233 87 N 8.74 E 234.03 N 2 8 E 273 03 N 15.39 E 273.46 N 3 14 E 315 95 N 21.54 E 316 68 N 3 54 E 362 73 N 27.29 E 363 75 N 4 18 E 413 39 N 33.96 E 414 78 N 4 42 E 468 75 N 42.11E 470 64 N 5 8 E 529 29 N 51.33 E 531 78 N 5 32 E 595 14 N 61.78 E 598 34 N 5 56 E 666 07 N 73.72 E 670 13 N 6 19 E = 03 743 88 N 87 26 E 748 99 N 6 41 E 829 95 N 101 61E 836 15 N 6 59 E ~m 0 r-T'l 925 13 N 117 32 E 932 54 N 7 14 E o ~ co 27 1031 97 N 135 59 E 1040 84 N 7 29 E 61 1144 36 N 156 O0 E 1154 94 N 7 46 E 32 1260 52 N 176 03 E 1272 75 N 7 57 E 51 1376 39 N 195 84 E 1390 26 N 8 6 E 47 1495 18 N 215 65 E 1510 65 N 8 12 E 87 1616 01N 235 43 E 1633 07 N 8 17 E 63 1735 30 N 254 46 E 1753 86 N 8 21E COMPUTATION DATE: 21-JUL-g2 PAGE 7 MARATHON OIL COMPANY TBUM-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY: 22-JUN-92 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: T. SMITH INTERPOLATED VALUES FOR EVEN 100 FEET Of SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/iO0 FEET FEET FEET DEG MIN 4737 97 4060.00 3900 O0 49 51 N 8 40 E 1873.56 4893 5050 5205 5361 5515 5668 5820 5974 6128 91 4160.00 4000 31 4260.00 4100 gg 4360.00 4200 34 4460.00 4300 73 4560.00 4400 45 4660.~00 4500 74 4760.00 4600 01 4860.00 4700 10 4960.00 4800 O0 50 28 N 8 16 E 1993.19 O0 50 7 N 8 42 E 2113.40 O0 50 0 N 8 43 E 2232.70 O0 49 20 N 8 27 E 2351 55 O0 49 27 N 8 I E 2469 12 O0 48 51 N 8 41 E 2584 50 O0 48 56 N 9 13 E 2699 33 O0 49 45 N 9 55 E 2815 49 O0 49 32 N 9 59 E 2932 72 0.75 1854.27 N 272.80 E 1874 23 N 8 22 E 0.31 1972.65 N 290.35 E 1993 90 N 8 22 E 0.13 2091.57 N 308.15 E 2114 15 N 8 23 E 0.26 2209.51 N 326.25 E 2233 47 N 8 24 E I 01 2327.04 N 344.07 E 2352 34 N 8 25 E 1 23 2443.48 N 360.74 E 2469 97 N 8 24 E 0 53 2557.69 N 377.46 E 2585.39 N 8 24 E 0 60 2671.18 N 395.08 E 2700.24 N 8 25 E 0 60 2785.70 N 414.50 E 2816.37 N 8 28 E I 46 2901.15 N 434,89 E 2933.56 N 8 32 E 6283 44 5060.00 4900.00 50 9 N 11 12 E 3051.58 6439 6594 6752 6909 7067 7222 7375 7527 7677 08 5160 O0 $O00.O0 49 52 N 11 27 E 3170.81 62 5260 25 5360 92 5460 01 5560 O3 5660 77 5760 O1 5860 05 5960 O0 5100.00 50 19 N 11 30 E 3289.89 O0 5200.00 50 43 N 11 39 E 3411.69 O0 5300.00 50 36 N 11 55 E 3533.53 O0 5400.00 50 11 N 12 8 E 3654.59 O0 5500.00 49 26 N 12 34 E 3772.94 O0 5600.00 49 11 N 12 34 E 3889.58 O0 5700.00 48 3 N 11 7 E 4002.96 O0 5800.00 49 2 N 10 5 E 4114.80 0 42 3018.00 N 456.71 E 3052.36 N 8 36 E 62 3134 93 N 480.18 E 3171 49 N 8 43 E 36 3251 46 3371 72 3490 54 3608 83 3724 O5 3838 05 3949 50 4059 70 N 503.78 E 3290 08 N 528.15 E 3412 41N 553.09 E 3533 89 N 578.36 E 3654 62 N 603.65 E 3773 58 N 629.13 E 3889 54 N 652.79 E 4003 55 N 672.93 E 4114 49 N 8 48 E 20 N 8 54 E 96 N 9 0 E 94 N 9 6 E 22 N 9 12 E. 79 N 9 18 E 12 N 9 23 E 95 N 9 25 E 7830 24 6060 O0 5900 O0 49 27 N 10 7 E 4230.84 7984 8139 8296 8453 8611 8769 8924 9076 9226 54 6160 52 626O 32 6360 91 6460 55 6560 O0 6660 15 6760 82 6860 81 6960 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 49 49 N 10 11E 4348 36 O0 50 15 N 10 8 E 4466 76 O0 50 44 N 10 0 E 4587 53 O0 50 32 N 10 19 E 4709 32 O0 50 35 N 10 59 E 4831 O0 50 32 N 11 34 E 4952 O0 49 45 N 11 7 E 5071 O0 48 20 N 11 44 E 5186 O0 48 1 N 11 49 E 5298 17 76 33 65 38 0.81 4173.79 N 693.34 E 4230.99 N 9 26 E 0 33 4289.47 N 714.02 E 4348.49 N 9 27 E 93 4406.03 N 734 85 E 4466.88 N 9 28 E 51 4524.93 N 755 95 E 4587.65 N 9 29 E 13 4644.83 N 777 41E 4709.44 N 9 30 E 79 4764.63 N 799 70 E 4831.27 N 9 32 E 70 4883.88 N 823 58 E 4952.84 N 9 34 E 24 5000.14 N 847 10 E 5071.39 N 9 37 E 45 5113.27 N 869 64 E 5186.69 N 9 39 E 66 5222.73 N 892 33 E 5298.41 N 9 42 E 9375.40 7060.00 6900.00 47 21 N 11 44 E 5408.22 9522 24 7160.00 7000.00 47 7 N 11 36 E 5515.70 9669 9815 9960 10105 1O252 10399 10544 10687 83 7260 O0 7100.00 47 24 N 11 6 E 5624.20 44 7360 O0 7200 O0 45 43 N 10 23 E 5730.01 09 7460 O0 7300 O0 46 31 N 10 19 E 5834.52 51 7560 O0 7400 O0 46 23 N 10 51 E 5940.09 64 7660 O0 7500 O0 47 27 N 10 10 E 6048.01 22 7760 O0 7600 O0 46 42 N 10 50 E 6155.17 37 7860 O0 7700 O0 46 6 N 11 18 E 6260.36 37 7960 O0 7800.00 45 12 N 12 10 E 6362.51 0.48 5330 28 N 914.96 E 5408.24 N 9 44 E 0.48 5435 61 N 936.62 E 5515.71 N 9 47 E 0.41 5541 96 N 958.30 E 5624.20 N 9 49 E 1.79 5645 85 N 978.48 E 5730.01 N 9 50 E 0.32 5748 73 N 996.89 E 5834.53 N 9 50 E 0.59 5852 50 N 1016.33 E 5940.10 N 9 51E 0.87 5958 64 N 1035.88 E 6048.01 N 9 52 E 0.92 6064.05 N 1055.17 E 6155.17 N 9 52 E 0.49 6167.29 N 1075.51E 6260.36 N 9 54 E 0.90 6267.34 N 1096.34 E 6362.51 N 9 55 E COMPUTATION DATE' 21-JUL-g2 PAGE 8 MARATHON OIL COMPANY 'I"BU M-30 MCARTHUR RIVER KENAI, ALASKA DATE OF SURVEY' 22-JUN-92 KELLY BUSHING ELEVATION' 160.00 ET ENGINEER: T. SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 10833 33 8060.00 7900 O0 47 59 10984 11137 11292 11447 11605 11763 11920 12077 12235 18 8160 O0 8000 75 826O 26 8360 87 8460 15 8560 56 8660 71 8760 81 8860 52 8960 O0 8100 O0 8200 O0 8300 O0 8400 O0 850O O0 8500 O0 8700 O0 8800 O0 48 56 O0 49 31 O0 49 54 O0 50 15 O0 50 31 O0 50 53 O0 50 18 O0 50 33 O0 50 9 N 10 22 E 6468 76 N 10 39 E 6581 69 N 11 10 E 6698 22 N 11 5 E 6815 96 N 10 48 E 6935 18 N 9 15 E 7056 57 N 9 4 E 7179 41 N 8 19 E 7300 61 N 7 55 E 7421.71 N 7 58 E 7543.59 0 60 1 78 0 99 1 3O 1 32 0 77 0 55 0 67 1 15 1.01 6371 53 N 1117.40 E 6468.77 N 9 57 E 6482 6596 6712 6829 6949 7070 7190 7310 7431 57 N 1137 99 E 6581 70 N 9 57 E 98 N 1160 20 E 6698 44 N 1183 50 E 6815 55 N 1205 87 E 6935 18 N 1226 48 E 7056 42 N 1246 30 E 7179 25 N 1264 61E 7300 23 N 1281.57 E 7421 O1N 1298.39 E 7543 22 N 9 58 E 97 N 10 0 E 19 N 10 1E 58 N 10 1E 42 N 10 0 E 62 N 9 59 E 72 N 9 57 E 59 N 9 55 E 12393 04 9060 O0 8900 O0 50 49 12550 12706 12859 13010 13156 13299 13441 13577 13711 18 9160 31 9260 82 9360 30 9460 21 9560 60 9660 54 9760 96 9860 18 -9960 O0 9000 O0 9100 O0 9200 O0 9300 O0 9400 O0 9500 O0 9600 O0 9700 O0 50 24 O0 49 42 O0 48 57 O0 47 25 O0 45 47 O0 45 44 O0 43 59 O0 42 11 O0 9800.00 40 32 N 8 12 E 7665 23 N 7 52 E 7786 N 8 0 E 7906 N 8 50 E 8022 N 8 56 E 8135 N 9 45 E 8241 N 8 54 E 8344 N 9 29 E 8444 N 10 29 E 8537 N 10 21E 8625 39 22 64 06 31 07 76 54 55 0 66 1 78 1 91 0 69 1 25 0 43 0 41 2 35 0 75 1 06 7551.46 N 1315.75 E 7665.23 N 9 53 E 7671.52 N 1332.53 E 7786.39 N 9 51 E 7790.29 N 1349.01 E 7906.23 N 9 49 E 7905.46 N 1366.27 E 8022.65 N 9 48 E 8016.63 N 1383.14 E 8135.07 N 9 47 E 8121.42 N 1400.70 E 8241.32 N 9 47 E 8222.80 N 1417.49 E 8344.08 N 9 47 E 8322.30 N 1433.05 E 8444.79 N 9 46 E 8413.57 N 1449.80 E 8537.56 N 9 47 E 8500.14 N 1465.63 E 8625.57 N 9 47 E 13841.60 10060.00 9900.00 39 41 13969.88 10160.00 10000.00 38 12 14096.39 10260.00 10100.00 37 42 14221.14 10360.00 10200.00 36 40 14345.18 10460.00 10300.00 35 53 14467.57 10560.00 10400.00 34 8 14575.00 10649.14 10489.14 33 39 N 10 34 E 8709.27 N 11 18 E 8789.58 N 11 29 E 8867.05 N 12 47 E 8941.55 N 13 4 E 9014,82 N 11 38 E 9085.31 N 10 26 E 9145.09 2.17 O. 59 O. 10 0.56 1.02 2,17 0. O0 8582 47 N 1480 81 E 8709 28 N 9 47 E 8661 28 N 1496 40 E 8789 59 N 9 48 E 8737 24 N 1511 75 E 8867 06 N 9 49 E 8810 02 N 1528 07 E 8941 56 N 9 50 E 8881 50 N 1544 67 E 9014 82 N 9 52 E 8950 42 N 1559 77 E 9085 31 N 9 53 E 9009 17 N 1570 83 E 9145 09 N 9 53 E COMPUTATION DATE- 21-JUL-g2 PAGE 9 MARATHON OIL COMPANY TBUM-30 MCARTHUR RIVER KENAI, ALASKA MARKER 16" CASING 13.375" CASING 9.625" CASING LAST READING GCT DRILLERS TD DATE OF SURVEY: 22-JUN-92 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER' T. SMITH INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 967~ FNL & 520' FWL, SEC33 TgN R13W MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1439.00 4223.00 12247.00 14515.60 14575.00 1436.98 1276.98 3732.33 3572.33 8967.36 8807.36 10599.69 10439.69 10649.14 10489.14 45.40 N 15.81W 1462.00 N 210.10 E 7439.74 N 1299.61E 8976.80 N 1564.87 E 9009.17 N 1570.83 E COMPUTATION DATE' 21-JUL-92 PAGE 10 MARATHON OIL COMPANY TBU M-30 MCARTHUR RIVER KENAI, ALASKA MARKER 16" CASING 13.375" CASING 9,625" CASING LAST READING GCT DRILLERS 'rD DATE OF SURVEY' 22-JUN-92 KELLY BUSHING ELEVATION- 160.00 FT ENGINEER- T. SMITH ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 967~ FNL · 520~ FWL, SEC33 TgN R13W MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH FAST/WEST 1439.00 4223.00 12247.00 14515.60 14575.00 1436.98 1276.98 3732.33 3572.33 8967.35 8807.36 10S99.89 10439.69 10649.14 10489.14 45.40 N 15.81W 1462.00 N 210.10 E 7439.74 N 1299.61 E 8976.80 N 1564.87 E 9009.17 N 1570.83 E FINAL WELL LOCATION AT 'rD. TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14575.00 10649.14 10489.14 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9145.09 N 9 53 E DIRECTIONAL SURVEY COMPANY MARATHON OIL COMPANY FIELD MCARTHUR RIVER WELL TBU M-30 COUNTRY USA RUN I DATE LOGGED 22 - JUN - 92 DEPTH UNIT FEET REFERENCE 92437 RECEIVED SEP 0 8 1992 ^lask~ Oil & ~s Cons. Commission Anchorage WELL. TBU M-30 (967'FNL,520'FWL,SEC 33,T9N,R13W) HORIZONTAL PROJECTION ~ 1~000 1OOOO RECEIVED SEP 0 8 1992. Alaska Oil & Gas Cons. 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NO~' [t9 thc . - "' d ~~ ,,, I, / I 5 ~? . ,!,~ 101 , ~ , ........ ~ ] , , , 15] ...................... i '" 11] iii ii i i i ii i i i i i i~1 i ii i Unocal North Americar'-~.. Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DocUMENT ~SMITI'AL September 3, 1992 TO: Larry Grant FROM: Kirk Kiloh 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Trading Bay Unit M-30 Log Data 1 blue~ine and I sepia of the following: Mph 'UD Log TVD 2" ~ UD Log TMD 2" '/ t.~ asor Induction-SFL 2" and 5" combined ore Hole Compensated Sonic-GR 2" and 5" combined ment Eval Log 6-22-92 Cement Eval Log 6-24-92 ~/ ~ompensated Cement Bond Log VDC 6-24-92 ',/~ement Bond Log 6-21-92 J ~/Continuous Gyro 6-22-92 ~ P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION 1 Blue/line each of the following: 0' Gamma Ray-CCL 7-1-92 ~ ~/Gamma Ray-CCL 6-30-92 ~ Or~ 77 Open Hole EDIT LIS Tape and Listing GCT Directional Survey LIS Tape and Listing and ~hardcopies PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITI'AL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED BY: RECEIYED SEP 08 1992 DATED: Alaska Oil & Gas Cons. Commission Anchorage Unocal North Americr'-'~il & Gas Division Unocal Corporation 909 West 9th Avenue, P.~,. ctox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL R. C. Warthen Regional Manager Development Geology & Geophysics Alaska Region ORIGINAL DOCUMENT TRANSMITYAL July 23, 1992 HAND DELIVERED TO: Larry Grant 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION FROM: Kirk Kiloh P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: .Tradin~g__Bay Unit, McArthur River Field, Steelhead Platform, Cook Inlet, Alaska ~-30 well ?/.~ 6,~4/ 4 boxes of washed and dried cuts: Box 1 1050- 5280 Box 2 5280- 9060 Box 3 9150 - 1.2840 Box 4 12840- 14620 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAI~. THANK YOU. RE CE I~ED B~~___-~..~..,~ ~,,~....,~~~ REcEiVED . DATED. JUL 2 3 1992 Naska 0il & Gas Cons. Commission Anchorage TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C Sm~.~.~ commissione~- / DATE: FILE NO: June 26, 1992 lg626-5.doc Blair Wondzell P. I. Supervisor Louis R Grimaldi Petr Inspector TELEPHONE NO: SUBJECT: Rig/BOPE Inspection Marathon M-30 Steelhead Rig 7766578 Permit No. 91-64 Trading Bay Unit ~:L. June.~ 22 19__9_~ While on board Marathon's Steelhead Platform for safety valve tests, I made a rig/BOPE inspection on their rig which is presently drilling Well M-30. I found the rig to be in good shape with all BOPE equipment in place. We should note that the pumps on the accumulator set have been overhauled and the recharge time has been brought down to 4 minutes, 20 seconds. This is a much more acceptable time then over 7 minutes required on my last visit to this rig. In s~ummarv, the rig on the Steelhead appears to be in good shape and I could find no noncompliances. Attachment 02-00lA (Rev. 6789) 20/11LMEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report C- ~'~ TEST: Rep ,~, ~0~' csg set @ ft Location (general) ~oC5)~ Housekeeping (general) ~00~ Well sign ~ Rig ~ Rsrve pit ~_m~____~ MUD SYSTEMS: Flo; monitor BOPE STACK: Annular preventer Test Pressure ' 0 ~>~',~ /' Pipe rams 3 ~o 0~. / ~~F'~ Blind rams ..... ~~ 0 HCR Valve Kill llne valves Check valve ...-7 0~0 Initial__ Weekly/x<' Other · Rep, ACCUMULATOR SYSTEM: Full charge pressure, 0 Press after closure, / ~ Pump incr clos press 200 psig Full charge press attained psig psig min /~' sec min S~ sec N2 Controls: Master ~~~ Remote~ (5)~ B1 ind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly /' ' Lower Kelly Ball type ~F/~ ~ Inside BOP Choke manifold Number valves Number flanges 3 ~.~ Adjustable chokes Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test pressure TEST RESULTS: Fai 1 ures Test time ~ /~ hrs Repair or replacement of failed equipment to be made within __ days. Notify the Inspector, and follo~ with written/FAXed [276-7542] verification to Commission office. Distribution: ori g - AOGCC C - Operator c - Supervisor STATE WITNESS REOUI RED? J yes_ nojX~ j yes~ no j Waived by: C.004 (rev 03/92) TO: THRU: FROM: MEMORANDUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION ~ DATE: C S Lonnie May !3, 1992 Commiss ion FILE NO: ~i~ lg513-1, doc TELEPHONE NO: Blair Wondzell P~ I. Supervisor Louis R Grimald~- Petr Inspector SUBJECT: BOP Test-Steelhead Marathon M-30 Permit 91-64 Steelhead Platform McArthur Rv Field F__ridav_, A_p_~il ,26, .... 1992 I traveled to Marathon's Steelhead Platform in the Cook Inlet to witness their weekly BOP test while drilling Well M-30 in the McArthur River Field. The test went very well with no failures noted. The accumulator was slow in recharging (6 minutes, 55 seconds). Lance Lamens (Marathon Rep) will have the pumps oil the accumulator rebuilt before spudding the next hole. In summary, I witnessed a good BOP test on Marathon's Steelhead Rig drilling Well M-30. Attachment 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 ~ERATION: Drlg Compl~ Operator /'~1 ~ ~ !Ci' '~' '~t~ 0£~ Location: ~c ~,~ T ~ Drlg contr ~0~ ~ Location (gan'l), ~~~ ! N COMPL I ANCE; yes no n/a. A. DIVERTER 1. ( ) ( ) ~ 2.() () 3.() () ~~(~ ~.() () $.() () 6.() () ~ 7. ( ) ( ) {/~ 8.(~ () () S. () () lO./~' () () ~l.k~ () () ~2.~. () () 13. () () ~4-.I{ ( ) () is. () () ~6. ~f () () 17 (j~. ( ) ( ) ~8{~)'~ ( ) ( ) ~9. (~F~ ( ) ( ) 2o. (~T~' ( ) ( ) 2~ (~. ( ) () 22 ,. ( } {) .24. 25. 26. 27. 28. 29. 30. 31. ~2. () () () () () () () () () () () () () () REMARKS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report Wkvr U I C_~ R~ M ~ ~ mm Rig#~'h/ Well si gn ~ DATE: () () () () () () line sz & length line conn& anchored bifurcated & dwn wi nd 90° targeted turns vlvs: auto & simultaneous annular pack-off condi ti on B. BOP STAC~ wellhead flg wkg press stack wkg press annul ar preventer pi pe rams bl i nd rams stack anchored chke/kill line sz 90° turns targeted (chke & kill ln) HCR vlvs (chke &~ manual vlvs (ehke & kill) connections {flj~ whd, ~ drl spool fl ow ni ppl e fl ow monitor ' control 1 ines fi re protected C. CLOSING UNITS wkg press fluid level -. oprtg press press gauges sufficient vlvs regulator bypass 4-way vlv$ (actuators) blind handle cover drill er control panel remote control panel Representative Well name /;'~' '--' Representative I N COMPL I ANCE; yes no n/,.a 33. (~) () () 34. ( ) ( ) 35. ~.) () () 37. ) ( ) 38. ~ (() () 39. ) ( ) 40' ~i ) () 4~. ) ( ) 42. - ( ) ( ) 43.~/ ) () 44. ~'( ) ( ) 45. ~327 ( ) ( ) 46. ~( ) ( ) 47. ( ) ( ) 49. ( ) 5o.~ () 51 ( ) 52. (~ ( ) 53 ( ) 54.() () 55. ((~ () 56 ( ) 57. ~( ) 58 ( ) fi rewal 1 nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip tank E. RIG FLOOR kelly cocks (upper,lower,IBOP) floor vlvs (dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor flow rate indicator, pit lave' indicators, gauges) ki 11 sheet up-to-date gas ~etection monitors (H S & methane) hydr chke panel chke manifold F. MISC EQUIPMENT fl are/vent line 90° turns targeted (dwn strm choke lns) reserve pit tankage personnel protective equip avail all drl site suprvs trained for procedures H2S probes rig housekeeping RECORDS: Date of last BOP inspection:. / Resulting non-compliance: , , y~ J) /J~ Non-compliances not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? Kill sheet current? TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C Sm~:-~ Commissione~ ~ Blair Wondzelt h/~ P. I. Supervisor DATE: April 16, 1992 FILE NO: 1 g416 - 1. do c TELEPHONE NO: SUBJECT: Diverter Inspection Steelhead Rig 455 Permit 91-64 Marathon M-30 McArthur River Louis R Grimaldi Petr Inspector Tuesda .~_1 .2~ i~992_., thru ~atu_rday, April !1.: _19~2 I travelled to Marathon's Steelhead Platform in the Cook Inlet to witness the diverter test on this Platform's Rig 455, which was preparing to drill Well M-30. The test was not started until Wednesday, April 8, 1992 and failed due to the annular not closing completely'. After extensive trouble shooting, it was determined that the piston inside was not achieving full travel. The rig crew was unable to disassemble the preventer at first due to corrosion, but was successful after approximately 24 hours. After the annular preventer was repaired, a retest was attempted and subsequently failed, due to~ a low hydraulic fluid level in the accumulator. While the rig crew was filling the reservoir~ I requested they check the precharge on the accumulator bottles. Out of 24 bottles, 3 were found to be at 800 psi~ one had 0 psi, and the rest were fully charged at 1000 psi. The low bottles were recharged and the bladder was changed and recharged in the bottle that showed 0 psi. We attempted to retest and again failed. Although the annular preventer closed when the alternate vent line was selected, the annular preventer lost pressure and began to open° It was found that a short existed in the electrical harness leading from the driller's control panel (BOP). After repairing this, a fourth test was attempted and all functions of the diverter and related systems appeared normal. I passed the diverter assembly and okayed the rig to drill at this point. In summary~ after a long and arduous test, the rig on Marathon's Steelhead Platform was in compliance and passed to drill M-30. The problems that were encountered all appeared to be maintenance related and I feel that after the long holdup there will be enough incentive to attend to these items in the future by the rig personnel on a regular basis. Attachment 02-001A (Rev. 6/89) 20/1 lfMEMO1.PM3 BY:ARCO OlaERAT I ON: ; 4-15-[12 ; ~l:Ll~m~l ; ~,rr: ,'~,,.,,, ............. STATE OF' A~KA A~SKA 01L AND GA~ CO~ERVAT [ ON COMM I ~$ I0~ R~g/BOPE Inspection Report Repre~onta~Sve ~~ ., Z3. (~) ( ) ( ) ~. (') (;~ () 26, I~) () () 27. ,CX) () ( ) 29. () () so, (~3 () 3~.() Oq IN COHPLIANCE: A, DIYERTER y.~ ~ tine ~z & length 35, 0<~ ( ) ( ) line ecrm & anchored $~. ~ ( ) C ) bifurcated & d~* wlnd 35. ~ ( ) ( J 90° targeted turns vlvs: ai.~to A ~tmultane~ua ~nnular paok-off ~.. a0P STACg wellhead flg wkg stack wkg press an~uler prevemi~¢l' pi pe rams bl { nd stack anchored 90° turna targeted (chke & kill ln) HeR vlw (¢~ke & kill) manual vlvs (¢hke & kill) connections (flgd~ whd~ clmpd) dr1 flow nipple flow monStor control lines fire protected C. CLOSING UNITS wkg ~ress fluid level oprtg press pres& gauges sufficient vlvs regulator bypass ~-way vlvs (actuators) blind handle cover dr(Ilar centrol panel remote control pearl se. )7. 64 ~0. ~ ~2. ~ ~8. () ~. ix) so'.() 51.() .~. ( ) s~.() ss, ~) 56. ~0 s?. ~ t ! rewa 11 nitrogen power source (back-up' condition (leaks~ hoses, ere) D. MUD SYSTEM pit level floats installed flow rate sen~ors mud gas separator degas,er separator bypasa gas sensor chke In ~onn trip tank [, RIG FLOOR · kelly eoe. k~ (uppee,loweeslBOP) f~oor vlvs (dart vlvs ball vlv) kelly & floor vlv wrench~ drt 11 er' B consol e (fl o~ moni tot fl~w rab~ (ndJ~tor, pit; lave indicators, gauges) ki 11 ~hcot= up-:o-do~e gas ~eteotfon monitors (H-S & m¢~ha~) hydr chke panel chk~ man[ fold F .__ Ill I SC .iEQu I p,IVlENT fl ecu/vent l!~e 90 ° turn~ targeted (Uwn Rtrm choke reserve pit tankage personnel protec:tve equip avei' all drl site suprvs trained _for procedures HZ' p~obes rig housekeeping Resulting non-¢ompliance~ Non-compliances no~ corrected & w~y: gate corrections will be compJeted=__ ROP teme& r'eg~l[o properly u,~ered on daily record? ^~sK~ u, & Gas Cons. Commission Kill sheaf, current.* /(j/~chorage-- C. 0013 (,',ay " ' STATE OF ALASKA ' ALAbamA OIL AND GAS CONSERVATION COMMISb~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time ex'tens,on __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ! 5. Type of Well: · L Development ~ IIN~f"~l (M~v,~'l'hnn Fi-il P~ _ ~,,k ,q .... + t','l Exploratory ...................... ~v ~,.~ ~,e ~,~ ~,.~, i,.~ ~.. ! ~.~, ~,,.. F ~ /~ 3, Address Stratigraphic_ P.O. Box lq0247 AnchnranP Ak' qq~;l~j Service__ 4. Location of well at sudace Leg Bi, Slot 9 Steel head Platform 967'FL.N520' FWL, Sec. 33-gN-13W-SM 1,300' FSL I 800' FWL, Sec. 21-9N-13W-SM At effective depth ' ' At total depth 2,555' FNL, 2,049' FWL. Sec. 21-qN-1~W-~4 1--2. Present well conditiOn summary ' Total depth: measured 1,039 ' feet Plugs(measured) true vertical 1,039 ' feet Effective depth: measured feet Junk (measured) true vertical feet 6. Datum elevation (DF or KB) I ¢:;P,,VD 4r,,,.-..,, ~, , t.,t%/ i'~.1,~ i I ~/111 I'ILLII Unit or Property name T~,~d-lnn R~w lin'iT ...... ;2~ --~j ~ .... 8. Well number H-30 9. Permit number Casing Length Structural Conductor 40 7 ' Surface 966' Intermediate Production Liner Perforation depth: measured Size Cemented 10. ~ ~r~ber 50-- 7'~3- 20~30 11. Field/Poe McArthur River G-7nne/West Fore! and true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet 998' to 1,039' Measured depth True vertical depth 34" driven 480' 480' 26" yes 1,039' 1,039' RECEIVED 13. Attachments Description summary of proposal ~ Detailed operations program _.Z_ BOP sketch .,y,._ 14. Estimated date for commencing operation April 1, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil__ Gas__ Suspended__ Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~c~-_~_x, ~, ~_ ,~4:~ Title k"~e_%~,,.,,,.9,~ '~NN¢ FOR COMMfS,.SION USE O ~tions of ~(~rova(~otify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ .//. Mechanical Integrity Test __ Subsequent form required 10- '""r o ~' .~ ,.; ::.:!., ,"'.~-~'~.._,~ ~ ..¢. :. .. ,,-i~. 0RtGIN~,L S~GNED BY Approved by order of the Commission LONE~, ..... Commissioner Date Approval N~,/~ ~ _ ¢ ,,¢-~ / Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE /'-~DRILLING AND COMPLETION PROGR/'''''~ MARATHON OIL COMPANY ALASKA REGION WELL: M-30 LEG: B-1 SLOT: 9 FIELD: AFE No.: TYPE: Trading Bay Unit, Steelhead Platform 8365-1 G-WF water injector REVISION NO.: 1 DATE: 3/16/92 SURFACE LOCATION: 967'FNL,520'FWL, Sec.33,T9N,R 13W, S.M. TARGETS: G-Zone: 1300'FSL, 1800' FWL, Sec 21, T9N, R13W @ 8990' TVD W. Foreland: 2328'FSL, 1980' FWL, Sec 21, T9N, R13W @ 10160' TVD BOTTOMHOLE LOCATION: KB ELEVATION: 160 ft. GL ELEVATION: 2555'FNL, 2049' FWL, Sec 21, T9N, R13W @ 10833' TVD FORMATION AC-1 A-1 B-1 C-1 D-1 E-1 G-1 Hemlock West Foreland TOTAL DEPTH TYPE SIZE WT. CONDUCTOR: 26 ESTIMATED FORMATION TOPS: 397 AUXILIARY: 16 75 SURFACE: 13.375 13.375 61 DEPTH(MD) POTENTIAL DEPTH(TVD) CONTENT 1651 2700 3425 437O 4949 8156 12331 13200 13903 14688 1 650 gas/water 2620 gas/water 3200 gas/water 3830 gas/water 4205 gas/water 6310 gas/water 8990 oil/water 9600 oil/water 10160 oil/water 10680 CASING PROGRAM GRADE THREAD PRODUCTION: 9.625 47.0 9.625 53.5 SET SET FROM TO LINER: 7.00 29.0 X-56 Dril-quip Surf 1039' 1039'TVD K-55 BTC Surf 1452' 1450'TVD K-55 BTC Surf 2563' K-55 BTC 4247' 3750'TVD N-80 BTC Surf 7804' N-80 BTC 7804' 12269' 8950' TVD L-80 BUTTKC 12069' 14688' Page 1 10833'TVD ECEJVED A~'~chora§~ HOLE SIZE in place 17-1/2" U/R to 22" 12-1/4" U/Rto 17-1/2 12-1/4" 8-1/2" SIZE WEIGHT GRADE CASING DESIGN SETTING FRAC GRD DEPTH,TVD @ SHOE 26" 369# X-56 1039' 12 16" 75.0# K-55 1450' 12.1 13.375" 61.0# K-55 2500' 68.0# K-55 3750' > 14.0 9.625" 47.0# N-80 6080' 9.625" 53.5# N-80 8950' > 14.0 7" 29# L-80 10833' n/a FORM PRSS DESIGN FACTORS @SHOE MASP TENS COLL BURST 420 500 663 1077 12.6 1.48 3.23 4.7 1.32 1.24 1797 1532 14.7 1.11 2.08 2.9 1.3 1.3 4268 3223 9.1 1.3 1.8 4720 3559 2.3 24.6 31.7 DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, a 30"x 500 psi riser, and two 16" diverter lines each equipped with a 16" hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16"x 10000 psi outlet and a 3-1/16" x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1/16" 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 with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. Page 2 MUD PROGRAM DEPTH WEIGHT VISCOSITY WATER MUD TO ppg sec/qt LOSS TYPE 1450' 9.0-9.2 60-80 <30cc's Spud 4247' 9.2-9.4 40-50 <20cc's PHPA 14689' 9.4-9.8 40-50 < 10cc's PHPA Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of a Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30" series 300 MSS x 26" butt weld CASING HEAD: 30" 300 MSS x 21-1/4" 2000 psi FMC segmented clamp hub w/2" L P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16" 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports Page 3 CEMENTING PROGRAM AUXILIARY: 16"@ 1452' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 50/20 blend TLW/Micro matrix+5% microbond +6%salt+ 1.5#/sk FDP-C493-92 SURFACE 13.0 ppg. 1.45 cu. ft./sk 7.40 gal/sk 6 hrs:min 100 % 1410 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/1%FDP-C493-92 1240 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 4+ hrs:min 100 % 550 sx RUNNING 1. 2. 3. 4. 5. AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. Baker-lok float shoe. Fill pipe until circulating. Check float. M/U float collar. (Baker-lok top and bottom of float collar) Fill pipe until circulating. Run remaining casing (filling every joint) and land in the 30" MSS flange (install centralizers as per centralizer program) 6. Rig up false rotary and run and space out stab-in cementing string. 7. Secure drill pipe and circulate while reciprocating casing. 8. Continue circulating until no gains in circulating efficiency is made. 9. With as little shut down as possible, begin pumping spacer. 10. Pump spacer as follows: 40 bbls 18% NaCI (9.5 ppg) 20 bbls drill water 20 bbls Super Flush (increase if losing circulation)(9.2ppg) 20 bbls drill water 40 bbls 18% NaCI (9.5ppg) 12. Mix and pump 363 bbls of lead slurry (1410 sx). 13. Mix and pump 103 bbls of tail slurry (550 sx). Reciprocate casing as long as possible. 14. Displace drillpipe. 15. Check float. 16. Pull seals out of float shoe. 17. Pull out of hole w/d.p. 18. WOC 12 hours holding 75 psi on annulus. 19. N/D diverter 20. N/U unihead and BOP stack. Page 4 CEMENTING PROGRAM SURFACE: 13-3/8" @ 4247' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 50/20 blend TLW/Micro matrix + 5%microbond + 6% salt + 1.5#/sk FDP-C493-92 SURFACE 13.0 ppg. 1.45 cu. ft./sk 7.40 gal/sk 6 hrs:min 50 % 1750 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/1%FDP-C493-92 3500 ft. 15.8 ppg. 1.15 cu. ft./sk 5.0 gal/sk 3:10 hrs:min 50 % 740 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Pickup shoe joint. Baker-lok float shoe. Check float. Fill pipe until circulating. 3. M/U float collar.(Baker-lok top and bottom 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. Pump spacer as follows: 40 bbls 18% NaCl(9.5ppg) 20 bbls drill water 20 bbls Super Flush(9.2ppg) 20 bbls drill water 40 bbls 18% NaCl(9.Sppg) 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 450 bbls lead slurry. 10. Mix and pump 150 bbls of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 13-3/8" packoff. 14. WOC 12 hours holding pressure on annulus. 15. Test BOPE. Run intermediate wear bushing. Page 5 ~'~CEMENTING PROGRAM PRODUCTION: 9-5/8" @ 12269' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME TLW w/.45% Halad 344 +.35% Super CBL + .3% LWL+ .2% CFR-3 3747 ft. 13.2 ppg. 1.33 cu. ft./sk 6.70 gal/sk 5 hrs:min 30 % 1230 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/.33% Halad 344 + .35% SuperCBL + .4% HR-5 + .25%CFR-3 8100 ft. 15.8 ppg. 1.15 cu. ft./sk 5.0 gal/sk 4:00 hrs:min 30% 1970 sx 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 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. Pump spacer as follows: 40 bbls 18% NaCI( ppg) 20 bbls drill water 20 bbls Super Flush(ppg) 20 bbls drill water 40 bbls 18% NaCI(ppg) 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 290 bbls. lead slurry. 10. Mix and pump 403 bbls. of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 10-3/4" packoff. 14. WOC 12 hours. 15. Test BOPE. Page 6 ,'"~CEMENTING PROGRAM LINER: 7"@ 12069'-14688' LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/.4% Gas Stop + .25% SuperCBL + .12% LWL + .2% CFR-3 12268 ft. 15.6 ppg. 1.18 cu. ft./sk 5.2 gal/sk 4:00 hrs:min 30 % over caliper volume and 300' over T~L. 390 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. M/U float collar. (Baker-lok all connections below top of float collar) Fill pipe until circulating. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. M/U swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 81 bbls slurry. Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. Page 7 ~"-OIRECTIONAL PLAN N t'H MD TVD INCL AZIM COORD DESO RKB 0 0 0 0 o TIE-IN & KICKOFF END OF BUILD 992 992 1.2 N60.6W 11 Build @ 1.75 deg/100ft. 3804 3463 49.6 N9.9E 1151 START OF DROP END OF DROP 12331 8990 49.6 N9.9E 7547 Drop @ 1.00 deg/100 ft. 14290 10488 30.0 N9.9E 8776 TOTAL DEPTH EAST VERT COORD SECTION 0 0 -7 10 163 1162 1280 7655 1495 8902 14688 10833 30.0 N9.9E 8972 1529 9101 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) M-26 15 992 RLF-1 15 2114 RLF-2 32 1595 M-27 43 992 M-29 30 992 M-28 39 992 M-25 23 992 G -25 304 9094 G-31 274 6640 G-1 RD 183 6740 M-lST-1 108 1167 Note: Close approach to Relief well #1& #2 is across a portion of the relief wells that was not cased and was abandoned with a balanced cement plug, and therefore presents no true interference problem. CONDUCTOR: LOGGING PROGRAM No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: No logging is planned for this interval. LINER: COMPLETION: GR/SP/Cal/DIL/BHC from 14688'-12468'. Four arm caliper for cement volumes across open hole. A CBL/GR and a directional gyro s..urvey will be run prior to perforating. rage u DRILLING PROGRAM CONDUCTOR: to 500 psi. 26" casing in place. Weld on starting flange to 26" casing. N/u diverter and test AUXILIARY: Drill a 17-1/2" hole to 1452' RKB per the directional program. Underream hole to 22" from 975' to 1452'. Pull wear bushing. Run and cement 16" auxiliary casing. WOC. Back out and L/D landing joint. N/D diverter and install FMC Unihead w/16" pack-off and test void to 700 psi. N/U bope and test to 2000 psi. Set Unihead wear bushing. Test 16" auxiliary casing to 1850 psi. SURFACE: Drill float equipment and 10' of new formation w/14-3/4" bit. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4" hole from 1462' to 4247' per the directional program. Underream the 12-1/4" hole to 17-1/2" from 1452' to 4243'. Pull wear bushing. Run and cement 13-3/8" casing. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Set wear bushing. Test 13-3/8" surface casing to 2150 psi. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-1/4" hole from 4257' to 12269' per the directional program. Pull wear bushing. Run and cement 9-5/8" casing. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 4000 psi. Test production casing to 4000 psi. Set wear bushing. LINER: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 8-1/2" hole from 12279' to 14688' per the directional program. Log. Run and cement 7" liner. Clean out to liner top and test lap to 4000 psi. COMPLETION: Cleanout casing to PBTD.Retest to 4000 psi. Run gyro and CBL. NOTE: The AOGCC must be given 24 hr. notice prior to testing the casing. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. Page 9 MARATHON 0IL Company Structure · STEELHEAD Platform Well' M-SO Field · McArthur River Field Location · TBU, Cook Inlet, Alaska Created by : jones For: P BERGA Date plotted : g-Mar-92 ]Plot Reference is M-30 Version fl 1. ICoordinates are in feet reference slot #B1-9. [rrue Vertical Depths are reference wellhead. | I--],~)~ EA S T M A N / IZ_/JLIIICH RISTE NS E N N 9.63 DEG E (TO TD) 2O00 25O0 4000 4500 5500 - - 6000- 6500- ';'500 800O 85O0 9500 lOOOO _ 10500 - - 11000- iRKB ELEVATION: 160' KOP TvD=992 TMD=992 DEP=10 2,g5 6.31 16"CSG PT TVD=1450 TM0=1452 DEP=45 9.78 20,24 2;;;3 BUILD 1.75 30.75 34.23 37.73 41.22 4~.72 ~i~'22 EOC TVD=3463 TMD=3804 DEP=1162 "~x,x 13 3/8"CSG PT 7VD=3750 TMD=4247 DEP=1499 ....... East --> 800 0 800 1600 TD LOCATION: ] 2555' FNL, 2049' FWL SEC. 21, T9N, R13W WEST FORELAND LOCATION: ] 2328' FSL, 1980' F'WL SEC. 21, TgN, R13W J C ZONE LOCATION: J 1300' FSL. 1800' FWL SEC. 21~ TgN, R13W N 9.91 DEG E DIRECTION AT E0C SURFACE LOCATION:l 967' FNL, 520' F'WL SEC. 3.3, TgN, R15W MAXIMUM ANGLE 49.59 DEG T~,T //~ / ~ Z0N~, 9 5/8"cs~8-~=~57 ~.oo DROP 1 DEG / lOO' '~. ' TARGET #g / WEST FORELAND TD ANGLE ~O~EP=OO~e 30 DEG iud ANGLE DROP WD=10488 TMD=14290 DEP=SO02 TI) TV1)=108~3 TldD=I4{188 BIlP=910I iiiiiiil[lllltllllllllllllllllllllllll]l 500 0 500 1000 1500 2000 2500 .3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 gO(X) 9500 Scole 1 ' 250.00 Verticol Section on 9.63 ozimufh with reference 0.00 N, 0,00 E from slot #B1-9 , 96oo HARATHO# OIL Company STEELHEAD Platform stot #B1-9 HcArthur River Fietd TBU, Cook Inlet, Alaska PROPOSAL LISTING Your ref : M-30 Version #11 Our ref : prop301 Other ref : Date printed : 9-Mar-92 Date created : 4-Nov-91 Last revised : 9-Mar-92 Field is centred on 0.000,0.000,-189.00000,N Structure is centred on 0.000,0.000,-189.00000,N MARATHON OIL Co~ny STEELHEAD Platform,N-30 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : M-30 Version #11 Last revised : 9-Mar-92 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 992.00 1.17 299.37 991.73 11.24 N 6.94 W 0.00 1000.00 1.22 305.62 999.73 11.32 N 7.0~W 1.75 1100.00 2.52 344.78 1099.68 14.00 N 8.52 W 1.75 1200.00 4.16 355.45 1199.51 19.80 N 9.39 W 1.75 1300.00 5.86 0.01 1299.12 28.52 N 9.68 W 1.75 9.92 KOP 9.98 12.44 17.95 26.50 1400.00 7.59 2.52 1398.43 40.23 N 9.38 W 1.75 1452.08 8.49 3.42 1450.00 47.51 N 9.00 W 1.75 1500.00 9.32 4.10 1497.34 54.92 N 8.52 W 1.75 1600.00 11.06 5.18 1595.76 72.56 N 7.07 W 1.75 1700.00 '12.81 5.98 1693.59 93.14 N 5.05 W 1.75 38.10 45.34 16" Csg Pt 52.72 70.35 90.98 1800.00 14.55 6.58 1790.75 116.64 N 2.45 ~ 1.75 1900.00 16.30 7.06 1887.14 143.05 N 0.71 E 1.75 2000.00 18.04 7.45 1982.68 172.33 N 4.44 E 1.75 2100.00 19.79 7.77 2077.28 204.46 N 8.74 E 1.75 2200.00 21.54 8.05 2170.84 239.42 N 13.60 E 1.75 114.59 141.15 170.65 203.05 238.32 2300.00 23.28 8.28 2263.28 277.15 N 19.02 E 1.75 2400.00 25.03 8.48 2354.52 317.64 N 24.99 E 1.75 2500.00 26.78 8.66 2444.47 360.84 N 31.50 E 1.75 2600.00 28.53 8.82 2533.04 406.72 N 38.55 E 1.75 2700.00 30.28 8.96 2620.16 455.23 N 46.14 E 1.75 276.43 317.35 361.03 407.44 456.53 2800.00 32.03 9.08 2705.73 506.32 N 54.25 E 1.75 2900.00 33.78 9.20 2789.69 559.95 N 62.88 E 1.75 3000.00 35.52 9.30 2871.95 616.06 N 72.01 E 1.75 3100.00 37.27 9.40 2952.43 674.61 N 81.65 E 1.75 3200.00 39.02 9.48 3031.07 735.54 N 91.79 E 1.75 508.26 562.58 619.43 678.77 740.54 3300.00 40.77 9.57 3107.79 798.80 N 102.40 E 1.75 3400.00 42.52 9.64 3182.51 864.32 N 113.49 E 1.75 3500.00 44.27 9.72 3255.17 932.04 N 125.05 E 1.75 3600.00 46.02 9.78 3325.69 1001.91 N 137.05 E 1.75 3700.00 47.77 9.85 3394.02 1073.85 N 149.50 E 1.75 804.68 871.13 939.83 1010.72 1083.73 3800.00 49.52 9.91 3460.09 1147.80 N 162.37 E 1.75 3804.06 49.59 9.91 3462.72 1150.84 N 162.90 E 1.75 4000.00 49.59 9.91 3589.74 1297.81 N 188.58 E 0.00 4247.22 49.59 9.91 3750.00 148~.24 N 220.97 E 0.00 4500.00 49.59 9.91 3913.87 1672.85 N 254.10 E 0.00 1158.79 1161.87 EOC 1311.07 1499.30 13 3/8" Csg Pt 1691.78 5000.00 49.59 9.91 4237.99 2047.88 N 319.61 E 0.00 5500.00 49.59 9.91 4562.11 2422.92 N 385.13 E 0.00 6000.00 49.59 9.91 4886.23 2797.96 N 450.64 E 0.00 6500.00 49.59 9.91 5210.36 3172.99 N 516.16 E 0.00 7000.00 49.59 9.91 5534.48 3548.03 N 581.67 E 0.00 2072.49 2453.20 2833.92 3214.63 3595.34 7500.00 49.59 9.91 5858.60 3923.07 N 647.19 E 0.00 8000.00 49.59 9.91 6182.72 4298.10 N 712.71 E 0.00 8500.00 49.59 9.91 6506.84 467'5.14 N 778.22 E 0.00 9000.00 49.59 9.91 6830.96 5048.18 N 843.74 E 0.00 9500.00 49.59 9.91 7155.09 5423.21 N 909.25 E 0.00 3976.05 4356.76 4737.47 5118.18 5498.90 10000.00 49.59 9.91 7479.21 5798.25 N 974.77 E 0.00 10500.00 49.59 9.91 7803.33 6173.29 N 1040.28 E 0.00 11000.00 49.59 9.91 8127.45 6548.32 N 1105.80 E 0.00 11500.00 49.59 9.91 8451.58 6923.36 N 1171.32 E 0.00 12000.00 49.59 9.91 8775.70 7298.40 N 1236.83 E 0.00 5879.61 6260.32 6641.03 7021.74 7402.46 12330.97 49.59 9.91 8990.25 7546.65 N 1280.20 E 0.00 12390.04 49.00 9.91 9028.77 7590.76 N 1287.90 E 1.00 12467.52 48.22 9.91 9080.00 7648.02 N 1297.91 E 1.00 7654.46 TARGET #1 - G Zone 7699.24 7757.38 9 5/8" Csg Pt ALL data is in feet unless otherwise stated Coordinates are from slot lB1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.~ degrees. Calculation uses the minimu~ curvature method. HARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : i-30 Version #11 Last revised : 9-Mar-92 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12490.04 48.00 9.91 9095.03 76~4.53 N 1300.79 E 1.00 777'4.13 12590.04 47.00 9.91 9162.59 7737.16 N 1313.48 E 1.00 7847.86 12690.04 46.00 9.91 9231.42 7808.62 N 1325.96 E 1.00 7920.39 12790.04 45.00 9.91 9301.51 7878.88 N 1338.24 E 1.00 7991.72 12890.04 44.00 9.91 9372.84 7947.92 N 1350.30 E 1.00 8061.81 12990.04 43.00 9.91 9445.3? 8015.73 N 1362.14 E 1.00 8130.64 13090.04 42.00 9.91 9519.10 8082.28 N 1373.77' E 1.00 8198.20 13190.04 41.00 9.91 9593.99 8147.55 N 1385.17 E 1.00 8264.46 13290.04 40.00 9.91 9670.03 8211.53 N 1396.35 E 1.00 8329.40 13390.04 '39.00 9.91 9747.20 8274.18 N 1407.29 E 1.00 8~93.01 13490.04 38.00 9.91 9825.46 8335.51 N 1418.01 E 1.00 8455.26 13590.04 3?.00 9.91 9904.79 8395.47 N 1428.48 E 1.00 8516.13 13690.04 36.00 9.91 9985.17 8454.07 N 1438.72 E 1.00 8575.61 13790.04 35.00 9.91 10066.58 8511.27 N 1448.71 E 1.00 8633.68 13890.04 34.00 9.91 10149.00 8567.06 N 1458.46 E 1.00 8690.32 13903.60 33.86 9.91 10160.25 8574.52 N 1459.76 E 1.00 13990.04 33.00 9.91 10232.38 8621.44 N 1467.96 E 1.00 14090.04 32.00 9.91 10316.72 86?4.36 N 1477.20 E 1.00 14190.04 31.00 9.91 10401.98 8725.83 N 1486.19 E 1.00 14290.04 30.00 9.91 10488.15 8775.83 N 1494.93 E 1.00 8697.89 TARGET #2 - West Fore[and 8745.51 8799.24 8851.49 8902.24 End Angle Drop 14488.47 30.00 9.91 10660.00 8873.57 N 1512.00 E 0.00 14500.00 30.00 9.91 10669.98 8879.24 N 1512.99 E 0.00 14688.47 30.00 9.91 10833.20 8972.07 N 1529.21 E 0.00 9001.46 9007.22 9101.46 TD - 7" Liner All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wetlhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD PLatform,#-30 HcArthur River Fietd,TBU, Cook Inlet, ALaska PROPOSAL LISTING Page 3 Your ref : M-30 Version #11 Last revised : 9-Hat-92 Con~ents in welLpath MD TVD Rectangular Coords. Comment 992.00 991.73 11.24 N 1452.08 1450.00 47.51 N 3804.06 3462.72 1150.84 N 4247.22 3750.00 148~.24 N 12330.97 8990.25 7546.65 N 12467.52 9080.00 7648.02 N 13903.60 10160.25 8574.52 N 14290.04 10488.15 8T75.83 N 146~.47 10833.20 8972.07 N 6.94 W KOP 9.00 W 16" Csg Pt 162.90 E EOC 220.97 E 13 3/8" Csg Pt 1280.20 E TARGET #1 - G Zone 1297.91E 9 5/8" Csg Pt 1459.76 E TARGET #2 - West Fore[and 1494.93 E End Angle Drop 1529.21E TD - 7" Liner Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVO Rectangular Coords. Casing n/a 991.73 11.24N 6.94W 1452.08 1450.00 47.51N 9.00W 16 CSG n/a 991.7'5 11.24N 6.94W 4247.21 3750.00 1485.24N 220.97E 13 3/8 n/a 991.73 11.24N 6.94W 12467.52 9080.00 7648.02N 1297.91E 9 5/8 CSG n/a 991.73 11.24N 6.94W 146~S.47 108~3.20 8972.07N 1529.21E 7" LINER Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised TARGET #1 / G Zone not specified 8990.25 7546.65N 1280.20E 4-Nov-91 All data is in feet unless otherwise stated Coordinates are from slot #81-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the mininm~ curvature method. MARATHON OIL Company STEELHEAD Platform slot ~qil-9 McArthur River Field TBU, Cook Intel, Alaska CLEARANCE REPORT Your ref : M-30 Version #11 Our ref : prop~01 Other ref : Date printed : 9-Mar-92 Date created : 4-Nov-91 Last revised : 9-Mar-92 Field is centred on 0.000,0.000,-189.00000,N Structure is centred on 0.000,0.000,-189.00000,N Main calculation performed with 3-D minimumdistance method Object wellpath GMS <O-12425'>,,G-28,GRAYLING PLatform MSS <O-10790~>,,G-33,GRAYLING PLatform GMS <O-12075~>,,G-23,GRAYL[NG PLatform GMS <0-11742~>,,G-23Rd,GRAYL[NG Platform GMS <0-10268~>,,G-34Rd,GRAYL[NG Platform MSS <2284-11655~>,,G-34,GRAYL[NG Platform PGMS <11100-13380~>,,G-360PN,GRAYLING Platform PMSS <11830-12453~>,,G-36,GRAYL[NG Platform GMS <0-129481>,,G-2?,GRAYL[NG Platform GMS <0-10642~>,,G-EO,GRAYLING Platform GMS <0-10400~>,,G-24,GRAYLING Platform GMS <O-12366~>,,G-25,GRAYL[NG PLatform GMS <0-11544~>,,G-26,GRAYL[NG Platform GMS <0-11160~>,,G-E1,GRAYLING Platform GMS <0-11335~>,,G-22,GRAYL~NG Platform MSS <10070-10975~>,,G-lO,GRAYL[NG Platform GMS <0-10115~>,,G-11,GRAYL[NG Platform PGMS <0-10?O0~>,,G-2Rd,GRAYL[NG Platform MSS <9120-11278~>,,G-3Rd,GRAYL[NG Platform GMS <0-8800~ (11050)>,,G-3,GRAYL[NG Platform GMS <lO0-11050~>,,G-3Rd2,GRAYL[NG Platform MSS <0-12885~>,,G-15,GRAYL]NG Platform MSS <0-12007~>,,G-13,GRAYLING Platform MSS <O-12291~>,,G-19,GRAYL[NG Platform MSS <4894-16575~>,,G-14A,GRAYL~NG Platform GMS <0-13661~>,,G-16,GRAYL[NG Platform MSS <O-11570~>,,G-32,GRAYL[NG Platform PGMS <100-11000~>,,G-6Rd,GRAYL]NG Platform GMS <O-9600~>,,G-6,GRAYL[NG Platform MSS <~709-121751>,,G-8,GRAYLING Platform GMS <0-11750~>,,G-SRd,GRAYL[NG Platform MSS <630-11451~>,,G-30,GRAYL~NG Platform MSS <0-16342~>,,G-14,GRAYL[NG Platform GMS <0-8860~>,,G-18Rd, GRAYLING Platform MSS <0-15330~>,,G-9,GRAYL]NG Platform GMS <0-9000~>,,G-4,GRAYLIHG Platform GMS <1400-10400~>,,G-4Rd,GRAYL[NG Platform MSS <0-127'56~>,,G-31,GRAYL[#G Platform GMS <0-138001>,,G-12Rd2,GRAYL[NG Platform MSS <10250-13748~>,,G-12,GRAYLING Platform Closest approach Last revised Distance M.D. Diverging from 2-Nov-91 - - - 2-Nov-91 1779.6 6460.0 6460.0 2-Nov-91 1296.3 4260.0 4260.0 2-Nov-91 1296.3 4260.0 4260.0 2-Nov-91 - 2-Nov-91 2-Nov-91 752.9 4312.0 4312.0 2-Nov-91 752.9 4312.0 4312.0 2-Nov-91 2-Nov-91 925.8 6660.0 6660.0 2-Nov-91 2-Nov-91 304.0 9094.2 9094.2 2-Nov-91 2-Nov-91 1181.5 5580.0 5580.0 2-Nov-91 2-Nov-91 2-Nov-91 2-Nov-91 2-Nov-91 1901.6 4420.0 4420.0 2-Nov-91 1901.6 4420.0 4420.0 2-Nov-91 1901.6 4420.0 4420.0 2-Nov-91 - - 2-Nov-91 - - - 2-Nov-91 - - - 2-Nov-91 875.4 5546.1 5546.1 2-Nov-91 954.1 6320.0 6320.0 2-Nov-91 1578.7 8380.0 8380.0 2-Nov-91 472.3 5840.0 5840.0 2-Nov-91 472.3 5840.0 5840.0 2-Nov-91 516.0 4560.0 4560.0 2-Nov-91 516.0 4560.0 4560.0 2-Nov-91 1251.4 5480.0 5480.0 2-Nov-91 862.2 5360.0 5360.0 2-Nov-91 1434.9 6360.0 6360.0 2-Nov-91 1429.1 6020.0 6020.0 2-Nov-91 1387.8 6820.0 6820.0 2-Nov-91 1271.8 7600.0 7600.0 2-#ov-91 274.2 6640.0 6640.0 2-#ov-91 2173.2 3500.0 3733.3 2-Nov-91 2173.2 3500.0 3733.3 HSS <10250-13700'>,,C ~,GRAYLZNG PLatform PGHS <O-10100'>,,G-f,GRAYLING PLatform NSS <3~)l-15095">,,G-17, GRAYL]NG PLatform GHS <O-11900">,,G-17Rd,GRAYL]NG Platform PGHS <O-9~50">,,G-5,GRAYLING Ptatfo~n PGHS <O-11~30~>,,G-1Rd,GRAYL]NG Platform HSS <84~l-11420'>,,G-1,GRAYL[NG PLatform 2-Nov-91 2173.;, JSO0.O 3733,3 2-Nov-91 19/+/..8 5900.0 5900.0 2-#ov-91 - - ' 2-Nov-91 ' - 2-Nov-91 ' ' 6-Nar-92 1~./+ 67J,0.0 67/+0.0 6-Mar-92 1~.~ 67/+0.0 67J~0.0 STEELHEAD P~atform,N-30 NcArthur River FieEd,TBU, Cook Inlet, Alaska CLEAP. ANCE LISTING Page 2 Your ref : #-30 Version #11 Last revised : 9-Nar-92 Reference ~e[ [path Object wellpeth : GNS <O-12~'>,,G-25,GRAYLING Platform Angle fm Nin'm TCy[ T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Dist Dist 8785.6 6692.0 4887.4N 815.6E 7774.5 6555.2 52l~.1N 970.4E +31.2 382.3 462.1 8862.8 6742.0 4945.2N 825.0E 7825.7 6597.4 5213.2N 999.3E +30.9 350.5 401.4 8939.9 6792.0 5003.1N 835.9E 78T7.6 ~0.1 5217.3N 1028.5E +32.7 325.7 351.0 9000.0 6031.0 5048.2N 8~3.7E 7917.6 ~7'5.0 5220.4N 1051.0E +35.8 312.3 322.7 9017.0 6&~2.0 50~d).gN ~.OE 79~.0 64d)2.3 5221.3N 1057.3E +36.9 309.6 316.8 9094.2 6892.0 5118.8N 856.1E 7979.1 6723.5 5225.0N 1085.7E +43.2 304.0 304.0 9171.3 6942.0 5176.6N ~.2E 8029.2 676~.5 5228.5N 1114.3E +50.7 3(~7.4 316.6 9248.4 6992.0 5234.5N 876.3E 8079.2 6805.4 5231.7N 1142.9E +58.5 325.4 352.5 9325.5 7042.0 5292.4N 886.4E 8129.2 6846.3 5234.8N 1171.6E +65.7 350.6 405.9 9402.7 7092.0 5350.2N 896.5E 8179.4 6887.3 5237.8N 1200.3E +72.1 383.2 471.1 ALL data is in feet unless otherwise stated Coordinates are from slot ~!11-9 ar~TVDs are from weLLhead. Vertical section is from weLLheadonazimuth 9.63degrees. CaLcuLation uses the minim~ncurvature method. NAEATIK)N OIL Coe~m~ CLEARANCE LISTING Page 3 STEELNEN) Platform,#-30 Your ref : #-30 Version #11 HcArthur River Fie[d, TBU, Cook Inlet, Alaska Last revised : 9-#ar-92 Reference ~e[[path Object ~ettpath : PGNS <lO0-11000t>,,G-6Rd,GRAYLING Platform Angle fm Minmm TCy[ M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Dist Dist 57'f?.5 4742.0 2631.1N 421.5E 5352.0 4993.0 25~.3# 28.0E -127.? 474.? 486.8 5854.6 4792.0 2688.9N 431.6E 5382.0 5017.2 2537.7N 44.71~ -131.2 472.4 474.5 Att data is in feet untess otherwise stated Coordinates are from stot tB1-9 and TVOs are from~etthead. Vertical section is from wellhead on azimuth 9.63 degrees. Catcutation uses the minin~Ja curvature method. MARATHON OIL Company STEELNEAO Platform,#-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 4 Your ref : M-30 Version #11 Last revised : 9-Har-92 Reference weLLpath Object wellpath : GMS <O-9600,>,,G-6,GRAYLING Platform M.D. 5777.5 5854.6 Angle fm Min'm T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Dist 4742.0 2631.1N 421.5E 5352.0 4993.0 2544.3N 28.0E -127.7 474.7 4792.0 2688.9N 431.6E 5382.0 5017.2 2537.7N 44.7E -131.2 472.4 TCyt Dist 486.8 474.5 All data is in feet un[ess otherwise stated Coordinates are from slot #B1-9 and TVOs are from we[lheed. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. NARATHON OIL company STEELHEAD Platform,H-30 HcArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 5 Your ref : H-30 Version #11 Last revised : 9-Mar-92 Reference weLLpath Object we[[path : NSS <O-12736,>,,G-31,GRAYLING Platform Angle fm Hin'm TCy[ H.D. T.V.D. Rect Coordinates H.D. T.V.D. Rect Coordinates HighSide Dist Dist 6394.6 5142.0 3093.9N 502.3E 5815.4 5325.8 3198.0N 237.6E -107.7 338.6 436.9 6471.7 5192.0 3151.8N 512.4E 5858.9 5361.8 3196.8N 262.0E -114.8 306.0 360.4 6500.0 5210.4 3173.0N 516.2E 5875.6 5375.7 3196.3N 271.2E -117.8 296.4 336.2 6548.8 5242.0 3209.6N 522.6E 5901.9 5397.6 3195.5N 285.8E -122.9 283.6 301.8 6625.9 5292.0 3267.5N 532.7E 5946.0 5434.5 3193.9N 310.1E -131.1 274.3 274.7 6703.1 5342.0 3325.3N 542.8E 5993.5 5474.2 3192.6N 336.0E -138.3 279.0 286.2 6780.2 5392.0 3383.2N 552.9E 6046.0 5518.2 3192.5N 364.6E -143.7 296.2 321.1 6857.3 5442.0 3441.0N 563.0E 6102.4 5565.2 3194.2N 395.7E -146.8 322.6 369.2 6934.5 5492.0 3498.9N 573.1E 6160.8 5613.7 3197.5N 428.1E -147.8 355.8 425.0 7000.0 5534.5 3548.0N 581.7E 6208.8 5653.4 3201.1N 454.9E -147.2 388.0 477.2 7011.6 5542.0 3556.7N 583.2E 6216.6 5659.8 3201.7N 459.2E -146.9 394.0 486.9 Att data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wetthead. Vertical section is from ~e[[head on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL company STEELHEAD PLatfom,#-30 McArthur River Field, TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 6 Your ref : N-lO Version #11 Last revised : 9-Mar-92 Referer~e wellpath Object weLLpath : PGNS <O-11430'>,,G-1Rd, GRAYLING PLatfom M.D. T.V.D. Rect Coordinates M.D. T.V.D. 6317.4 5092.0 3036.0N 492.2E 5654.2 5231.5 6394.6 5142.0 3093.9N 502.3E 5707.2 5275.2 6471.7 5192.0 3151.8N 512.4E 5761.9 5320.1 6500.0 5210.4 3173.0# 516.2E 5781.0 5335.8 6548.8 5242.0 3209.6N 522.6E 5814.0 5362.8 6625.9 5292.0 3267.5# 532.7E 5866.4 5405.7 6703.1 5342.0 3325.3N 542.8E 5919.7 5449.2 6780.2 5392.0 3383.2N 552.9E 5972.7 5492.0 685?.3 5442.0 3441.0# 563.0E 6020.1 5531.2 6934.5 5492.0 3498.9# 573.1E 6075.4 5577.9 7000.0 5534.5 3548.0N 581.7E 6123.2 5618.2 7011.6 5542.0 3556.7N 583.2E 6131.4 5625.0 7088.7 5592.0 3614.6N 593.3E 6186.9 5671.6 7165.9 5642.0 3672.4N 603.4E 6242.7 5718.4 Angle fm Min'm TCyt Rect Coordinates HighSicle Dist Dist 3256.3# 249.3E -88.8 356.4 479.2 3261.2N 278.9E -93.6 309.3 406.8 3266.2N 309.7E -100.2 265.7 336.6 3267.8N 320.6E -103.1 251.0 311.8 3270.6# 339.3E -108.8 227.8 271.2 3274.8N 369.2E -120.2 199.3 217.1 3278.9N 399.8E -133.5 184.6 186.0 3283.9N 430.6E -145.2 186.5 190.9 3289.4N 456.6E -149.2 205.6 227.5 3296.7N 485.3E -149.7 236.6 279.7 3303.2N 510.2E -148.2 268.4 331.2 3304.3N 514.5E -147.7 274.5 340.8 3311.6N 543.8E +145.0 317.1 407.5 3319.2N 573.4E +142.3 362.6 478.1 ALL data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.6~ degrees. Calculation uses the minimuncurvature method. HARATN(~OIL Company STEELHEAD Piatfom,#-30 NcArthur River FieLd,TBU, Cook InLet, ALaska CLEARANCE LISTING Page 7 Your ref : N-30 Version #11 Last revised : 9-Nar-92 Reference ~dettpath Object weLLpath : NSS <8491-11420'>,,G-1,GRAYLING PLatform T.V.D. Rect Coordinates AngLe fm Nin'm TCy[ N.D. T.V.D. Rect Coordinates HighSide Dist Dist 6317.4 5092.0 3036.0N 492.2E 6394.6 5142.0 3093.9fl 502.3E 6471.7 5192.0 3151.8N 512.4E 6500.0 5210.4 3173.0N 516.2E 6548.8 5242.0 3209.6N 522.6E 5654.2 5231.5 3256.3N 249.3E -88.8 356.4 479.2 5707.2 5275.2 3261.2N 278.9E -93.6 309.3 406.8 5761.9 5320.1 3266.2N 309.7E -100.2 265.7 336.6 5781.0 5335.8 3267.8N 320.6E -103.1 251.0 311.8 5814.0 5362.8 3270.6N 339.3E -108.8 227.8 271.2 6625.9 5292.0 3267.5N 532.7E 6703.1 5342.0 3325.3N 542.8E 6780.2 5392.0 3383.2N 552.9E 6857.3 5442.0 3441.0N 563.0E 6934.5 5492.0 3498.9N 573.1E 5866.4 5405.7 3274.8N 369.2E -120.2 199.3 217.1 5919.7 5449.2 3278.9N 399.8E -133.5 184.6 186.0 5972.7 5492.0 3283.9N 430.6E -145.2 186.5 190.9 6020.1 5531.2 3289.4N 456.6E -149.2 205.6 227.5 6075.4 5577.9 3296.7tl 485.3E -149.7 236.6 279.7 7000.0 5534.5 3548.0N 581.7E 7011.6 5542.0 3556.7N 583.2E 7088.7 5592.0 3614.6N 593.3E 7165.9 5642.0 3672.4N 603.4E 6123.2 5618.2 3303.2N 510.2E -148.2 268.4 331.2 6131.4 5625.0 3304.3N 514.5E -147.7 274.5 340.8 6186.9 5671.6 3311.6N 543.8E +145.0 317.1 407.5 6242.7 5718.4 3319.2N 573.4E +142.3 362.6 478.1 Att data is in feet unless otherwise stated Coordinates are frown slot ~B1-9 and TVOs are from ~etthead. Vertical section is from ~etthead on azimuth 9.63 degrees. CaLcuLation uses the minimum curvature method. MARATHON OIL Coepany STEELHEAO PLatform slot #B1-9 McArthur River Field TBU, Cook Inlet, ALaska CLEARANCE REPORT Y~r ref : H-30 Version #10 Our ref : pr~01 Other ref : Date printed : 25-Feb-92 Date created : 4-Nov-91 Last revised : 25-Feb-92 Field is centred on 0.000,0.000,-189.00000,N Structure is centred on 0.000,0.000,-189.00000,N Main calculation performed with 3-D minimu~ distance method Object welLpath PGMS <O-5600'>,,M-5,STEELHEAD Platform PGMS <O-7250'>,,M-3,STEELHEAD Platform GSS <0-1421'>,,M-4,STEELHEAD Platform PONS <O-7250'>w,M-1St#1,STEELHEAD Platform PMSS <6595-6988'>,,M-1St#1,STEELHEAD Platform PGMS <O-7419'>,,M-2,STEELHEAO PLatform PGMS <3700-11700'>,,M-25,STEELHEAD Platform PGMS <O-10938'>,,M-29,STEELHEAD PLatform GSS <975-2660'>,,M-29,STEELHEAO Platform PGMS <12~86-15276'>,,M-27, STEELHEAD PLatform PGHS <O-129~O'>~,M-28~STEEL#EAD PLatform MSS <1103-2265'>,,M-26,STEELHEAD PLatform PGMS <2700-9101'>,,M-14,STEELHEAD PLatform PMSS <1006-7952'>,,M-15 St,STEELHEAD PLatform PMSS <1006-1449'>,,M-15,STEELHEAD PLatform M-19 Version ff~,,M-19,STEELHEAD PLatform GSS <436-1422'>,,M-19,STEELHEAD Platform MSS <1363-1859'>,,RLF #2,STEELHEAD Platform PONS <O-2310'>,,RLF #1,STEELHEAD PLatform PMSS <808-1165'>,,RLF #2,STEELHEAD PLatform MSS <0-7~5'>,,0B #2,STEELHEAD Platform *M-7* Version #5,,*M-7*,STEELHEAD PLatform PGHS <0-857'>,,B1-8,STEELHEAD PLatform PGMS <O-785'>,,B1-6,STEELHEAD PLatform PGMS <500-g28'>,,B1-Z,STEELHEAD PLatform *M-32' Version #5,,*M-32*,STEELHEAD Platform PGMS <O-928'>,,*M-32*,STEELHEAD PLatform *M-31' Version #1,,~M-31*,STEELHEAD PLatform PGMS <O-927'>,,*M-31*,STEELHEAO PLatform PGMS <O-7~'>,,M-13,$TEELHEAD PLatform PGMS <O-992'>,,M-30,STEELHEAD PLatform Closest approach Last revised Distance M.D. 1-Nov-91 113.4 992.0 1-Nov-91 130.9 992.0 1-Nov-91 114.4 992.0 1-Nov-91 1~.2 1166.7 1-Nov-91 108.2 1166.7 1-Nov-91 141.8 992.0 1-Nov-91 22.9 992.0 2-Dec- 91 29.7 992.0 2-Dec-91 29.7 992.0 21-Nov-91 42.9 992.0 29-0ct-91 ~.8 992.0 29-0ct-91 15.3 992.0 29-0ct-91 113.4 992.0 3-Nov-91 155.0 992.0 3-Nov-91 155.0 992.0 19-Dec-91 115.9 992.0 29-0ct-91 121.7 992.0 3-Nov-91 32.3 1595.2 3-Nov-91 15.6 2114.6 3-Nov-91 578.9 1166.7 3-Nov-91 - - 18-Nov-91 118.2 992.0 1-Nov-91 - - 29-0ct-91 - - 29-0ct-91 - - 7-Nov-91 18.5 1066.7 1-Nov-91 - - 8-Nov-91 30.7 992.0 1-Nov-91 - - 29-0ct-91 137.2 992.0 1-Nov-91 0.0 992.0 Diverging from 992.0 992.0 992.0 4380.0 4380.0 992.0 992.0 5681.2 992.0 992.0 992.0 992.0 992.0 992.0 992.0 992.0 1600.0 2114.6 1191.5 · 992.0 1066.7 992.0 992.0 992.0 MARATHON OIL Company STEELHEAD PLatform,M-30 McArthur River FieLd,TBU, Cook Inlet, Alaska Reference weLLpath CLEARANCE L[STXNG Page 1 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Object weLLpath : PGMS <O-5600,>,,M-5,STEELHEAD PLatform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9$4 985.1 1000.0 999.7 11.3N 7.1W 993.1 1091.3 1091.0 13.7N 8.4W 1084.2 1100.0 1099.7 14.1N 8.5W 1092.9 1191.5 1191.0 19.2N 9.3W 1184.2 1200.0 1199.5 19.8N 9.4~ 1192.7 1291.8 1291.0 27.7N 9.714 1284.5 1300.0 1299.1 28.5N 9.714 1292.6 1392.5 1391.0 39.2N 9.4~ 1384.7 1400.0 1398.4 40.2N 9.4~ 1392.1 1452.1 1450.0 47.5N 9.0~ 1444.0 1493.6 1491.0 53.9N 8.6W 1485.6 1500.0 1497.3 54.9N 8.5~ 1492.0 1595.2 1591.0 71.6N 7.1~ 1586.2 1600.0 1595.8 72.6N 7.OW 1591.0 1697.3 1691.0 92.6N 5.1~ 1686.3 1700.0 1693.6 93.1N 5.0~ 1688.9 1800.0 1790.8 116.6N 2.4W 1786.0 1800.2 1791.0 116.7N 2.4~ 1786.2 1900.0 1887.1 143.0N 0.TE 1882.6 1904.0 1891.0 144.2N 0.9E 1~.5 2000.0 1982.7 172.3N 4.5E 1978.1 2008.7 1991.0 175.0N 4.8E 1986.5 2100.0 2077.3 204.4N 8.8E 2072.1 2114.6 2091.0 209.4N 9.5E 2085.9 Angle fm Min'm TCyL T.V.D. Rect Coordinates HighSide Dist Dist 993.0 69.9S 72.3E -163.7 113.4 113.4 1001.0 69.8S 72.3E -170.0 113.5 113.5 1092.2 69.1S 71.6E +152.8 115.1 115.2 1100.8 69.0S 71.5E +151.2 115.4 115.4 1192.1 68.2S 71.1E +142.4 118.8 118.9 1200.6 68.1S 71.1E +141.9 119.2 119.4 1292.4 67.1S 70.8E +139.7 124.4 124.6 1300.5 67.0S 70.8E +139.6 124.9 125.2 1392.6 65.9S 70.5E +139.9 132.1 132.6 1400.0 65.8S 70.4E +140.0 132.7 133.3 1451.9 65.0S 70.3E +140.8 137.7 138.4 1493.5 64.3S 70.2E +141.6 142.0 142.9 1499.9 64.2S 70.1E +141.7 142.7 143.6 1594.0 62.2S 69.8E +143.8 154.4 155.9 1598.8 62.1S 69.8E +143.9 155.1 156.6 1694.1 60.2S 69.6E +146.2 170.0 172.6 1696.7 60.1S 69.6E +146.2 170.5 173.1 1793.8 58.4S 69.4E +148.4 189.2 193.4 1794.1 58.4S 69.4E +148.4 189.3 193.4 1890.4 56.9S 69.2E +150.1 211.3 217.7 1894.3 56.8S 69.2E +150.2 212.3 218.7 1985.9 55.4S 69.1E +151.3 236.8 246.2 1994.3 55.3S 69.1E +151.4 239.2 249.0 2079.9 54.3S 69.1E +151.9 265.7 279.4 2093.7 54.1S 69.1E +152.0 270.2 284.7 2200.0 2170.8 239.4N 13.6E 2165.6 2221.7 2191.0 247.4N 14.8E 2185.9 2300.0 2263.3 277.1N 19.1E 2258.6 2330.2 2291.0 289.1N 20.8E 2286.4 2400.0 2354.5 317.6N 25.0E 2350.3 2173.4 53.4S 69.3E +152.1 298.0 317.1 2193.7 53.2S 69.3E +152.1 305.5 325.9 22~.4 52.5S 69.6E +151.9 333.5 359.3 2294.2 52.2S 69.7E +151.7 344.8 373.0 2358.0 51.6S 70.OE +151.3 372.0 406.4 2440.4 2391.0 334.7N 27.6E 2386.8 2500.0 2444.5 360.8N 31.6E 2440.1 2552.3 2491.0 384.5N 35.2E 2486.3 2394.5 51.2S 70.2E +151.0 388.3 426.9 2447.9 50.7S 70.4E +150.4 413.4 458.8 2494.1 50.4S 70.5E +149.8 436.3 488.3 ALL data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the mini~ curvature method. MARATHON OIL COmpany STEELHEAO Platform,N-30 McArthur River Field,TBU, Cook Inlet, Alaska Reference weLLpath CLEARANCE LISTING Page 2 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Object wettpath : PGMS <O-7250,>,,M-3,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9S4 990.8 1000.0 999.7 11.3N 7.1W 998.8 1091.3 1091.0 13.7N 8.4W 1090.4 1100.0 1099.7 14.1N 8.5~ 1099.1 1191.5 1191.0 19.2N 9.3W 1190.8 1200.0 1199.5 19.8N 9.4W 1199.3 1291.8 1291.0 27.7N 9.7g 1291.2 1300.0 1299.1 28.5N 9.71~ 1299.3 1392.5 1391.0 39.2N 9.4W 1391.3 1400.0 1398.4 40.2N 9.4W 1398.8 1452.1 1450.0 47.5N 9.OW 1450.4 1493.6 1491.0 53.9N 8.6~ 1491.4 1500.0 1497.3 54.9N 8.5~ 1497.7 1595.2 1591.0 71.6N 7.1~ 1595.9 1600.0 1595.8 72.6N 7.OW 1600.7 1697.3 1691.0 92.6N 5.1~ 1702.4 1700.0 1693.6 93.1N 5.OW 1705.1 1800.0 1790.8 116.6N 2.4~ 1804.0 1800.2 1791.0 116.7N 2.4~ 1804.3 1900.0 1887.1 143.0N 0.7E 1905.3 1904.0 1891.0 144.2N 0.9E 1909.2 2000.0 1982.7 172.3N 4.5E 1989.8 2008.7 1991.0 175.0N 4.8E 1998.2 2100.0 2077.3 204.4N 8.8E 2081.3 2114.6 2091.0 209.4N 9.5E 2095.2 2200.0 2170.8 239.4N 13.6E 2178.5 2221.7 2191.0 247.4N 14.8E 2199.0 2300.0 2263.3 277.1N 19.1E 2275.1 2330.2 2291.0 289.1N 20.8E 2304.7 2400.0 2354.5 317.6N 25.0E 2370.9 2440.4 2391.0 334.7N 27.6E 2408.3 2500.0 2444.5 360.8N 31.6E 2460.3 2552.3 2491.0 384.5N 35.2E 2505.2 2600.0 2533,0 406.7N 38.6E 2547.5 Angle fm Min'm TCyl T.V.D. Rect Coordinates HighSide Dist Dist 990.6 87.7S 78.6E -160.2 130.8 130.9 998.6 87.8S 78.6E -166.4 131.0 131.1 1090.2 88.8S 78.4E +156.4 134.3 134.5 1098.9 88.9S 78.3E +154.9 134.7 134.8 1190.7 89.5S 78.1E +146.1 139.5 139.7 1199.2 89.6S 78.0E +145.6 140.0 140.3 1291.0 89.9S 77.7E +143.2 146.5 147.0 1299.1 89.9S 7'~.~E +143.2 147.2 147.6 1391.2 90.OS 77.3E +143.1 155.7 156.5 1398.6 90.1S T7.2E +143.2 156.5 157.3 1450.2 90.1S 77.0E +143.7 162.3 163.5 1491.2 90.2S 76.8E +144.3 167.5 168.9 1497.6 90.2S 76.7E +144.4 168.3 169.8 1595.7 88.4S 77.1E +146.0 180.9 182.4 1600.5 88.2S 77.2E +146.0 181.5 183.0 1702.0 81.5S 80.3E +146.9 194.2 195.9 1704.6 81.3S 80.4E +146.9 194.6 196.3 1802.9 72.1S 87.0E +146.6 209.2 211.8 1803.1 72.1S 87.1E +146.6 209.2 211.8 1903.0 60.3S 96.0E +146.1 225,1 228.8 1906.9 59.8S 96.4E +146.1 225.8 229.6 1986.2 51.0S 107.2E +144.0 245.9 254.6 1994.5 50.2S 108.7E +143.9 248.1 257.1 2075.5 42.5S 125.3E +141.8 273.1 285.3 2089.0 41.1S 128.5E +141.6 277.4 290.0 2169.1 31.7S 149.3E +139.7 303.1 318.3 2188.7 29.0S 154.9E +139.2 309,8 325.8 2260.4 17.8S 177.4E +137.3 334.8 353.8 2288.0 12.8S 187.0E +136.5 344.6 365.2 2348.8 0.6S 210.1E +134.5 368,2 393.5 2382.6 7.0N 224.1E +133.2 382,2 411,2 2429.0 18.1N 245.0E +131.3 404.0 438.6 2468.3 28.2N 264.1E +129.6 424.2 463.7 2504.9 37.9N 282.9E +128.1 443.3 487.4 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL C~pany STEELHEAD Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska M.D. Reference wet [path T.V.D. Rect Coordinates CLEARANCE LISTING Page 3 Your ref : H-30 Version #10 Last revised : 25-Feb-92 992.0 991.7 11.2N 6.9W 1000.0 999.7 11.3N 7.1g 1091.3 1091.0 13.7N 8.4W 1100.0 1099.7 14.1N 8.5W 1191.5 1191.0 19.2N 9.3~ Object we[lpath : GSS <O-1421,>,,M-4,STEELHEAD Platform 1200.0 1199.5 19.8N 9.4~ 1291.8 1291.0 27.?N 9.714 1300.0 1299.1 28.5N 9.7t~ 1392.5 1391.0 39.2N 9.4~ 1400.0 1398.4 40.2N 9.4W Angle fm Min'm TCyl M.D. T.V.D. Rect Coordinates HighSide Dist Dist 994.2 992.? 33.9S 98.2E +173.8 114.4 114.4 1002.2 1000.5 32.9S 98.5E +167.1 114.5 114.5 1093.2 1090.6 20.1S 102.9E +123.6 116.3 116.3 1101.6 1098.9 18.75 103.3E +121.5 116.5 116.6 1191.0 1186.4 1.6S 109.2E +104.8 120.4 120.6 1199.4 1194.6 0.2N 109.8E +103.6 120.9 121.1 1288.1 1280.6 20.3N 117.6E +93.1 127.9 128.4 1296.4 1288.6 22.4N 118.4E +92.2 128.6 129.1 1386.9 1375.4 46.3N 126.6E +83.9 137.1 137.8 1394.2 1382.5 48.4N 127.3E +83.2 137.8 138.6 At[ data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska Reference weltpath CLEARANCE LISTING Page 4 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Object we[[path M.D. T.V.D. Rect Coordinates H.D. T.V.D. 992.0 991.7 11.2N 6.914 999.6 996.2 1000.0 999.7 11.3N 7.1W 1008.0 1004.5 1091.3 1091.0 13.7N 8.4W 1099.8 1095.2 1100.0 1099.7 14.1N 8.5W 1108.8 1104.1 1191.5 1191.0 19.2N 9.3~ 1199.8 1192.8 1200.0 1199.5 19.8N 9.4W 1208.1 1200.8 1291.8 1291.0 27.7N 9.714 1297.4 1286.5 1300.0 129<2.1 28.5N 9.7t4 1305.3 1294.0 1392.5 1391.0 39.2N 9.4~ 1394.2 1377.5 1400.0 1398.4 40.2N 9.4~ 1401.0 1383.8 1452.1 1450.0 47.5N 9.OW 1450.9 1429.8 1493.6 1491.0 53.9N 8.6W 1489.6 1465.0 1500.0 1497.3 54.9N 8.5W 1495.8 1470.6 1595.2 1591.0 71.6N 7.1W 1581.9 1547.5 1600.0 1595.8 72.6N 7.0~ 1586.5 1551.5 1697.3 1691.0 92.6N 5.1W 1673.1 1626.5 1700.0 1693.6 93.1N 5.OW 1675.7 1628.7 1800.0 1790.8 116.6N 2.4~ 1762.3 1701.5 1800.2 1791.0 116.7N 2.4W 1762.5 1701.7 1900.0 1887.1 143.0N O.7E 1855.2 1777.7 1904.0 1891.0 144.2N 0.9E 1859.0 1780.8 2000.0 1982.7 172.3N 4.5E 1954.5 1859.4 2008.7 1991.0 175.0N 4.8E 1962.9 1866.4 2100.0 2077.3 204.4N 8.8E 2062.9 1950.3 2114.6 2091.0 209.4N 9.5E 2081.0 1965.8 2200.0 2170.8 239.4N 13.6E 2173.4 2046.0 2221.7 2191.0 247.4N 14.8E 2194.9 2064.8 2300.0 2263.3 277.1N 19.1E 2270.8 2131.0 2330.2 2291.0 289.1N 20.8E 2300.9 2157.1 2400.0 2354.5 317.6N 25.0E 2365.6 2212.9 2440.4 2391.0 334.7N 27.6E 2400.9 2243.1 2500.0 2444.5 360.8N 31.6E 2458.0 2291.7 2552.3 2491.0 384.5N 35.2E 2505.6 2332.0 2600.0 2533.0 406.7N 38.6E 2551.1 2370.1 2666.3 2591.0 438.6N 43.6E 2612.5 2421.2 2700.0 2620.2 455.2N 46.2E 2642.5 2446.0 2782.6 2691.0 497.2N 52.9E 2718.8 2508.3 2800.0 2705.7 506.3N 54.4E 2734.5 2521.0 2900.0 2789.7 559.9N 63.0E 2831.7 2599.2 2901.6 2791.0 560.8N 63.1E 2833.3 2600.5 3000.0 2871.9 616.0N 72.1E 2932.2 2679.7 3023.5 2891.0 629.6N 74.4E 2957.0 2699.7 3100.0 2952.4 674.6N 81.8E 3034.1 2761.8 3148.7 2991.0 704.0N 86.7E 3082.7 2800.9 3200.0 3031.1 735.5N 91.9E 3134.9 2843.0 3277.9 3091.0 784.6N 100.2E 3216.9 2909.3 3300.0 3107.8 798.8N 102.6E 3238.9 2927.2 3400.0 3182.5 864.3N 113.7E 3340.2 3009.9 3411.5 3191.0 872.0N 115.0E 3351.6 3019.2 3500.0 3255.2 932.0N 125.2E 3436.1 3087.8 3550.4 3291.0 967.0N 131.2E 3484.3 3126.6 3600.0 3325.7 1001.9N 137.3E 3532.1 3165.0 3695.5 3391.0 1070.5N 149.2E 3623.4 3238.8 3700.0 3394.0 1073.8N 149.7E 3626.9 3241.7 : PGMS <O-7250'>,,M-1St#1,STEELHEAD Platform Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 47.8S 86.3E -176.8 110.5 110.5 46.8S 86.5E +176.0 110.3 110.3 32.8S 89.8E +132.2 108.8 108.8 31.2S 90.2E +129.9 108.6 108.6 11.7S 94.5E +111.7 108.4 108.4 9.7S 95.0E +110.3 108.4 108.5 14.8N 101.1E +96.6 111.6 111.8 17.2N 101.7E +95.4 112.0 112.2 47.1N 108.7E +83.1 119.2 119.8 49.5N 109.3E +82.2 119.9 120.6 68.3N 113.6E +75.8 126.0 127.1 83.9N 117.0E +71.2 131.7 133.3 86.4N 117.5E +70.5 132.6 134.3 124.4N 125.7E +61.4 149.4 153.0 126.6N 126.2E +60.9 150.4 154.1 168.9N 135.8E +53.6 172.7 179.4 170.1N 136.1E +53.4 173.4 180.1 215.6N 147.5E +48.0 200.6 210.2 215.7N 147.5E +48.0 200.7 210.3 267.3N 159.8E +43.0 229.6 239.2 269.4N 160.3E +42.8 230.7 240.3 322.5N 171.7E +38.6 256.3 264.4 327.1N 172.6E +38.3 258.5 266.3 380.2N 184.1E +34.7 278.8 283.1 389.3N 186.0E +34.1 281.4 285.3 434.5N 194.9E +32.1 294.1 296.2 444.8N 196.7E +31.8 296.7 298.6 481.3N 203.1E +30.7 305.0 306.7 496.0N 205.6E +30.3 308.0 309.6 528.2N 211.2E +29.6 314.7 316.2 546.1N 214.4E +29.4 318.5 319.9 575.7N 219.7E +28.8 323.8 325.2 600.8N 224.2E +28.4 328.3 329.6 625.2N 228.6E +28.1 332.2 333.3 658.7N 234.5E +27.6 337.2 338.2 675.4N 237.5E +27.5 339.7 340.7 718.6N 245.7E +27.1 345.8 346.7 727.6N 247.4E +27.0 347.0 347.8 784.4N 257.9E +26.5 353,0 353.5 785.3N 258.1E +26.5 353.1 353.6 843.5N 268.5E +26.1 356.7 356.8 858.1N 271.0E +26.1 357.1 357.1 903.2N 278.9E +26.1 357.0 357.0 931.6N 283.8E +26.2 356.1 356.2 962.0N 289.1E +26.4 354.4 354.7 1009.6N 296.9E +27.0 349.7 350.7 1022.2N 298.9E +27.2 348.0 349.2 1079.8N 308.5E +28.4 338.0 340.2 1086.4N 309.6E +28.5 336.6 339.0 1135.3N 317.1E +29.5 325.8 328.7 1163.5N 321.4E +30.2 319.1 322.3 1191.5N 325.8E +30.9 312.0 315.5 1244.2N 336.5E +33.0 297.4 301.4 1246.2N 337.0E +33.1 296.7 300.7 AIl data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wel[heed on azimuth 9.63 degrees. Calculation uses the minim~n curvature method. MARATHO# OIL company STEELHEAD Platform,H-30 HcArthur River Fie[d,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 5 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference wel[path Object weLLpath : PGMS <O-7250.>,,M-1St#1,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. T.V.D. 3778.0 3445.7 1131.3N 159.8E 3699.0 3300.4 3847.1 3491.0 1182.8N 168.8E 3757.0 3347.4 4000.0 3591.0 1296.7N 188.6E 3902.2 3464.0 4000.0 3591.0 1296.7N 188.6E 3902.3 3464.0 4152.8 3691.0 1410.5N 208.5E 4054.5 3587.2 4243.0 3750.0 1477.7N 220.2E 4141.9 3658.3 4305.6 3791.0 1524.4N 228.4E 4203.4 3708.5 4458.5 3891.0 1638.2N 248.3E 4352.2 3830.9 4500.0 3918.2 1669.2N 253.7E 4391.8 3863.7 4611.3 3991.0 1752.1N 268.2E 4498.0 3951.3 4764.2 4091.0 1866.0N 288.1E 4647.1 4074.8 4917.0 4191.0 1979.8N 308.0E 4792.2 4195.1 5000.0 4245.3 2041.6N 318.7E 4874.0 4262.6 5069.8 4291.0 2093.7N 327.8E 4941.0 4317.6 5222.7 4391.0 2207.5N 347.7E 5084.9 4438.5 5375.5 4491.0 2321.4N 367.6E 5230.6 4562.1 5500.0 4572.4 2414.1N 383.8E 5354.1 4665.2 5528.4 4591.0 2435.3N 387.5E 5381.2 4687.8 5681.2 4691.0 2549.1N 407.4E 5526.1 4808.5 5834.0 4791.0 2663.0N 427.3E 5676.9 4933.7 Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 12~.4N 34.8.4E +35.6 284.2 2~.2 1318.3N 359.8E +37.7 274.7 27-/'.0 1398.5N 392.~ +45.0 261.0 261.8 1398.5N 392.7E +45.0 261.0 261.8 1481.8N 425.5E +53.6 250.9 251.2 1529.2N 443.9E +58.9 247.1 247.2 1562.2N 456.8E +62.8 245.7 245.7 1641.2# 487.1E +72.5 246.2 246.3 1662.0N 495.1E +75.1 247.6 247.8 1718.0N 516.7E +81.8 254.0 254.7 1796.2N 546.1E +90.8 267.8 269.5 1872.3N 574.6E +98.5 287.5 291.0 1915.4N 590.8E +102.3 300.4 304.3 1951.3N 603.8E +105.0 311.7 316.6 2024.6N 630.4E +111.0 340.1 347.7 2097.4N 656.8E +116.4 372.6 382.2 2161.1N 679.8E +120.0 400.3 411.0 2175.3N 684.9E +120.6 406.7 417.9 2250.8N 712.0E +123.9 442.2 455.4 2329.9N 740.0E +126.9 478.7 492.0 AL[ data is in feet un[ess otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. FLARATHON OIL cOmPany STE£LHEAD PLatform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska Reference we[lpath CLEARANCE LISTING Page 6 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object wettpath : PMSS <6595-6988,>,,M-1St#1,STEELHEAD P[atform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9g 999.6 1000.0 999.7 11.3N 7.1W 1008.0 1091.3 1091.0 13.7N 8.4W 1099.8 1100.0 1099.7 14.1N 8.5W 1108.8 1191.5 1191.0 19.2N 9.3W 1199.8 1200.0 1199.5 19.8N 9.4~ 1208.1 1291.8 1291.0 27.7N 9.7g 1297.4 1300.0 1299.1 28.5N 9.7g 1305.3 1392.5 1391.0 39.2N 9.4W 1394.2 1400.0 1398.4 40.2N 9.4~ 1401.0 1452.1 1450.0 47.5N 9.OW 1450.9 1493.6 1491.0 53.9N 8.6W 1489.6 1500.0 1497.3 54.9N 8.5~ 1495.8 1595.2 1591.0 71.6N 7.1~ 1581.9 1600.0 1595.8 72.6N 7.OW 1586.5 1697.3 1691.0 92.6N 5.1~ 1673.1 1700.0 1693.6 93.1N 5.OW 1675.7 1800.0 1790.8 116.6N 2.4~ 1762.3 1800.2 1791.0 116.7N 2.4W 1762.5 1900.0 1887.1 143.0N 0.TE 1855.2 1904.0 1891.0 144.2N 0.gE 1859.0 2000.0 1982.7 172.3N 4.5E 1954.5 2008.7 1991.0 175.0N 4.8E 1962.9 2100.0 2077.3 204.4N 8.8E 2062.9 2114.6 2091.0 209.4N 9.5E 2081.0 2200.0 2170.8 239.4N 13.6E 2173.4 2221.7 2191.0 247.4N 14.8E 2194.9 2300.0 2263.3 277.1N 19.1E 2270.8 2330.2 2291.0 289.1N 20.8E 2300.9 2400.0 2354.5 317.6N 25.0E 2365.6 2440.4 2391.0 334.7N 27.6E 2400.9 2500.0 2444.5 360.8N 31.6E 2458.0 2552.3 2491.0 384.5N 35.2E 2505.6 2600.0 2533.0 406.7N 38.6E 2551.1 2666.3 2591.0 438.6N 43.6E 2612.5 2700.0 2620.2 455.2N 46.2E 2642.5 2782.6 2691.0 497.2N 52.9E 2718.8 2800.0 2705.7 506.3N 54.4E 2734.5 2900.0 2789.7 559.9N 63.0E 2831.7 2901.6 2791.0 560.8N 63.1E 2833.3 3000.0 2871.9 616.0N 72.1E 2932.2 3023.5 2891.0 629.6N 74.4E 2957.0 3100.0 2952.4 674.6N 81.8E 3034.1 3148.7 2991.0 704.0N 86.7E 3082.7 3200.0 3031.1 735.5N 91.9E 3134.9 3277.9 3091.0 784.6N 100.2E 3216.9 3300.0 3107.8 798.8N 102.6E 3238.9 3400.0 3182.5 864.3N 113.7E 3340.2 3411.5 3191.0 872.0N 115.0E 3351.6 3500.0 3255.2 932.0N 125.2E 3436.1 3550.4 3291.0 967.0N 131.2E 3484.3 3600.0 3325.7 1001.9N 137.3E 3532.1 3695.5 3391.0 1070.5N 149.2E 3623.4 3700.0 3394.0 1073.8N 149.7E 3626.9 AngLe fm Min'm TCyL T.V.D. Rect Coordinates HighSJde Dist Dist 996.2 47.8S 86.3E -176.8 110.5 110.5 1004.5 46.8S 86.5E +176.0 110.3 110.3 1095.2 32.8S 89.8E +132.2 108.8 108.8 1104.1 31.2S 90.2E +129.9 108.6 108.6 1192.8 11.7S 94.5E +111.7 108.4 108.4 1200.8 9.7S 95.0E +110.3 108.4 108.5 1286.5 14.8N 101.1E +96.6 111.6 111.8 1294.0 17.2N 101.7E +95.4 112.0 112.2 137'/.5 47.1N 108.7E +83.1 119.2 119.8 1383.8 49.5N 109.3E +82.2 119.9 120.6 1429.8 68.3N 113.6E +75.8 126.0 127.1 1465.0 83.9N 117.0E +71.2 131.7 133.3 1470.6 86.4N 117.5E +70.5 132.6 134.3 1547.5 124.4N 125.7E +61.4 149.4 153.0 1551.5 126.6N 126.2E +60.9 150.4 154.1 1626.5 168.9N 135.8E +53.6 172.7 179.4 1628.7 170.1N 136.1E +53.4 173.4 180.1 1701.5 215.6N 147.5E +48.0 200.6 210.2 1701.7 215.7N 147.5E +48.0 200.7 210.3 17'~7.7 267.3N 159.8E +43.0 229.6 239.2 1780.8 269.4N 160.3E +42.8 230.7 240.3 1859.4 322.5N 171.7E +38.6 256.3 264.4 1866.4 327.1N 172.6E +38.3 258.5 266.3 1950.3 380.2N 184.1E +34.7 278.8 283.1 1965.8 389.3N 186.0E +34.1 281.4 285.3 2046.0 434.5N 194.9E +32.1 294.1 296.2 2064.8 444.8N 196.7E +31.8 296.7 298.6 2131.0 481.3N 203.1E +30.7 305.0 306.7 2157.1 496.0N 205.6E +30.3 308.0 309.6 2212.9 528.2N 211.2E +29.6 314.7 316.2 2243.1 546.1N 214.4E +29.4 318.5 319.9 2291.7 575.7N 219.7E +28.8 323.8 325.2 2332.0 600.8N 224.2E +28.4 328.3 329.6 2370.1 625.2N 228.6E +28.1 332.2 333.3 2421.2 658.7N 234.5E +27.6 337.2 338.2 2446.0 675.4N 237.5E +27.5 339.7 340.7 2508.3 718.6N 245.7E +27.1 345.8 346.7 2521.0 727.6N 247.4E +27.0 347.0 347.8 2599.2 784.4N 257.9E +26.5 353.0 353.5 2600.5 785.3N 258.1E +26.5 353.1 353.6 2679.7 843.5N 268.5E +26.1 356.7 356.8 2699.7 858.1N 271.0E +26.1 357.1 357.1 2761.8 903.2N 278.9E +26.1 357.0 357.0 2800.9 931.6N 283.8E +26.2 356.1 356.2 2843.0 962.0N 289.1E +26.4 354.4 354.7 2909.3 1009.6N 296.9E +27.0 349.7 350.7 2927.2 1022.2N 298.9E +27.2 348.0 349.2 3009.9 1079.8N 308.5E +28.4 338.0 340.2 3019.2 1086.4N 309.6E +28.5 336.6 339.0 3087.8 1135.3N 317.1E +29.5 325.8 328.7 3126.6 1163.5N 321.4E +30.2 319.1 322.3 3165.0 1191.5N 325.8E +30.9 312.0 315.5 3238.8 1244.2N 336.5E +33.0 297.4 301.4 3241.7 1246.2N 337.0E +33.1 296.7 300.7 AlL data is in feet un[ess otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from weLLhead on azimuth 9.63 degrees. CaLculation uses the minimum curvature method. MARATHON OIL Company STEELHEAO PLatform,M-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 7 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object we[[path : PMSS <6595-6988'>,,M-1St#1,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 3778.0 3445.7 1131.3N 159.8E 3699.0 3847.1 3491.0 1182.8N 168.8E 3757.0 4000.0 3591.0 1296.7N 188.6E 3902.2 4000.0 3591.0 1296.7N 188.6E 3902.3 4152.8 3691.0 1410.5N 208.5E 4054.5 4243.0 3750.0 147T.TN 220.2E 4141.9 4305.6 3791.0 1524.4N 228.4E 4203.4 4458.5 3891.0 1638.2N 248.3E 4352.2 4500.0 3918.2 1669.2N 253.7E 4391.8 4611.3 3991.0 1752.1N 268.2E 4498.0 Angle fm Min'm TOy[ T.V.D. Rect Coordinates HighSide Dist Dist 3300.4 1286.4N 348.4E +35.6 284.2 288.2 3347.4 1318.3N 359.8E +37.7 274.7 27T.0 3464.0 1398.5N 392.7E +45.0 261.0 261.8 3464.0 1398.5N 392.7E +45.0 261.0 261.8 3587.2 1481.8N 425.5E +53.6 250.9 251.2 3658.3 1529.2N 443.9E +58.9 247.1 247.2 3708.5 1562.2N 456.8E +62.8 245.7 245.7 3830.9 1641.2N 487.1E +72.5 246.2 246.3 3863.7 1662.0N 495.1E +75.1 247.6 247.8 3951.3 1718.0N 516.7E +81.8 254.0 254.7 4764.2 4091.0 1866.0N 288.1E 4647.1 4917.0 4191.0 1979.8N 308.0E 4792.2 5000.0 4245.3 2041.6N 318.7E 4874.0 5069.8 4291.0 2093.7N 327.8E 4941.0 5222.7 4391.0 2207.5N 347.7E 5084.9 4074.8 1796.2N 546.1E +90.8 267.8 269.5 4195.1 1872.3N 574.6E +98.5 287.5 291.0 4262.6 1915.4N 590.8E +102.3 300.4 304.3 4317.6 1951.3N 603.8E +105.0 311.7 316.6 4438.5 2024.6N 630.4E +111.0 340.1 347.7 5375.5 4491.0 2321.4N 367.6E 5230.6 5500.0 4572.4 2414.1N 383.8E 5354.1 5528.4 4591.0 2435.3N 387.5E 5381.2 5681.2 4691.0 2549.1N 407.4E 5526.1 5834.0 4791.0 2663.0N 427.3E 5676.9 4562.1 2097.4N 656.8E +116.4 372.6 382.2 4665.2 2161.1N 679.8E +120.0 400.3 411.0 4687.8 2175.3N 684.9E +120.6 406.7 417.9 4808.5 2250.8N 712.0E +123.9 442.2 455.4 4933.7 2329.9N 740.0E +126.9 478.7 492.0 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHO# OIL STEELHEAD Platform,M-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska Reference we[[path CLEARANCE LISTING Page 8 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object we[lpath : PGMS <O-7419,>,,M-2,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9W 978.2 1000.0 999.? 11.3N ?.lW 986.1 1091.3 1091.0 13.7N 8.4W 1068.2 1100.0 1099.7 14.1N 8.5W 1073.9 1191.5 1191.0 19.2N 9.3W 1152.5 1200.0 1199.5 19.8N 9.4~ 1160.6 1291.8 1291.0 27.7N 9.714 1233.9 1300.0 1299.1 28.5N 9.714 1241.4 1392.5 1391.0 39.2N 9.4~ 1308.0 1400.0 1398.4 40.2N 9.4W 1314.5 1452.1 1450.0 47.5N 9.0~ 1349.7 1493.6 1491.0 53.9N 8.6W 1379.3 1500.0 1497.3 54.9N 8.5~ 1384.7 Angle fm Min'm TCyl T.V.D. Rect Coordinates RighSide Dist Dist 9?4.8 93.9S 84.5E -158.8 140.4 141.8 982.6 94.8S 84.8E -164.3 141.5 143.0 1063.7 107.?S 88.3E +155.1 157.6 161.8 1069.2 108.8S 8~.6E +153.3 159.5 164.1 1145.7 126.6S 92.3E +145.2 183.4 193.6 1153.5 128.6S 92.8E +145.0 186.0 196.9 1223.7 148.8S 98.5E +141.1 217.7 240.6 1230.8 151.1S 99.2E +141.0 220.8 245.2 1293.2 173.6S 105.8E +137.8 261.0 305.1 1299.2 176.0S 106.5E +137.8 264.6 310.7 1331.5 189.2S 110.6E +136.0 290.4 352.4 1358.5 200.8S 114.4E +135.0 312.3 390.2 1363.4 202.9S 115.2E +135.0 315.8 396.4 All data is in feet unless otherwise stated Coordinates are from slot ~1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD PLatform,M-30 McArthur River FieLd,TBU, Cook Inlet, Alaska CLEARANCE L%ST%NG Page 9 Your ref : N-30 Version #10 Last revised : 25-Feb-92 Referer.:e wellpath Object we[[path : PONS <3700-11700'>,,M-25,STEELHEAD Platform M.D. Angle fm Hin'm TCy[ T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Dist Dist 992.0 991.7 11.2N 6.9W 984.1 991.2 7.4S 6.3E -154.6 22.9 22.9 1000.0 999.7 11.3N 7.1W 992.4 999.5 7.6S 6.3E -160.7 23.2 23.2 1091.3 1091.0 13.7N 8.4W 1083.8 1090.9 8.3S 5.8E +163.7 26.3 26.3 1100.0 1099.7 14.1N 8.5W 1092.5 1099.6 8.4S 5.8E +162.4 26.6 26.7 1191.5 1191.0 19.2N 9.3W 1183.8 1190.9 8.6S 6.1E +155.7 31.8 31.9 1200.0 1199.5 19.8N 9.4W 1192.4 1199.4 8.6S 6.1E +155.6 32.4 32.5 1291.8 1291.0 27.7N 9.7~ 1284.0 1291.1 8.5S 6.1E +156.0 39.5 39.7 1300.0 1299.1 28.5N 9.7~ 1292.1 1299.2 8.5S 6.1E +156.2 40.2 40.4 1392.5 1391.0 39.2N 9.4~ 1383.8 1390.9 8.4S 6.0E +158.3 50.0 50.4 1400.0 1398.4 40.2N 9.4~ 1391.3 1398.4 8.4S 6.0E +158.5 51.0 51.4 1452.1 1450.0 47.5N 9.0~ 1442.7 1449.8 8.5S 6.2E +159.6 58.0 58.6 1493.6 1491.0 53.9N 8.6W 1483.8 1490.9 8.6S 6.2E +160.4 64.2 65.0 1500.0 1497.3 54.9N 8.5W 1490.2 1497.3 8.7S 6.1E +160.6 65.2 66.0 1595.2 1591.0 71.6N 7.1~ 1584.0 1591.0 8.7S 5.9E +162.0 81.4 82.8 1600.0 1595.8 72.6N 7.0~ 1588.7 1595.8 8.7S 5.9E +162.0 82.3 83.7 1697.3 1691.0 92.6N 5.1~ 1684.2 1691.2 8.6S 5.7E +162.6 101.7 104.1 1700.0 1693.6 93.1N 5.OW 1686.7 1693.8 8.65 5.7E +162.6 102.3 104.7 1800.0 1790.8 116.6N 2.4W 1783.6 1790.7 8.45 5.8E +162.2 125.3 129.3 1800.2 1791.0 116.7N 2.4~ 1783.8 1790.9 8.4S 5.8E +162.2 125.3 129.4 1900.0 1887.1 143.0N 0.TE 1880.2 1887.3 8.4S 5.6E +161.5 151.6 157.7 1904.0 1891.0 144,2N 0.9E 1884.1 1891.1 8.4S 5.6E +161.5 152.7 158.9 2000.0 1982.7 172.3N 4.5E 1975.0 1982.1 8.5S 5.7E +160.2 180.9 190.1 2008.7 1991.0 175.0N 4.8E 1983.6 1990.7 8.6S 5.7E +160.2 183.6 193.0 2100.0 2077.3 204.4N 8.8E 2070.5 2077.6 8.55 5.6E +159.1 213.0 226.4 2114.6 2091.0 209,4N 9.5E 2083.5 2090.6 8.5S 5.7E +158.8 217.9 232.1 2200.0 2170.8 239.4N 13.6E 2162.9 2170.0 8.8S 5.9E +157.4 248.3 266.7 2221.7 2191.0 247.4N 14.8E 2183.6 2190.6 8.8S 5.9E +157.2 256.4 276.0 2300.0 2263.3 277.1N 19.1E 2256.9 2264.0 8.8S 5.8E +156.2 286.2 311.1 2330.2 2291.0 289.1N 20.8E 2284.7 2291.8 8.7S 5.8E +155.7 298.2 325.6 2400.0 2354.5 317.6N 25.0E 2348.2 2355.2 8.6S 5.9E +154.6 326.8 360.5 2440.4 2500.0 2552.3 2600.0 2391.0 334.7N 27.6E 2383.0 2390.1 8.6S 6.0E +153.7 344.0 381.9 2444.5 360.8N 31.6E 2437.3 2444.3 8.7S 6.1E +152.8 370.4 415.2 2491.0 384.5N 35.2E 2483.6 2490.7 8.7S 6.1E +151.9 394.3 445.9 2533.0 406.7N 38.6E 2524.8 2531.9 8.8S 6.3E +151.0 416.7 475.4 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wet[heed on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD Platform,N-30 NcArthur River Field,TBU, Cook Inlet, Alaska Reference weltpath CLEARANCE LISTING Page 10 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Object we[[path : PGHS <O-10938,>,,H-29,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9S4 991.3 1000.0 999.7 11.3N 7.1W 999.3 1091.3 1091.0 13.7N 8.4W 1090.1 1100.0 1099.7 14.1N 8.5~ 1098.8 1191.5 1191.0 19.2N 9.3~ 1189.7 1200.0 1199.5 19.8N 9.4~ 1198.2 1291.8 1291.0 27.7N 9.7S4 1289.5 1300.0 1299.1 28.5N 9.7S4 1297.6 1392.5 1391.0 39.2N 9.4~ 1389.7 1400.0 1398.4 40.2N 9.4W 1397.1 1452.1 1450.0 47.5N 9.OW 1448.8 1493.6 1491.0 53.9N 8.6W 1490.2 1500.0 1497.3 54.9N 8.5~ 1496.5 1595.2 1591.0 71.6N 7.1~ 1590.6 1600.0 1595.8 72.6N 7.0~ 1595.4 1697.3 1691.0 92.6N 5.1W 1691.0 1700.0 1693.6 93.1N 5.0~ 1693.6 1800.0 1790.8 116.6N 2.4W 1790.5 1800.2 1791.0 116.7N 2.4W 1790.7 1900.0 1887.1 143.0N 0.7E 1886.7 1904.0 1891.0 144.2N 0.9E 1890.5 2000.0 1982.7 172.3N 4.5E 1982.0 2008.7 1991.0 175.0N 4.8E 1990.3 2100.0 2077.3 204.4N 8.8E 2076.1 2114.6 2091.0 209.4N 9.5E 2089.8 2200.0 2170.8 239.4N 13.6E 2169.4 2221.7 2191.0 247.4N 14.8E 2189.5 2300.0 2263.3 277.1N 19.1E 2261.9 2330.2 2291.0 289.1N 20.8E 2289.6 2400.0 2354.5 317.6N 25.0E 2352.3 2440.4 2391.0 334.7N 27.6E 2387.2 2500.0 2444.5 360.8N 31.6E 2440.6 2552.3 2491.0 384.5N 35.2E 2489.0 Angle fm Min'm TCy[ T.V.D. Rect Coordinates HighSide Dist Dist 991.2 18.4S 7.OW -119.2 29.7 29.7 999.2 18.6S 7.1W -125.5 29.9 29.9 1089.9 21.05 8.5~ -162.6 34.7 34.8 1098.6 21.2S 8.6~ -164.0 35.3 35.4 1189.4 24.4S 10.5~ -171.0 43.6 43.8 1197.9 24.7S 10.714 -171.2 44.5 44.8 1289.2 27.7S 12.7~1 -171.7 55.5 56.0 1297.2 28.0S 12.9S4 -171.6 56.6 57.1 1389.3 30.4S 14.8W -170.9 69.8 70.7 1396.7 30.5S 15.0W -170.8 71.0 71.8 1448.4 31.5S 16.0~ -170.2 79.3 80.4 1489.7 32.0S 16.8~ -169.8 86.3 8?,6 1496.1 32.1S 16.914 -169.7 87.4 88.8 1590.2 32.8S 18.6~ -168.5 105.1 107.1 1594.9 32.8S 18.6~ -168.4 106.0 108.2 1690.6 33.1S 20.OW -167.0 126.5 129.8 1693.2 33.1S 20.0~ -167.0 127.1 130.4 1790.0 33.3S 21.2~ -165.2 151.1 156.4 1790.3 33.3S 21.2W -165.2 151.2 156.4 1886.2 33.6S 22.5~ -163.4 178.2 186.0 1890.1 33.7S 22.6W -163.3 179.4 187.2 1981.6 34.0S 23.7S4 -161.6 208.2 219.5 1989.8 34.0S 23.8~ -161.5 211.0 222.6 2075.6 34.4S 24.8~ -159.8 241.3 257.1 2089.3 34.5S 25.0~ -159.6 246.3 262.9 2168.9 35.0S 26.0~ -158.1 277.2 298.8 2189.0 35.1S 26.2W -157.7 285.4 308.4 2261.4 35.4S 27.3W -156.4 316.0 345.3 2289.1 35.5S 27.7t4 -155.8 328.2 360.3 2351.8 35.8S 28.8~ -154.5 357.5 396.1 2386.7 36.1S 29.6~ -153.6 375.2 417.3 2440.0 36.5S 30.914 -152.6 402.2 449.0 2488.4 36.75 32.0~ -152.0 426.5 477.4 ALL data is in feet unless otherwise stated Coordinates are from slot g81-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the mini~ curvature method. MARATHON OIL Cc~iDany STEELHEN) Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 11 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference wellpath Object wellpath : GSS <975-2660'>,,M-29, STEELHEAD PLatform H.D. T.V.D. Rect Coordinates M.D. Angle fm Min'm TCyL T.V.D. Rect Coordinates HighSide Dist Dist 992.0 991.7 11.2N 1000.0 ~.7 11.3N 7.1W 1091.3 1091.0 13.~ 8.4W 1100.0 1099.7 14.1N 8.5W 1191.5 1191.0 19.2N 9.3W 991.3 991.1 18.4S 7.1W -119.1 29.7 29.7 999.2 999.1 18.6S 7.2W -125.4 29.9 29.9 1089.7 1089.6 21.0S 9.0~ -161.6 34.8 34.9 1098.4 1098.2 21.4S 9.2W -163.0 35.5 35.6 1190.5 1190.2 24.0S 11.3W -170.8 43.2 43.4 1200.0 1199.5 19.8N 9.4W 1291.8 1291.0 27.7N 9.7W 1300.0 1299.1 28.5N 9.714 1392.5 1391.0 39.2N 9.4W 1400.0 1398.4 40.2N 9.4~ 1199.0 1198.7 24.1S 11.5W -171.0 44.0 44.2 1290.3 1290.0 26.2S 12.9W -172.2 54.0 54.4 1298.4 1298.1 26.4S 13.0W -172.2 55.0 55.4 1390.4 1390.1 27.6S 14.0W -171.6 67.0 67.7 1397.9 1397.6 27.7S 14.0W -171.6 68.1 68.8 1452.1 1450.0 47.5N 9.OW 1493.6 1491.0 53.9N 8.6W 1500.0 1497.3 54.9N 8.5W 1595.2 1591.0 71.6N 7.1~ 1600.0 1595.8 72.6N 7.OW 1449.3 1449.0 28.4S 14.2W -170.8 76.1 77.0 1490.3 1490.0 28.9S 14.4W -170.1 83.0 84.2 1496.6 1496.3 28.9S 14.5W +170.0 84.1 85.4 1590.2 1589.8 30.0S 15.4W +168.4 102.0 104.1 1594.9 1594.6 30.1S 15.4~ +168.3 103.0 105.1 1697.3 1691.0 92.6N 5.1~ 1700.0 1693.6 93.1N 5.OW 1800.0 1790.8 116.6N 2.4~ 1800.2 1791.0 116.7N 2.4~ 1900.0 1887.1 143.0N 0.TE 1690.3 1690.0 30.9S 16.4W +166.8 124.0 127.3 1692.9 1692.6 30.9S 16.4W +166.7 124.6 128.0 1789.9 1789.6 31.6S 17.6W +165.0 149.0 154.2 1790.2 1789.8 31.6S 17.6W +165.0 149.1 154.3 1886.7 1~.3 32.1S 18.9W +163.4 176.2 183.9 1904.0 1891.0 144.2N 0.gE 2000.0 1982.7 172.3N 4.5E 2008.7 1991.0 175.0N 4.8E 2100.0 2077.3 204.4N 8.8E 2114.6 2091.0 209.4N 9.5E 1890.5 1890.2 32.1S 18.9t4 +163.4 177.4 185.1 1982.0 1981.7 32.4S 20.1W +161.7 206.2 217.3 1990.4 1990.0 32.4S 20.2~ +161.5 209.0 220.5 2075.4 2075.1 32.9S 21.5W +159.7 239.3 255.2 2089.1 2088.8 33.0S 21.714 +159.4 244.4 261.1 2200.0 2170.8 239.4N 13.6E 2221.7 2191.0 247.4N 14.8E 2300.0 2263.3 277.1N 19.1E 2330.2 2291.0 289.1N 20.8E 2400.0 2354.5 317.6N 25.0E 2168.5 2168.1 33.6S 22.9S4 +157.9 275.5 297.3 2188.5 2188.1 33.8S 23.2~ +157.5 283.7 306.9 2261.2 2260.8 34.3S 24.4W +156.2 314.5 343.4 2288.8 2288.4 34.5S 24.9S4 +155.7 326.8 358.3 2352.5 2352.1 34.8S 26.1~ +154.6 356.1 394.1 2440.4 2391.0 334.7N 27.6E 2500.0 2444.5 360.8N 31.6E 2388.9 2388.5 34.9S 26.8W +153.9 373.6 415.9 2442.6 2442.2 35.1S 27.7~/ +152.9 400.3 449.7 ALL data is in feet unless otherwise stated Coordinates are from slot ~B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Fietd, TBU, Cook Inlet, Alaska CLEARANCE L%STING Page 12 Your ref : H-30 Version#10 Last revised : 25-Feb-92 Reference wel[path Object we[[path : PGMS <12486-15276'>,,H-27,STEELHEAD P[atfom M.D. T.V.D. Rect Coordinates M.D. T.V.D. 992.0 991.7 11.2N 6.9t4 990.6 99~).2 1000.0 999.7 11.3N 7.1W 998.6 998.2 1091.3 1091.0 13.7N 8.4W 1089.0 10~.8.4 1100.0 1099.7 14.1N 8.5W 1097.7 1097.0 1191.5 1191.0 19.2N 9.3W 1188.5 1187.4 1200.0 1199.5 19.8N 9.4W 1197.0 1195.8 1291.8 1291.0 27.7N 9.714 1288.1 1286.3 1300.0 1299.1 28.5N 9.714 1296.2 1294.3 1392.5 1391.0 39.2N 9.4N 1387.9 1385.1 1400.0 1398.4 40.2N 9.4~ 1395.4 1392.5 1452.1 1450.0 47.5N 9.ON 1446.4 1442.9 1493.6 1491.0 53.9N 8.6W 1487.1 1483.1 1500.0 1497.3 54.9N 8.5~ 1493.5 1489.4 1595.2 1591.0 71.6N 7.1~ 1585.8 1580.1 1600.0 1595.8 72.6N 7.ON 1590.6 1584.8 1697.3 1691.0 92.6N 5.1N 1684.2 1676.3 1700.0 1693.6 93.1N 5.OW 1686.8 1678.8 1800.0 1790.8 116.6N 2.4W 1783.6 1772.7 1800.2 1791.0 116.7N 2.4W 1783.8 177'2.9 1900.0 1887.1 143.0N 0.7E 1880.2 1865.6 1904.0 1891.0 144.2N 0.9E 1884.1 1869.4 2000.0 1982.7 172.3N 4.5E 1975.9 1956.8 2008.7 1991.0 175.0N 4.8E 1984.4 1964.8 2100.0 2077.3 204.4N 8.8E 2070.7 2046.2 2114.6 2091.0 209.4N 9.5E 2084.8 2059.4 2200.0 2170.8 239.4N 13.6E 2165.0 2134.3 2221.7 2191.0 247.4N 14.8E 2184.4 2152.4 2300.0 2263.3 277.1N 19.1E 2256.2 2218.6 2330.2 2291.0 289.1N 20.8E 2283.2 2243.4 2400.0 2354.5 317.6N 25.0E 2346.3 2301.0 2440.4 2391.0 334.7N 27.6E 2382.9 2334.2 2500.0 2444.5 360.8N 31.6E 2436.3 2382.3 2552.3 2491.0 384.5N 35.2E 2484.1 2425.1 2600.0 2533.0 406.7N 38.6E 2527.6 2463.8 2~.3 2591.0 438.6N 43.6E 2587.6 2516.8 2700.0 2620.2 455.2N 46.2E 2618.0 2543.6 2782.6 2691.0 497.2N 52.9E 2694.1 2610.1 2800.0 2705.7 506.3N 54.4E 2709.2 2623.2 Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 11.0S 29.6E -176.3 42.8 42.9 10.8S 30.1E +174.2 43.3 43.4 8.0S 36.2E +132.5 49.7 49.8 7.7S 36.8E +130.5 50.4 50.6 3.2S 44.6E +117.3 58.5 58.8 2.7S 45.4E +116.5 59.3 59.6 3.7N 54.3E +110.2 68.5 68.8 4.4N 55.1E +109.8 69.3 69.7 12.5N 65.1E +106.6 79.4 79.9 13.2N 65.9E +106.4 80.2 80.7 18.2N 71.9E +105.5 86.3 87.0 22.3N 77.0E +105.1 91.6 92.4 23.0N 77.9E +105.1 92.4 93.2 33.4N 91.1E +104.6 106.0 107.3 33.9N 91.8E +104.6 106.7 108.0 46.0N 107.8E +104.3 123.0 125.0 46.3N 108.2E +104.3 123.4 125.5 60.6N 127.1E +104.2 142.2 145.1 60.7N 127.1E +104.2 142.3 145.1 77.2N 147.7E +104.0 162.4 1~.1 78.0N 148.5E +104.0 163.3 167.0 96.0N 169.9E +103.7 184.0 189.0 97.8N 172.0E +103.6 1~.0 191.0 116.4N 193.8E +103.4 207.3 213.8 119.5N 197.6E +103.4 210.8 217.6 138.0N 219.6E +103.2 232.4 241.2 142.6N 225.1E +103.2 238.2 247.6 160.0N 246.6E +103.0 259.8 271.7 1~.6N 255.0E +103.0 268.5 281.5 182.4N 275.4E +103.0 289.5 305.2 191.7N 287.6E +103.0 302.2 319.4 205.6N 306.1E +102.9 321.4 341.1 218.4N 323.1E +102.9 338.8 360.7 230.4N 339.0E +102.9 355.1 379.0 247.3N 361.3E +102.9 378.2 405.0 256.1N 372.9E +102.9 390.2 418.4 278.4N 402.3E +103.0 420.1 452.4 282.9N 408.1E +103.0 426.4 459.7 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wet[head on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELNEAD Platform,#-30 McArthur River Fietd,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 13 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference wel[path Object we[[path : PGMS <O-12930'>,,M-28,STEELHEAD Platform M.D. Angle fm Min'm TCyl T.V.D. Rect Coordinates H.O. T.V.D. Rect Coordinates HighSide Dist Dist 992.0 991.7 11.2N 6.9W 990.8 990.6 4.1S 28.7E +173.3 38.8 38.8 1000.0 999.7 11.3N 7.1W 998.8 998.6 4.OS 29.0E +167.1 39.2 39.2 1091.3 1091.0 13.7N 8.4W 1090.1 1089.7 2.0S 32.8E +127.6 44.2 44.2 1100.0 1099.7 14.1N 8.5W 1098.8 1098.4 1.8S 33.2E +125.8 44.6 44.7 1191.5 1191.0 19.2N 9.3W 1191.0 1190.5 2.1N 36.3E +115.5 48.7 48.8 1200.0 1199.5 19.8N 9.4W 1199.9 1199.3 2.6N 36.6E +114.9 49.0 49.1 1291.8 1291.0 27.7N 9.7t,/ 1292.6 1291.8 9.4N 38.7E +110.9 51.7 51.7 1300.0 1299.1 28.5N 9.7W 1300.8 1299.9 10.2N 38.8E +110.6 51.8 51.9 1392.5 1391.0 39.2N 9.4W 1394.0 1392.3 22.1N 41.0E +106.4 53.3 53.3 1400.0 1398.4 40.2N 9.4W 1401.5 1399.7 23.3N 41.2E +106.0 53.4 53.4 1452.1 1493.6 1500.0 1595.2 1600.0 1450.0 47.5N 9.0~ 1453.7 1451.2 31.7N 42.5E +103.7 53.9 53.9 1491.0 53.9N 8.6~ 1494.7 1491.6 38.7N 44.0E +102.0 54.7 54.7 1497.3 54.9N 8.5W 1501.1 1497.9 39.9N 44.2E +101.8 54.9 54.9 1591.0 71.6N 7.1W 1596.0 1590.6 59.3N 48.7E +97.1 57.2 57.2 1595.8 72.6N 7.OW 1600.8 1595.3 60.4N 49.0E +96.8 57.3 57.4 1697.3 1700.0 1800.0 1800.2 1900.0 1691.0 92.6N 5.1~ 1696.8 1687.6 85.9N 56.0E +89.5 61.6 61.6 1693.6 93.1N 5.0~ 1699.4 1690.1 86.7N 56.2E +89.3 61.7 61.8 1790.8 116.6N 2.4W 1797.0 1782.4 116.5N 66.1E +82.0 69.0 69.3 1791,0 116.7N 2.4W 1797.2 1782.7 116.6N 66.1E +82.0 69.0 69.4 1887.1 143.0N 0.TE 1893.6 1872.1 150.1N 79.0E +75.4 80.0 80.6 1904.0 2000.0 2008.7 2100.0 2114.6 1891.0 144.2N 0.9E 1897.5 1875.7 151.5N 79.6E +75.1 80.5 81.1 1982.7 172.3N 4.5E 1991.2 1961.2 187.1N 93.6E +70.1 92.8 93.7 1991.0 175.0N 4.8E 1999.8 1969.1 190.4N 94.9E +69.8 94.0 94.8 2077.3 204.4N 8.8E 2088.0 2048.6 226.0N 109.0E +66.4 106.4 107.6 2091.0 209.4N 9.5E 2101.6 2060.6 231.8N 111.2E +65.9 108.5 109.8 2200.0 2221.7 2300.0 2330.2 2400.0 2170.8 239.4N 13.6E 2180.4 2129.3 267.8N 125.3E +62.8 122.5 124.6 2191.0 247.4N 14.8E 2201.7 2147.5 278.0N 129.5E +62.0 126.4 128.8 2263.3 277.1N 19.1E 2273.8 2208.1 314.1N 144.4E +59.5 141.8 145.2 2291.0 289.1N 20.8E 2301.6 2231.1 328.6N 150.5E +58.6 148.2 152.1 2354.5 317.6N 25.0E 2364.0 2281.7 362.0N 165.0E +57.0 163.9 169.0 2440.4 2391.0 334.7N 27.6E 2401.2 2311.2 382.7N 174.1E +56.0 173.6 179.4 2500.0 2444.5 360.8N 31.6E 2455.4 2353.6 413.5N 188.1E +54.8 188.5 195.0 2552.3 2491.0 384.5N 35.2E 2504.1 2391.3 441.4N 201.0E +54.0 201.7 208.4 2600.0 2533.0 406.7N 38.6E 2549.6 2426.4 467.8N 213.2E +53.3 213.5 220.1 2666.3 2591.0 438.6N 43.6E 2614.5 2476.3 505.4N 230.4E +52.5 229.2 235.4 2700.0 2620.2 455.2N 46.2E 2647.7 2501.8 524.8N 239.2E +52.2 236.8 242.8 2782.6 2691.0 497.2N 52.9E 2728.9 2564.5 571.8N 260.6E +51.9 254.3 259.7 2800.0 2705.7 506.3N 54.4E 2746.3 2578.0 581.8N 265.2E +51.9 257.8 263.0 2900.0 2789.7 559.9N 63.0E 2845.1 2654.6 638.5N 291.2E +52.1 276.6 281.0 2901.6 2791.0 560.8N 63.1E 2846.7 2655.8 639.4N 291.6E +52.1 276.9 281.2 3000.0 2871.9 616.0N 72.1E 2945.2 2732.5 695.6N 317.4E +52.8 293.1 296.6 3023.5 2891.0 629.6N 74.4E 2968.3 2750.6 708.7N 323.4E +53.0 296.6 300.0 3100.0 2952.4 674.6N 81.8E 3044.4 2810.2 751.7N 343.2E +54.0 307.4 310.3 3148.7 2991.0 704.0N 86.7E 3092.4 2847.8 778.7N 355.7E +54.7 313.8 316.4 3200.0 3031.1 735.5N 91.9E 3143.3 2887.8 807.4N 369.0E +55.6 320.1 322.4 3277.9 3091.0 784.6N 100.2E 3221.1 2948.8 851.1N 389.1E +57.1 328.8 330.6 3300.0 3107.8 798.8N 102.6E 3243.9 2966.8 864.0N 394.9E +57.5 331.1 332.8 3400.0 3182.5 864.3N 113.7E 3343.7 3045.4 920.0N 420.1E +59.8 340.2 341.6 3411.5 3191.0 872.0N 115.0E 3355.0 3054.4 926.3N 422.9E +60.1 341.2 342.6 3500.0 3255.2 932.0N 125.2E 3439.2 3121.1 972.7N 444.8E +62.5 348.9 350.3 3550.4 3291.0 967.0N 131.2E 3489.4 3161.0 1000.1N 458.0E +64.1 353.2 354.5 3600.0 3325.7 1001.9N 137.3E 3539.0 3200.5 1027.2N 471.0E +65.7 357.3 358.5 3695.5 3391.0 1070.5N 149.2E 3634.2 3276.3 1079.5N 495.1E +69.0 364.6 365.6 3700.0 3394.0 1073.8N 149.7E 3638.6 3279.8 1081.9N 496.2E +69.2 364.9 366.0 ALL data is in feet unless otherwise stated Coordinates are from slot ~B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minim~mn curvature method. HARATHOfl OIL Company STEELHEAD Platform,N-30 NcArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE L%STING Page 14 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Reference ~eltpath Object weltpath : PGHS <O-12930,>,,H-28,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. Angle fm Hin'm TCyl T.V.D. Rect Coordinates HighSide Dist Dist 3778.0 3445.? 1131.3N 159.8E 3847.1 3491.0 1182.8N 168.8E 4000.0 3591.0 1296.7N 188.6E 4000.0 3591.0 1296.7N 188.6E 4152.8 3691.0 1410.5N 208.5E 3713.2 3339.4 1122.8N 514.9E +71.9 370.9 372.2 3779.9 3392.7 1159.2N 531.8E +74.6 376.8 378.5 3925.4 3509.2 1238.2N 568.4E +80.2 392.8 396.1 3925.4 3509.3 1238.2N 568.4E +80.2 392.8 396.1 4076.1 3630.3 1319.2N 606.8E +85.6 413.1 416.9 4243.0 3750.0 1477.7N 220.2E 4305.6 3791.0 1524.4N 228.4E 4458.5 3891.0 1638.2N 248.3E 4500.0 3918.2 1669.2N 253.7E 4611.3 3991.0 1752.1N 268.2E 4167.9 3703.4 1370.1N 629.0E +88.4 425.2 429.1 4230.5 3752.9 1405.4N 643.7E +90.2 433.6 437.9 4378.0 3868.3 1490.3N 678.8E +93.7 455.7 461.1 4419.0 3900.1 1514.3N 688.6E +94.6 462.0 467.5 4529.4 3985.0 1579.8N 715.2E +96.7 479.1 484.8 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from ~ellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 15 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference welLpath Object we[lpath : MSS <1103-2265'>,,M-26,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. T.V.D. 992.0 991.7 11.2N 6.91~ 983.6 991.8 1000.0 999.7 11.3N 7.1W 991.6 999.8 1091.3 1091.0 13.7N 8.4W 1083.2 1091.4 1100.0 1099.7 14.1N 8.5~ 1091.9 1100.1 1191.5 1191.0 19.2N 9.3W 1183.8 1191.8 1200.0 1199.5 19.8N 9.4W 1192.3 1200.4 1291.8 1291.0 27.7N 9.71~ 1284.2 1291.8 1300.0 1299.1 28.5N 9.71~ 1292.5 1300.0 1392.5 1391.0 39.2N 9.4W 1385.2 1391.7 1400.0 1398.4 40.2N 9.4W 1392.7 1399.1 1452.1 1450.0 47.5N 9.OW 1444.7 1450.2 1493.6 1491.0 53.9N 8.6W 1486.1 1490.8 1500.0 1497.3 54.9N 8.5W 1492.5 1497.0 1595.2 1591.0 71.6N 7.1W 1587.3 1589.8 1600.0 1595.8 72.6N 7.OW 1592.2 1594.5 1697.3 1691.0 92.6N 5.1W 1689.3 1689.1 1700.0 1693.6 93.1# 5.0~ 1692.0 1691.7 1800.0 1790.8 116.6N 2.4~ 1791.8 1788.6 1800.2 1791.0 1t6.7N 2.4W 1792.0 1788.8 1900.0 1887.1 143.0N 0.TE 1891.5 1885.1 1904.0 1891.0 144.2N 0.9E 1895.5 1889.0 2000.0 1982.7 172.3N 4.5E 1991.4 1981.4 2008.7 1991.0 175.0N 4.8E 2000.1 1989.8 2100.0 2077.3 204.4N 8.8E 2091.2 2077.2 2114.6 2091.0 209.4N 9.5E 2105.8 2091.1 2200.0 2170.8 239.4N 13.6E 2191.1 2172.6 2221.7 2191.0 247.4N 14.8E 2212.8 2193.2 Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 0.8N 4.2E -1~.2 15.3 15.3 0.8N 4.2E -172.6 15.5 15.5 2.7N 3.9E +148.7 16.6 16.6 3.ON 3.9E +147.0 16.6 16.6 8.1N 3.5E +135.9 17.0 17.0 8.8N 3.5E +135.2 17.0 17.0 17.6# 4.5E +125.7 17.4 17.4 18.6N 4.7E +124.6 17.5 17.5 32.2N 7.1E +110.9 18.0 18.0 33.5N 7.3E +109.6 18.0 18.0 43.0N 9.0E +100.6 18.6 18.6 50.9N 10.6E +94.5 19.4 19.4 52.2N 10.9E +93.7 19.6 19.6 71.4N 15.4E +84.8 22.6 22.6 72.5N 15.7E +84.5 22.8 22.8 93.7N 21.3E +80.9 26.5 26.5 94.3N 21.4E +80.9 26.6 26.6 117.4N 27.6E +81.2 30.2 30.2 117.4N 27.6E +81.2 30.2 30.2 141.8N 34.2E +84.3 33.5 33.5 142.8N 34.4E +84.5 33.6 33.7 167.5N 41.0E +89.4 36.9 36.9 169.8N 41.6E +89.9 37.2 37.2 194.7N 48.1E +95.7 40.5 40.6 198.8N 49.2E +96.8 41.1 41.1 223.4N 55.4E +102.9 44.7 44.8 229.8N 57.0E +104.5 45.8 45.8 Alt data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minim~n curvature method. MARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 16 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference wellpath Object we[[path : PGMS <2700-9101'>,,M-14,STEELHEAD P[atfom Angle fm Min'm TCy[ M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Gist Gist 992.0 991.7 11.2N 6.9'.I 981.8 989.8 89.7S 58.6W -92.2 113.4 113.4 1000.0 999.7 11.3N 7.1W 989.8 997.8 89.8S 58.6W -98.6 113.5 113.6 1091.3 1091.0 13.7N 8.4W 1081.3 1089.2 91.2S 59.1W -137.3 116.5 116.7 1100.0 1099.7 14.1N 8.5W 1090.0 1097.9 91.3S 59.2W -139.0 116.9 117.1 1191.5 1191.0 19.2N 9.3W 1181.4 1189.3 92.6S 59.5W -150.4 122.6 122.9 1200.0 1199.5 19.8N 9.4W 1189.9 1197.8 92.7S 59.6~ -151.0 123.2 123.6 1291.8 1291.0 27.7N 9.714 1281.8 1289.6 93.8S 59.8W -156.5 131.4 132.1 1300.0 1299.1 28.5N 9.7i4 1289.9 1297.7 93.8S 59.9W -156.8 132.3 133.0 1392.5 1391.0 39.2N 9.4W 1382.2 1390.1 94.6S 59.9W -160.2 143.1 144.3 1400.0 1398.4 40.2N 9.4~ 1389.6 1397.5 94.7S 59.~ -160.4 144.0 145.3 1452.1 1450.0 47.5N 9.OW 1441.5 1449.4 95.0S 59.8W -161.6 151.3 152.9 1493.6 1491.0 53.9N 8.6W 1482.8 1490.7 95.1S 59.714 -162.5 157.5 159.5 1500.0 1497.3 54.9N 8.5W 1489.1 1497.0 95.1S 59.7~4 -162.6 158.5 160.5 1595.2 1591.0 71.6N 7.1~ 1583.0 1590.8 95.3S 59.6W -163.5 174.9 178.1 1600.0 1595.8 72.6N 7.OW 1587.7 1595.6 95.3S 59.6~ -163.6 175.8 179.0 1697.3 1691.0 92.6N 5.1W 1683.0 1690.9 95.3S 59.6W -163.7 195.6 200.5 1700.0 1693.6 93.1N 5.OW 1685.6 1693.4 95.3S 59.6W -163.7 196.2 201.1 1800.0 1790.8 116.6N 2.4~ 1782.7 1790.6 95.4S 59.714 -163.2 219.6 226.7 1800.2 1791.0 116.7N 2.4~ 1783.0 1790.8 95.4S 59.7S4 -163.2 219.7 226.8 1900.0 1887.1 143.0N 0.TE 1879.4 1887.3 95.4S 59.6W -162.3 245.9 256.1 1904.0 1891.0 144.2N 0.9E 1883.3 1891.1 95.4S 59.6~ -162.2 247.0 257.3 2000.0 1982.7 172.3N 4.5E 1974.4 1982.3 95.4S 59.8~ -160.9 275.3 289.6 2008.7 1991.0 175.0N 4.8E 1982.7 1990.6 95.4S 59.8~ -160.8 278.0 292.7 2100.0 2077.3 204.4N 8.8E 2068.6 2076.5 95.5S 60.OW -159.4 307.8 327.3 2114.6 2091.0 209.4N 9.5E 2082.3 2090.2 95.5S 60.1W -159.2 312.7 333.1 2200.0 2170.8 239.4N 13.6E 2162.3 2170.2 95.8S 60.2~ -157,9 343.2 3(>8.9 2221.7 2191.0 247.4N 14.8E 2182.5 2190.4 95.8S 60.3~ -157.6 351.3 378.5 2300.0 2263.3 277.1N 19.1E 2255.3 2263.2 95.8S 60.4~ -156.4 381.3 415.0 2330.2 2291.0 289.1N 20.8E 2283.0 2290.9 95.8S 60.4~ -155.9 393.4 429.9 2400.0 2354.5 317,6N 25.0E 2346.3 2354.2 95.8S 60.4W -154.7 422.2 465.8 2440.4 2391.0 334.7N 27.6E 2383.0 2390.8 95.8S 60.4W -154.1 439.5 487.8 ALL data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD.Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska Reference wellpath CLEARANCE L%ST%NG Page 17 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object wellpath : PMSS <1006-7~S2'>,,M-15 St,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.91~ 971.5 1000.0 999.7 11.3N 7.1W 977.6 1091.3 1091.0 13.7N 8.4W 1062.2 1100.0 1099.7 14.1N 8.5~ 1067.9 1191.5 1191.0 19.2N 9.3~ 1154.1 T .V.D. Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 969.7 122.2S 78.9W -90.8 975.7 123.1S 79.3W -97.1 1059.2 136.2S 85.1W -134.4 1064.7 137.2S 85.5W -135.8 1149.0 154.1S 92.0W -145.4 1200.0 1199.5 19.8N 9.4~ 1162.3 1157.0 155.7S 1291.8 1291.0 27.7N 9.7t~ 1247.3 1239.9 172.9S 1300.0 1299.1 28.5N 9.7~ 1255.1 1247.5 174.5S 1392.5 1391.0 39.2N 9.4W 1340.8 1330.9 192.2S 1400.0 1398.4 40.2N 9.4W 1347.8 1337.7 193.6S 1452.1 1450.0 47.5N 9.0~ 1394.7 1383.3 203.4S 1493.6 1491.0 53.9N 8.6W 1431.3 1418.8 211.1S 1500.0 1497.3 54.9N 8.5~ 1437.3 1424.6 212.4S 1595.2 1591.0 71.6N 7.1~ 1522.3 1507.0 230.6S 1600.0 1595.8 72.6N 7.OW 1526.7 1511.2 231.5S 153.2 155.0 154.4 156.4 171.4 176.1 173.3 178.4 196.6 204.6 92.7W -146.0 198.9 207.2 100.3W -149.2 226.0 238.2 101.0~ -149.4 228.6 241.1 109.7W -150.4 259.3 277.2 110.5W -150.5 261.9 280.3 115.714 -150.4 280.7 303.0 120.0W -150.2 296.4 322.1 120.8~ -150.1 298.9 325.2 131.5W -149.4 337.4 376.6 132.1W -149.4 339.5 379.5 1697.3 1691.0 92.6N 5.1W 1605.1 1586.8 249.1S 143.0W -147.3 1700.0 1693.6 93.1N 5.0~ 1607.4 1589.0 249.6S 143.3~ -147.3 382.8 443.0 384.1 444.9 Alt data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minim~m~ curvature method. HARATHON OIL c°mPeny STEELHEAD Platform,N-30 HcArthur River Field,TBU, Cook Inlet, Alaska Reference we[[path CLEARANCE LISTING Page 18 Your ref : H-30 Version #10 Last revised : 25-Feb-92 Object we[[path : PHSS <1006-1449'>,,H-15,STEELHEAD Platform H.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9td 971.5 1000.0 999.7 11.3N 7.1W 977.6 1091.3 1091.0 13.7N 8.4W 1062.2 1100.0 1099.7 14.1N 8.5W 1067.9 1191.5 1191.0 19.2N 9.3W 1148.4 T .V.D. Angle fm Min'm TCy[ Rect Coordinates HighSide Dist Dist 969.7 122.2S 78.9~ -90.8 975.7 123.1S 79.3W -97.1 1059.2 136.2S 85.1W -134.4 1064.7 137.2S 85.5W -135.8 1143.2 153.6S 91.4W -144.8 153.2 155.0 154.4 156.4 171.4 176.1 17'5.3 1T8.4 197.2 207.5 1200.0 1199.5 19.8N 9.4W 1156.5 1151.1 155.4S 92.0W -145.3 199.7 210.7 1291.8 1291.0 27.7N 9.7N 1234.2 1226.0 175.1S 98.0t4 -147.7 230.6 251.0 1300.0 129<2.1 28.5N 9.7N 1241.7 1233.3 17'7.2S 98.6~ -147.9 233.6 255.2 ALl data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the mininun curvature method. MARATHON OIL C~pany STEELHEAD Platform,N-30 McArthur River Field,TBU, Cook Inlet, Alaska Reference welLpath CLEARANCE LISTING Page 19 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object we[[path : M-19 Version ~rS,,M-19,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9S4 986.8 1000.0 999.7 11.3N 7.1W 994.7 1091.3 1091.0 13.7N 8.4W 1086.3 1100.0 1099.7 14.1N 8.5~ 1095.5 1191.5 1191.0 19.2N 9.3W 1188.0 1200.0 1199.5 19.8N 9.4W 1196.5 1291.8 1291.0 27.7N 9.714 1289.6 1300.0 1299.1 28.5N 9.7S4 1297.7 1392.5 1391.0 39.2N 9.4~ 1391.6 1400.0 1398.4 40.2N 9.4W 1399.0 1452.1 1450.0 47.5N 9.0~ 1451.3 1493.6 1491.0 53.9N 8.6N 1492.7 1500.0 1497.3 54.9N 8.5~ 1499.0 1595.2 1591.0 71.6N 7.1N 1592.7 1600.0 1595.8 72.6N 7.OW 1597.4 1697.3 1691.0 92.6N 5.1W 1692.7 1700.0 1693.6 93.1N 5.0~ 1695.3 1800.0 1790.8 116.6N 2.4W 1792.4 1800.2 1791.0 116.7N 2.4W 1792.7 1900.0 1887.1 143.0N 0.TE 1888.8 1904.0 1891.0 144.2N 0.9E 1892.7 2000.0 1982.7 172.3N 4.5E 1982.3 2008.7 1991.0 175.0N 4.8E 1990.6 2100.0 2077.3 204.4N 8.8E 2067.5 2114.6 2091.0 209.4N 9.5E 2076.3 2200.0 2170.8 239.4N 13.6E 2144.1 2221.7 2191.0 247.4N 14.8E 2163.6 2300.0 2263.3 277.1N 19.1E 2221.5 Angle fm Min'm TCyl T.V.D. Rect Coordinates HighSide Dist Dist 985.9 100.9S 34.9~ -105.3 115.7 115.9 993.8 101.4S 34.4W -111.9 116.2 116.4 1085.0 107.2S 28.6~ -153.2 122.8 123.2 1094.2 107.7S 28.1~ -155.1 123.5 123.9 1186.5 112.2S 23.714 -167.2 132.2 132.9 1194.9 112.5S 23.3W -167.8 133.1 133.8 1287.9 115.5S 20.4W -171.7 143.6 144.7 1296.0 115.7S 20.2W -171.8 144.6 145.7 1389.9 117.25 18.6W -172.1 156.8 158.2 1397.3 117.3S 18.5~ -172.0 157.8 159.3 1449.6 117.5S 18.3~ +171.4 165.3 167.1 1491.0 117.5S 18.3~ +170.8 171.7 173.9 1497.3 117.5S 18.3W +170.6 172.7 175.0 1591.0 117.55 18.3~ +168.9 189.5 193.0 1595.8 117.5S 18.3W +168.8 190.4 194.0 1691.0 117.5S 18.3W +167.0 210.5 215.8 1693.6 117.5S 18.3~ +167.0 211.1 216.4 1790.8 117.5S 18.3W +165.2 234.7 242.4 1791.0 117.5S 18.3W +165.2 234.8 242.5 1887.1 117.5S 18.3~ +163.4 261.2 272.2 1891.0 117.5S 18.3~ +163.4 262.4 273.4 1980.6 117.6S 18.3~ +161.3 290.8 308.6 1988.9 117.6S 18.4W +161.2 293.6 312.2 2065.7 119.6S 19.0~ +158.0 325.4 355.5 2074.6 120.0S 19.1W +156.9 331.0 363.3 2142.3 124.0S 20.4W +153.8 366.1 414.6 2161.7 125.5S 20.9S4 +153.5 375.7 429.2 2219.3 130.9S 22.6~ +150.5 412.5 488.1 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVOs are from wellhead. Vertical section is from we[[heed on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL cOmPany STEELHEAO Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska Last revised : 25-Feb-92 Reference wetlpath Object weLtpath : GSS <436-1422,>,,M- CLEARANCE LISTING Page 20 Your ref : H-30 Version #10 H.D. T.V.D. Rect Coordinates H.D. T.V.D. Rect Coordinates 992.0 991.7 11.2N 6.9W 987.7 986.3 108.5S 26.9S4 1000.0 999.7 11.3N 7.1W 995.7 994.2 109.0S 26.5W 1091.3 1091.0 13.7N 8.4W 1089.3 1087.7 112.6S 22.0W 1100.0 1099.7 14.1N 8.5W 1099.1 1097.5 112.9S 21.6W 1191.5 1191.0 19.2N 9.3W 1191.0 1189.3 114.6S 18.2W 1200.0 1199.5 19.8N 9.4W 1199.5 1197.8 114.7S 18.1W 1291.8 1291.0 27.7N 9.7W 1290.2 1288.5 115.9S 18.6W 1300.0 1299.1 28.5N 9.7~1 1298.3 1296.6 116.0S 18.7W 1392.5 1391.0 39.2N 9.4~ 1391.4 1389.7 117.2S 20.0~ 1400.0 1398.4 40.2N 9.4W 1400.0 1398.3 117.2S 20.1W 19,STEELHEAD PLatform Angle fm Min'm TCy[ HighSide Dist Dist -109.8 121.6 121.7 -116.4 122.0 122.2 -156.7 127.1 127.4 -158.6 127.7 127.9 -169.9 134.1 134.5 -170.4 134.8 135.2 -172.3 143.9 144.8 -172.3 144.8 145.9 -171.9 156.8 158.2 -172.2 157.8 159.2 All data is in feet unless otherwise stated Coordinates are from slot #gl-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD PLatform,M-30 McArthur River Fie[d,TBU, Cook Inter, Alaska CLEARANCE LISTING Page 21 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference we[Lpath Object wettpath : MSS <1363-1859'>,,RLF #2,STEELHEAD Ptatfom M.D. T.V.D. Rect Coordinates Angle fm Min'm TCy[ M.D. T.V.D. Rect Coordinates HighSide Dist Dist 1291.8 1291.0 27.7N 9.714 1300.0 1299.1 28.5N 9.714 1392.5 1391.0 39.2N 9.4W 1400.0 1398.4 40.2N 9.4W 1452.1 1450.0 47.5N 9.OW 1703.2 1516.4 15.9S 121.3E +104.6 264.3 451.0 1707.6 1518.6 13.3S 118.4E +104.4 257.5 441.4 1757.4 1543.1 15.5N 86.1E +102.5 181.2 318.0 1761.6 1545.2 18.0N 8~.4E +102.3 175.1 307.2 1791.1 1559.8 35.2N 64.4E +100.4 132.7 232.4 1493.6 1491.0 53.9N 8.6W 1500.0 1497.3 54.9N 8.5W 1595.2 1591.0 71.6N 7.1W 1814.4 1571.4 48.9N 49.6E +97.9 99.3 170.9 1818.1 1573.2 51.1N 47.2E +97.4 94.2 161.5 1859.0 1593.5 75.4N 21.3E +78.6 28.8 32.3 Alt data is in feet un[ess otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertica[ section is from wet[heed on azimuth 9.63 degrees. Ca[cutation uses the minimtzn curvature method. MARATHON OIL Company STEELHEN) Platform,M-30 McArthur River Fietd,TBU, Cook Inlet, Alaska Reference welLpath CLEARANCE LISTING Page 22 Your ref : #-30 Version #10 Last revised : 2S-Feb-92 Object welLpath : PGMS <O-2310'>,,RLF #1,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 1452.1 1450.0 47.5N 9.OW 1753.2 1493.6 1491.0 53.9N 8.6W 1785.8 1500.0 1497.3 54.9N 8.5~ 1790.0 1595.2 1591.0 71.6N 7.1W 1868.8 1600.0 1595.8 72.6N 7.OW 1872.8 Angke fm Min'm TCy[ T.V.D. Rect Coordinates HighSicle Dist Dist 1694.7 60.OS 272.3E +108.9 388.0 474.0 1718.7 43.1S 257.9E +108.2 363.7 446.2 17"21.8 41.0S 256.0E +11~8.1 359.9 441.8 1779.8 0.6S 221.3E +106.5 305.0 373.4 1782.7 1.4N 219.5E +106.4 302.2 369.9 1697.3 1691.0 92.6N 5.1W 1952.6 1700.0 1693.6 93.1N 5.OW 1954.8 1800.0 1790.8 116.6N 2.4W 2038.9 1800.2 1791.0 116.71~ 2.4W 2039.1 1900.0 1887.1 143.0N 0.TE 2124.3 1842.0 41.1N 185.6E +105.0 247.1 299.4 1843.6 42.2N 182.7E +105.0 245.6 297.5 1905.2 84.4N 143.9E +103.3 188.6 228.2 1905.4 84.5N 143.8E +103.3 188.5 228.0 1967.1 127.8N 104.2E +100.8 131.7 159.7 1904.0 1891.0 144.2N 0.gE 2127.6 2000.0 1982.7 172.3N 4.5E 2206.5 2008.7 1991.0 175.0N 4.8E 2213.7 2100.0 2077.3 204.4N 8.8E 2287.9 2114.6 2091.0 209.4N 9.5E 2299.7 1969.4 129.4N 102.7E +100.7 129.4 157.0 2025.3 170.6N 65.0E +95.7 74.0 90.4 2030.3 174.4N 61.6E +94.9 69.0 84.3 2082.0 213.8N 25.8E +62.3 19.9 22.4 2090.2 220.1N 20.OE +39.6 15.1 15.6 All data is in feet unless otherwise stated Coordinates are from slot ~B1-9 and TVOs are from wetkhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimun curvature method. MARATHON OIL Company STEELHEAD PLatform,H-30 McArthur River Field,TBU, Cook InLet, Alaska CLEARANCE LISTING Page 23 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference wet[path Object wel[path : *M-7* Version #5,,*M-7*,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. T.V.D. 992.0 991.7 11.2N 6.9t4 986.9 981.6 1000.0 999.7 11.3N 7.1W 994.6 989.1 1091.3 1091.0 13.7N 8.4W 1079.9 1071.0 1100.0 1099.7 14.1N 8.5W 10~.2 1079.0 1191.5 1191.0 19.2N 9.3W 1172.8 1159.0 1200.0 1199.5 19.8N 9.4W 1179.7 1165.5 1291.8 1291.0 27.7N 9.7W 1262.8 1242.7 1300.0 1299.1 28.5N 9.7~J 1270.6 1249.9 1392.5 1391.0 39.2N 9.4~ 1350.8 1322.9 1400.0 1398.4 40.2N 9.4W 1357.9 1329.3 1452.1 1450.0 47.5N 9.OW 1402.5 1369.3 1493.6 1491.0 53.9N 8.6W 1439.1 1401.7 1500.0 1497.3 54.9N 8.5~ 1445.1 1407.0 1595.2 1591.0 71.6N 7.1W 1526.1 147'/.4 1600.0 1595.8 72.6N 7.0~ 1527.6 1478.8 1697.3 1691.0 92.6N 5.1~ 1608.4 1547.2 1700.0 1693.6 93.1N 5.OW 1610.8 1549.2 1800.0 1790.8 116.6N 2.4W 1692.1 1616.2 1800.2 1791.0 116,7N 2.4~ 1692.4 1616.4 1900.0 1887.1 143.0N 0.TE 1771.5 1679.6 1904.0 1891.0 144.2N 0.9E 1775.2 1682.5 2000.0 1982.7 172.3N 4.5E 1848.8 1739.5 2008.7 1991.0 175.0N 4.8E 1851.8 1741.7 AngLe fm Min'm TCyl Rect Coordinates HighSide Dist Dist 10.5S 108.0E +160.4 117.5 118.2 8.8S 109.0E +153.4 118.3 119.1 11.7N 120.9E +107.1 130.8 132.8 13.9N 122.1E +104.7 132.3 134.4 37.6N 135.8E +87.1 149.8 153.7 39.7N 137.0E +86.0 151.6 155.7 66.2N 152.4E +75.8 173.4 180.0 68.9N 153.9E +75.1 175.5 182.4 97.5N 170.4E +68.4 200.9 211.0 100.1N 171.9E +67.9 203.0 213.4 117.3N 181.8E +65.1 218.6 231.1 132.0N 190.3E +63.0 231.6 246.0 134.5N 191.7E +62.7 233.6 248.3 169.0N 211.7E +59.1 265.1 284.7 169.8N 212.1E +59.1 2~.8 286.7 206.8N 233.5E +56.4 301.1 327.0 208.0N 234.2E +56.3 302.1 328.1 247.9N 257.3E +54.1 339.3 372.4 248.1N 257.3E +54.1 339.4 372.6 289.2N 281.1E +52.4 378.2 419.5 291.2N 282.2E +52.3 379.8 421.4 331.7N 305.6E +51.1 418.6 469.1 333.4N 306.6E +51.2 422.2 473.6 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. CaLcuLation uses the minimum curvature method. MARATHON OIL company STEELHEAD Platform,M-30 McArthur River Field,TBU, Cook Inlet, Alaska Reference weLlpath CLEARANCE LISTING Page 24 Your ref : M-30 Version #10 Last revisecl : 25-Feb-92 Object we[[path M.D. T.V.D. Rect Coordinates M.D. T.V.D. 992.0 991.7 11.2N 6.914 992.3 991.9 1000.0 999.7 11.3N 7.1W 1000.3 999.9 1091.3 1091.0 13.7N 8.4W 1092.1 1091.4 1100.0 1099.7 14.1N 8.5~ 1100.8 1100.1 1191.5 1191.0 19.2N 9.3~ 1192.6 1191.4 1200.0 1199.5 19.8N 9.4W 1201.1 1199.9 1291.8 1291.0 27.7N 9.7t4 1293.2 1291.1 1300.0 1299.1 28.5N 9.714 1301.3 1299.2 1392.5 1391.0 39.2N 9.4~ 1393.8 1390.5 1400.0 1398.4 40.2N 9.4W 1401.3 1397.8 1452.1 1450.0 47.5N 9.0~ 1453.3 1448.9 1493.6 1491.0 53.9N 8.6W 1494.7 1489.5 1500.0 1497.3 54.9N 8.5~ 1501.1 1495.7 1595.2 1591.0 71,6N 7.1~ 1595.9 1588.0 1600.0 1595.8 72.6N 7.OW 1600.7 1592.6 1697.3 1691.0 92.6N 5.1~ 1697.4 1685.9 1700.0 1693.6 93.1N 5.0~ 1700.0 1688.5 1800.0 1790.8 116.6N 2.4~ 1799.1 1783.1 1800.2 1791.0 116.7N 2.4~ 1799.3 1783.4 1900.0 1887.1 143.0N 0.TE 1897.8 1876.4 1904.0 1891.0 144.2N 0.9E 1901.6 1880.0 2000.0 1982.7 172.3N 4.5E 1996.3 1968.3 2008.7 1991.0 175.0N 4.8E 2004.6 1976.1 2100.0 2077.3 204.4N 8.8E 2094.4 2058.6 2114.6 2091.0 209.4N 9.5E 2108.4 2071.5 2200.0 2170.8 239.4N 13.6E 2192.1 2147.3 2221,7 2191.0 247.4N 14.8E 2213.1 2166.1 2300.0 2263.3 277.1N 19.1E 2289.5 2234.1 2330.2 2291.0 289.1N 20.8E 2318.8 2260.0 2400.0 2354.5 317.6N 25.0E 2386.4 2319.1 2440.4 2391.0 334.7N 27.6E 2425.6 2353.0 2500.0 2444.5 360.8N 31.6E 2483.0 2402.1 2552.3 2491.0 384.5N 35.2E 2533.6 2444.9 2600.0 2533.0 406.7N 38.6E 2580.4 2484.3 2666.3 2591.0 438.6N 43.6E 2645.8 2539.4 2700.0 2620.2 455.2N 46.2E 2679.1 2567.4 2782.6 2691.0 497.2N 52.9E 2760.7 2636.1 2800.0 2705.7 506.3N 54.4E 2777.8 2650.5 2900.0 2789.7 559.9N 63.0E 2876.6 2733.6 2901.6 2791.0 560.8N 63.1E 2878.1 2734.9 3000.0 2871.9 616.0N 72.1E 2975.1 2816.5 3023.5 2891.0 629.6N 74.4E 2998.2 2836.0 3100.0 2952.4 674.6N 81.8E 3073.5 2899.3 3148.7 2991.0 704.0N 86.7E 3121.3 2939.6 3200.0 3031.1 735.5N 91.9E 3171.5 2981.8 3277.9 3091.0 784.6N 100.2E 3247.6 3045.8 3300.0 3107.8 798.8N 102.6E 3269.2 3064.0 3400.0 3182.5 864.3N 113.7E 3366.3 3145.7 3411.5 3191.0 872.0N 115.0E 3377.5 3155.1 3500.0 3255.2 932.0N 125.2E 3462.8 3227.0 3550.4 3291.0 967.0N 131.2E 3511.3 3267.7 3600.0 3325.7 1001.9N 137.3E 3558.7 3307.6 3695.5 3391.0 1070.5N 149.2E 3649.5 3384.0 3700.0 3394.0 1073.8N 149.7E 3653.8 3387.6 : *M-32' Version ~5,,*M-32*,STEELHEAD Platform Angle fm Min'm TCyl Rect Coordinates HighSicle Dist Dist 6.9S 11.714 -104.8 18.7 18.7 6.7S 12.1W -110.0 18.7 18.7 2.5S 17.5W -134.0 18.5 18.5 1.9S 18.0W -134.2 18.6 18.6 5.5N 23.4~ -129.0 19.7 19.7 6.3N 24.0W -128.2 19.9 19.9 17.0N 29.6W -118.0 22.6 22.7 18.0N 30.1W -117,0 23.0 23.0 31.9N 35.9~ -107.5 27.5 27.5 33.2N 36.4W -106.8 27.9 28.0 42.4N 39.7t4 -102.4 31.1 31.2 50.4N 42.4W -99.2 34.0 34.1 51.7N 42.8W -98.8 34.4 34.6 72.5N 49.0~ -93.1 41.9 42.1 73.6N 49.3~ -92.8 42.4 42.5 98.1N 55.714 -88.4 51.2 51.4 98.8H 55.914 -88.3 51.4 51.7 127.2N 62.6W -84.9 61.6 61.9 127.3N 62.6W -84.9 61.6 61.9 158.8N 69.4W -82.3 72.6 73.1 160.1N 69.6W -82.2 73.1 73.6 193.5N 76.2~ -80.2 84.6 85.3 196.6N 76.8~ -80.0 85.7 86.4 231.1N 83.1W -78.5 97.5 98.4 236.8N 84.1~ -78.2 99.4 100.4 271.7N 90.1~ -77.0 111.2 112.3 280.8N 91.6~ -76.8 114.2 115.4 315.1N 97.0~ -75.9 125.6 127.1 328.8N 99.2W -75.5 130.1 131.7 361.3N 104.1~ -74.8 140.8 142.6 380.8N 106.914 -74.5 147.2 149.1 410.1N 111.1~ -73.9 156.8 159.0 436.8N 114.8W -73.5 165.4 167.8 461.8N 118.2~ -73.2 173.3 175.6 496.8N 123.0~ -73.2 183.9 186.3 514.6N 125.5W -73.4 189.2 191.6 558.3N 131.5W -74.0 201.8 204.2 567.5N 132.7~ -74.3 204.4 206.8 620.3N 140.0W -75.8 219.1 221.4 621.2N 140.1W -75.8 219.3 221.6 673.1N 147.2~ -77.8 233.3 235.7 685.5N 148.9W -78.4 236.6 239.1 725.7N 154.4W -80.3 247.5 250.0 751.3N 157.914 -81.7 254.4 257.1 778.2N 161.6W -83.1 261.8 264.7 818.9N 167.2~ -85.5 273.3 276.6 830.5N 168.8W -86.2 276.7 280.1 882.5N 175.9W -89.6 292.5 296.6 888.4N 176.7~4 -89.9 294.4 298.6 934.1N 183.0W -93.0 309.5 314.8 960.0N 186.5~ -94.7 318.7 324.7 985.4N 190.0W -96.4 328.2 335.0 1034.0N 196.714 -99.7 347.8 356.7 1036.3N 197.0~ -99.9 348.8 357.8 ALL data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wet[head. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAD Platform,M-30 McArthur River Field,TBU, Cook Inlet, ALaska Reference wettpath CLEARANCE LISTING Page 25 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object wettpath : *H-32' Version ffS,,*H-32*,STEELHEAD PLatform M.D. T.V.D. Rect Coordinates M.D. 3778.0 3445.7 1131.3N 159.8E 3727.3 3847.1 3491.0 1182.8N 168.8E 3792.4 4000.0 3591.0 1296.7N 188.6E 3936.0 4000.0 3591.0 1296.7N 188.6E 3936.0 4152.8 3691.0 1410.5N 208.5E 4079.6 Angle fm Min'm TCyl T.V.D. Rect Coordinates HighSide Dist Dist 3449.5 1075.7N 202.4W -102.5 366.4 377.6 3504.2 1110.5N 207.1W -105.0 38.~.0 395.9 3625.1 1187.4N 217.7W -109.6 422.1 438.6 3625.1 1187.4N 217.~ -109.6 422.1 438.6 3746.0 1264.2N 228.2W -113.5 463.8 484.0 All data is in feet unless otherwise stated Coordinates are from slot ~1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHO~ OIL Company STEELHEAD Platform,M-30 McArthur River Field, TBU, Cook Inlet, Alaska Last revised : 25-Feb-92 Reference welLpath Object welLpeth : *M-31' Version #1,, CLEARANCE LISTING Page 26 Your ref : M-30 Version #10 H.D. T.V.D. Rect Coordinates H.D. T.V.D. Rect Coordinates 992.0 991.7 11.2N 6.9W 991.2 991.2 12.8S 12.0E 1000.0 999.7 11.3N 7.1W 999.2 999.1 12.9S 12.2E 1091.3 1091.0 13.7N 8.4W 1089.8 1089.6 13.1S 16.1E 1100.0 1099.7 14.1N 8.5W 1098.4 1098.3 13.1S 16.6E 1191.5 1191.0 19.2N 9.3W 1188.7 1188.2 12.9S 23.4E 1200.0 1199.5 19.8N 9.4W 1197.1 1196.6 12.8S 24.2E 1291.8 1291.0 27.7N 9.714 1287.0 1285.9 12.1S 34.1E 1300.0 1299.1 28.5N 9.7~/ 1295.1 1294.0 12.0S 35.1E 1392.5 1391.0 39.2N 9.4W 1384.7 1382.6 10.8S 48.0E 1400.0 1398.4 40.2N 9.4W 1392.0 1389.9 10.6S 49.2E 1452.1 1450.0 47.5N 9.OW 1442.0 1439.1 9.7S 57.6E 1493.6 1491.0 53.9N 8.6W 1481.5 1477.9 8.9S 64.9E 1500.0 1497.3 54.9N 8.5W 1487.7 1484.0 8.8S 66.1E 1595.2 1591.0 71.6N 7.1~ 157'/.6 1571.9 6.6S 84.9E 1600.0 1595.8 72.6N 7.0~ 1582.3 1576.4 6.4S 85.9E 1697.3 1691.0 92.6N 5.1W 1672.6 1664.0 3.7S 107.7E 1700.0 1693.6 93.1N 5.OW 1675.1 1666.5 3.65 108.3E 1800.0 1790.8 116.6N 2.4W 1767.6 1755.4 0.3S 133.4E 1800.2 1791.0 116.7N 2.4W 1767.8 1755.7 0.3S 133.5E 1900.0 1887.1 143.0N 0.7E 1857.0 1840.6 3.3N 160.4E 1904.0 1891.0 144.2N 0.9E 1860.7 1844.1 3.4N 161.6E 2000.0 1982.7 172.3N 4.5E 1944.2 1922.8 7.2N 189.2E 2008.7 1991.0 175.0N 4.8E 1952.3 1930.4 7.6N 192.0E 2100.0 2077.3 204.4N 8.8E 2031.4 2004.1 11.6N 220.5E 2114.6 2091.0 209.4N 9.5E 2042.4 2014.3 12.2N 224.6E 2200.0 2170.8 239.4N 13.6E 2114.3 2080.5 16.1N 252.5E 2221.7 2191.0 247.4N 14.8E 2133.7 2098.2 17.2N 260.3E 2300.0 2263.3 277.1N 19.1E 2197.5 2156.1 21.1N 286.8E 2330.2 2291,0 289.1N 20.8E 2221.1 217-/.4 22.5N 296.9E *M-31*,STEELHEAD Platform Angle fm Min'm TCyl HighSide Dist Dist -157.5 30.6 30.7 -164.1 31.0 31.0 +154.0 36.4 36.5 +152.1 37.0 37.2 +138.8 46.0 46.3 +138.0 47.0 47.3 +131.4 59.4 60.1 +131.0 60.6 61.4 +127.0 76.6 78.0 +126.8 78.0 79.6 +125.2 88.5 90.6 +124.1 97.6 100.2 +123.9 99.0 101.8 +121.9 122.3 126.8 +121.9 123.5 128.2 +120.3 150.7 158.0 +120.2 151.5 158.8 +119.0 182.7 194.0 +119.0 182.8 194.1 +117.8 217.2 233.8 +117.7 218.7 235.5 +116.6 254.9 278.5 +116.6 258.3 282.7 +115.7 295.6 328.4 +115.4 301.8 336.1 +114.6 339.2 383.7 +114.5 349.0 396.4 +113.7 385.6 444.8 +113.4 400.2 464.4 Att data is in feet un[ess otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company STEELHEAO Platform,M-30 McArthur River Fie[d,TBU, Cook Inlet, Alaska Reference weLLpath CLEARANCE LISTING Page 27 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Object we[[path : PGMS <O-?434'>,,M-13,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 992.0 991.7 11.2N 6.9l,~ 969.6 1000.0 ~.7 11.3N 7.1W 976.4 1091.3 1091.0 13.7N 8.4W 1063.5 1100.0 1099.7 14.1N 8.5W 1070.3 1191.5 1191.0 19.2N 9.3W 1155.7 1200.0 1199.5 19.8N 9.4W 1164.0 1291.8 1291.0 27.7N 9.714 1244.9 1300.0 1299.1 28.5N 9.714 1252.7 1392.5 1391.0 39.2N 9.4W 1334.4 1400.0 1398.4 40.2N 9.4W 1338.8 1452.1 1450.0 47.5N 9.OW 1384.5 1493.6 1491.0 53.9N 8.6~ 1420.3 1500.0 1497.3 54.9N 8.5W 1426.2 1595.2 1591.0 71.6N 7.1W 1499.7 1600.0 1595.8 72.6N 7.OW 1501.6 Angle fm Min'm TCy[ T.V.D. Rect Coordinates HighSide Oist Dist 976.5 93.9S 92.5W -80.2 136.4 137.2 983.2 94.2S 93.3W -86.3 137.3 138.2 1069.3 99.2S 105.3W -121.7 150.4 152.7 1076.0 99.6S 106.4W -123.1 151.9 154.4 1159.8 105.4S 121.4W -130.9 170.5 175.5 116~.0 106.0S 123.0W -131.3 172.4 177.8 1246.8 113.0S 139.9W -133.3 196.7 206.6 1254.4 113.7S 141.714 -133.4 199.1 209.5 1333.2 122.5S 161.1W -133.9 229.2 246.0 1337.5 123.0S 162.2W -133.8 231.8 249.3 1381.2 128.6S 174.0W -133.7 251.0 273.4 1415.4 133.3S 183.6W -133.6 267.2 295.2 1421.0 134.1S 185.2W -133.6 269.8 298.8 1490.7 144.55 200.4~ -132.5 310.6 359.9 1492.4 144.8S 206.914 -132.2 312.8 363.4 1697.3 1691.0 92.6N 5.1W 1574.8 1560.6 1700.0 1693.6 93.1N 5.OW 1574.1 1559.8 157.0S 230.9W -130.9 360.9 442.8 156.8S 230.6W -130.6 362.3 445.2 All data is in feet unless otherwise stated Coordinates are from slot #B1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimum curvature method. ~ARATHON OIL Co~)an¥ STEELHEAO Platform,N-30 HcArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 28 Your ref : M-30 Version #10 Last revised : 25-Feb-92 Reference weLlpath Object wellpath : PGMS <O-992'>,,M-30,STEELHEAD Platform 992.0 T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates 991.7 11.2N 6.914 992.0 991.7 11.2N 6.9t4 Angle fm Min'm TCy[ HighSide Oist Dist +91.5 0.0 0.0 ALL data is in feet unless otherwise stated Coordinates are from slot ~1-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 9.63 degrees. Calculation uses the minimta~ curvature method. MARATHON OIL Con~any STEELHEAD Platform slot #B1-9 McArthur River Field TBU, Cook Inlet, Alaska CLEARANCE REPORT Your ref : M-30 Version #10 ~ II Our ref : prop]01 Other ref = Date printed : 25-Feb-92 Date created : 4-Nov-91 Last revised : 25-Feb-92 Field is centred on 0.000,0.000,-189.00000,N Structure is centred on 0.000,0.000,-189.00000,N Main calculation performed with 3-D minimum distance method Object wellpath GMS <O-12900'>,,K-5,KING SALMON Platform GMS <9424-12940'>,,K-2Rd,KING SALMON Platform GMS <O-9324'>,,K-2,KING SALMON Platform GMS <0-11650'>,,K-9,KING SALMON Platform MSS <0-8580'>,,K-20,KING SALMON Platform GMS <0-14700'>,,K-23,KING SALMON Platform MSS <0-12600'>,,K-30,KING SALMON Platform MSS <39-13196'>,,K-30Rd,KING SALMON Platform GMS <10000-12450'>~,K-21Rd,KING SALMON Platfor GMS <0-12T70'>,,K-21,KING SALMON Platform GMS <0-14200'>,,K-24,KING SALMON Platform PGMS <0-14325'>,,K-25,KING SALMON Platform Closest approach Last revised Distance M.D. Diverging from 29-0ct-91 3171.0 12603.0 12603.0 29-0ct-91 3060.3 12753.0 12753.0 29-0ct-91 29-0ct-91 1006.8 11900.0 11900.0 29-0ct-91 8750.6 10440.0 10440.0 29-0ct-91 4371.0 12703.0 12803.0 29-0ct-91 1782.4 12240.0 12240.0 29-0ct-91 1782.4 12240.0 12240.0 29-0ct-91 6679.5 10880.0 11100.0 29-0ct-91 6679.5 10880.0 11120.0 29-0ct-91 8458.4 10740.0 10740.0 29-0ct-91 7452.6 11560.0 11560.0 Plan View STEELHEAD PLATFORM . DIVERTER SYSTEM Rig Substructure 16; Diverter Line Section View 16' Remote Operated Ball Valve F' ~-'~ 16' Dlverter Line Riser l..~ 29-112° 500 psi Flange Conductor STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS CHOKE LINE A..._I ALL VALVES IN FLOW PATH iRE 3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA Fi#up Line 16-3/4' 10,000 psi Doublegate Pipe Rems ~- ' Blind Rams · . Flow Line Hydril 16-3/4' 5000 pie Type GK Annular Kill Line .. Check Valve Gate Valve Gate Valve Gate Valve HCR Valve Choke Line Pipe Rams 16-3/4' lO,O00'psi Singlegete 16-314' 5000 psi Riser STEELHEAD pLATFORM Preventer Schematic J., Ball Valve Wellhead o ¢/,'4 '_.:.._ 0 , A A A A A A i 11 L __ - i i-- _ HUD I-- DESANDER - DESANDER --' IIUD _ CENTRIFUOE CENTRIFUGE CLEANER ' A CL£ANER PIT , PIT ~/ PIT PIT ; PIT~/; _ _ ~ PIT / 100 BAli 100 BAli Cap 113 BAli Cap ~/ 113 BAll Oep 10~ BAll CIp 0.99 BblI/M o.gg BAli/in ! 105 BAli ¢lp 1.11 BAit/in . ~,' RESERVE PIT ~ 1.11 BAll/in 1.0~. BAll/in I ; 1.03 Bbli/in o~ o · o ~ ,..,.,,.,,. ~.o ,o o- k)' ,"'-_- ~. ~ .... , .... ~ :r---~ h ' SUCTION PIT *2 ~ ~ SUCTION PIT ~ 1 320 BAll 320 Bbll CIp ~/ 3.05 BAli/in ~/ . 3.05 Bbll/in o , _ A A ~~ A A i .... MiX PIT PILL PIT ' 82 BAli Cap 80 BAll Cip 0.77 BAll/tn 0.75 BAli/in 0 0 0 0 MUD RETURN DITCH J EQUALIZE R AGITATOR MUD GUN STEELHEAD PLATFORM MUD PIT LAYOUT STEELHEAD PLATFORM BOP Schematic WELL'. -. FROM MUD PUMPS 3'' HYD. CHOKE m ADJUSTABLE CHOKE PRESS. SENSOR T CHOKE MANIFOLD DRILLFLOOR 3' TO MUD SEPARATOR 3' TO DERRICK VENT 3' TO SHALE SHAKER W LINE i HYDRIL TYPE GK 16 3/4'X 5000 PSI ~IPE RAM,( 3' KILL LINE Co FLEXIP HOSE 3" CHOKE LINE Co FLEXIP HOSE RAM RAM PREVENTOR8 ARE HYDRIL TYPE V 16 3/4' x 10,000 PSI 16 3/4'-5000'P81 RISER 16 3/4' - ~000 PSI CASING HEAD 30' DRIVE PIPE 20' CONDUCTOR 16' CONDUCTOR 13 ;3/8' SURFACE CASING ALASKA OIL AND GAS CONSERVATION COMMISSION May 20, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Gary S. Bush Regional Drilling Engineer Unocal P. O. Box 109247 Anchorage, Alaska 99519-0247 Re: Well No. Trading Bay Unit M-30 Unocal Permit No. 91-64 Sur. Loc 967'FNL, 520'FWL, Sec. 33, T9N, R13W, SM Btmhole Loc. 1806'FNL, 2272'FWL, Sec. 21, T9N, R13W, SM Dear Mr. Bush: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The mechanical integrity of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3) before operation. Please contact the commission at least 24 hours .before pressure testing so that a representative of the commission may witness the test. David W. Jol~ns~ton~ Chairm-~an . Alaska Oil an as Conservation Commisison BY ORDER OF THE COMMISSION dlf/Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA O,. AND GAS CONSERVATION CO,v,~VllSSION PERMIT TO DRILL I la. Type of work Drill ~ Redrill FqI Re-Entry [] Deepen []1 2. Name of Operator Unocal 20 AAC 25.005 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Service E~ Developement Gas [] Single Zone [] Multiple Zone (Marathon Sub-op.) 3. Address P.O. Box 109247 Anchorage, 99519-0247 4. Location of well at surface 967'FNL,520'FWL,Sec 33, T9N, R13W, S.M. At top of productive interval 000 ' F SL, 2000 ' FWL, S ec21, TgN, Ri 3W, S. M. @ 9080 ' TV: At total depth L806 ' FNL. 2272 ' I~WL. Se¢21, T9N, R13W 12. Distan;;e to nearest I 13. Distance to nearest well property line / feet ~-26 @ 1241 '-16 feet 8500 16. To be completed for deviated wells Kickoff depth 990'feet Maximum hole angle52.~ Specifications Weight ] Grade I Coupling 68 IK-55 I Butt 47# IN-80 I Butt 53.5#1N-80 lButt ILength 1382 2493 1705 7993 4887 2521 18. Casing program size Hole 22" Casing 26" 16" j 13-3/8"i 13-3/8" 9-5/8" 9-5/8" 5. Datum Elevation (DF or KB) 16'KB from MLLW feet 6. Property Designation ADL-17594 (BH) 7. Unit or property Name Trading Bay Unit 8. Well nu ,mber M-30 17-1/2" 17-1/2" 12-1/4" 12-1/4"i 9. Approximate spud date 9/1/91 10. Field and Pool McAurthur River Field Middle Kenai "G" and West Foreland Oil Pools. 11. Type Bond (see 20 AAC 25.025) Number 5194234 Amount $200,000 14. Number of acres in property 15. Proposed depth (MO and TVD) 5120 [5,215'ND 10,680'~ 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 4 7 2 0 psig At total depth (I'VD) 3 5 5 9 psig Setting Depth Top Bottom MD J TVDi MD TVD 70 I 7rtl !4_.._.5~.21 1450 I 2563 I 250o1 42681 3750 I 8063 I 6050 ¢oso · Quantity of cement (include stage data) Already set 1870 sx 3202 sx 3177 sx 485 sx 20. Attachments Filing fee Ii0 Property plat E~ BOP Sketch ~ Diverter Sketch ~ Drilling program E~ Drilling fluid program I~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify_ that the foregoing is true and correct to the best of my knowledge Signed ~.~_~. %, (~ ~ Title ~...e..7,~.~~ ~::~w~,.,~, (~ '-:~' . Commission Use ~ly Permit Number J APl number J Appr°va~a~n / I I Conditions of approval Samples required ~ Yes ~ No Mud log required ~ Yes Hydrogen sulfide measures g Yes ~-No Directional survey required ~ Yes Required working pressure for BOPE ' ~M; ~ 3M; ~ 5M; U 1OM; ~ 15M Other: ~ ~ / ~proved ~~~~~ Gommiss,oner Date JSee cover letter for other requirements /l~No [] No by order of the commission DRII~'~-'~tG AND COMPLETION PROGRAM MAr',. HON OIL COMPANY ALASKA REGION WELL: M-30 LEG: B-1 SLOT: 9 FIELD: AFE No.: TYPE: Trading Bay Unit, Steelhead Platform 8365-1 G-WF water injector REVISION NO.: 0 DATE: 4/23/91 SURFACE LOCATION: 967'FNL,520'FWL, Sec.33,T9N,R 13W, S.M. TARGETS: G-Zone: 2000'FSL, 2000' FWL, Sec 21, T9N, R13W @ 9080' TVD W. Foreland: 2235'FNL, 2193' FWL, Sec 21, T9N, R13W @ 10160' TVD BOTTOMHOLE LOCATION: KB ELEVATION: 160 ft. GL ELEVATION: 1806'FNL, 2272' FWL, Sec 21, T9N, R13W @ 10833' TVD FORMATION AC-1 A-1 B-1 C-1 D-1 E-1 G-1 Hemlock West Foreland TOTAL DEPTH TYPE SIZE CONDUCTOR: 26 ESTIMATED FORMATION TOPS: DEPTH(MD) 1655 2700 3412 4398 5009 8437 12982 13744 14481 15215 CASING PROGRAM 397 GRADE X-56 AUXI MARY: 16 75 K-55 POTENTIAL DEPTH(TVD) CONTENT SURFACE: 1650 gas/water 2620 gas/water 3200 gas/water 3830 gas/water 4205 gas/water 6310 gas/water 9100 oil/water 9610 oil/water 10170 oil/water: 10680 13.375 13.375 PRODUCTION: LINER: SET SET THREAD FROM TO 9.625 9.625 7.00 Dril-quip Surf BTC Surf BTC Surf BTC 2563' BTC Surf BTC 8063' BUTT'KC 12750' 61 K-55 K-55 47.0 53.5 N-80 N-80 29.0 L-80 Page1 1039' 1039'TVD 1452' 1450'TVD 2563' 4268' 3750'TVD 8063' 12950' 9080'TVD 15271' 10833'TVD HOLE SIZE in place 17-1/2" U/R to 22" 12-1/4" U/R to 17-1/2 12-1/4" 8-1/2" CASING DESIGN SETTING FRAC GRD FORM PRSS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP 26" 369# X-56 979' 12 420 500 16" 75.0# K~5 1450' 12.1 663 1077 13.375" 61.0# K~5 2500' 68.0# K~5 3750' >14.0 1797 1532 9.625" 47.0# N-80 6080' 54 N-80 9080' >14.0 4268 3223 7" 29# S-95 10833' n/a 4720 3559 DESIGN FACTORS TENS COLL BURST 12.6 1.48 3.23 4.7 1.32 1.24 14.7 1.11 2.08 2.9 1.3 1.3 9.1 1.3 1.8 2.3 24.6 31.7 DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, a 30" x 500 psi riser, and two 16" diverter lines each equipped with a 16" hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16" x 10000 psi outlet and a 3-1/16"x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1/16" 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 with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. Page 2 MUD PROGRAM DEPTH WEIGHT VISCOSITY WATER MUD TO ppg sec/qt LOSS TYPE 1450' 9.0-9.2 60-80 <30cc's Spud 4268' 9.2-9.4 40-50 <20cc's PHPA 15271' 9.4-9.8 40-50 < 10cc's PHPA Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30" series 300 MSS x 26" butt weld CASING HEAD: 30" 300 MSS x 21-1/4" 2000 psi FMC segmented clamp hub w/2" L.P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16" 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports Page3 CEMENTING PROGRAM AUXILIARY: 16"@ 1452' MD LEAD SLURRY' TLW w/ 2% CaCl2 + 5 lb/sack Gilsonite +.60% Halad 344 + .20%CFR-3 + 10%Microbond TOP OF CEMENT: SURFACE WEIGHT: 13.1 ppg. YIELD: 1.50 cu. ft./sk WATER REQ.: 7.06 gal/sk PUMPING TIME: 5+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME 1370 sx TAIL SLURRY: .2%CFR-3 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/.45% Halad 344 + 1.7% CaCI2 + .25% SuperCBL + 1240 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 4+ hrs:min 100 % 500 sx RUNNING 1. 2. 3. 4. 5. AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. Baker-lok float shoe. Fill pipe until circulating. Check float. M/U float collar. (Baker-lok top and bottom of float collar) Fill pipe until circulating. Run remaining casing (filling every joint) and land in the 30" MSS flange (install centralizers on jts. 1,2,4,6,8,10,12,14) 6. Rig up false rotary and run and space out stab-in cementing string. 7. Secure drill pipe and circulate while reciprocating casing. 8. Continue circulating until no gains in circulating efficiency is made. 9. With as little shut down as possible, begin pumping spacer. 10. Pump spacer as follows: 40 bbls 18% NaCl 20 bbls drill water 20 bbls Super Flush (increase if losing circulation) 20 bbls drill water 40 bbls 18% NaCI 12. Mix and pump 215 bbls of lead slurry (800 sx). 13. Mix and pump 102 bbls of tail slurry (500 sx). Reciprocate casing as long as possible. 14. Displace drillpipe. 15. Check float. 16. Pull seals out of float shoe. 17. Pull out of hole w/d.p. 18. WOC 12 hours holding 75 psi on annulus. 19. N/D diverter 20. N/U unihead and BOP stack. Page 4 CEMENTING PROGRAM SURFACE: 13-3/8"@ 4268' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME TLW w/ .6% Halad 344 + .35% HR-7 + 10% Microbond + .2% CFR-3 SURFACE 13.3 ppg. 1.42 cu. ff./sk 1.06 gal/sk 5+ hrs:min 50 % 2252 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/.3% Halad 344 + .35% SuperCBL + .2% HR-7 3500 ft. 15.8 ppg. 1.15 cu. ft./sk 5.0 gal/sk 3:10 hrs:min 50 % 950 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Pickup shoe joint. Baker-lok float shoe. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok top and bottom 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. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 447 bbls lead slurry. 10. Mix and pump 200 bbls of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 13-3/8" packoff. 14. WOC 12 hours holding pressure on annulus. 15. Test BOPE. Run intermediate wear bushing. Page 5 /~'~,EMENTING PROGRAM PRODUCTION: 9-5/8" @ 12950' MD LEAD SLURRY: TLW w/.3% Halad 344 + .35% Super CBL + .25% LWL+.2%CFR-3 TOP OF CEMENT: 4000 ft. WEIGHT: 13.2 ppg. YIELD: 1.32 cu. ft./sk WATER REQ.: 6.70 gal/sk PUMPING TIME: 5 hrs:min EXCESS (%): 45 % ESTIMATED VOLUME 2227 sx TAIL SLURRY: Premium cement w/.4% Halad 344 + .35% SuperCBL + .36% HR-5 TOP OF CEMENT: 8100 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5.0 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS (%): 45 % ESTIMATED VOLUME 950 sx 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 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. Pump spacer as follows: 40 bbls 18% NaCl 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 545 bbls. lead slurry. 10. Mix and pump 389 bbls. of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 10-3/4" packoff. 14. WOC 12 hours. 15. Test BOPE. Page 6 ,'"-'~',EMENTING PROGRAM LINER: 7" @ 12750'-15271' LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/.4% Gas Stop + .25% SuperCBL + .12% LWL + .2% CFR-3 12450 ft. 15,8 ppg. 1.18 cu. ft./sk 5.0 gal/sk 4:00 hrs:min 45 % over caliper volume + 300' over TOL 485 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. M/U float collar. (Baker-lok all connections below top of float collar) Fill pipe until circulating. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. M/U swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 126 bbls slurry. Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. Page 7 DESC .JIRECTIONAL PLAN MD TVD INCL NORTH AZIM COORD EAST COORD VERT SECTION RKB 0 0 0 0 0 TIE-IN & KICKOFF END OF BUILD 992 992 1.2 Build @ 1.75 deg/100ft. 3949 3555 52.1 N60.6W 11 N10.5E 1260 -7 192 10 1274 START OF DROP END OF DROP 12950 9080 52.1 Drop @ 1.00 deg/100 ft. 15162 10738 30.0 N10.5E 8247 N10.5E 9667 1480 1742 8378 9823 TOTAL DEPTH 15271 10833 30.0 N10.5E 9720 1752 9877 POTENTIAL INTERFERENCE: WELL G-12RD2 G-31 G-1 M-13 M-19 M-15 M-14 M-27 M-29 M-26 M-28 M-25 M-1 M-2 M-4 M-3 M-5 RLF-1 DEPTH (MD) DISTANCE (ff.) 3635 135 6548 293 6809 194 990 137 990 121 990 154 990 114 990 42 99O 33 1241 16 990 39 99O 22 1140 108 990 140 990 114 99O 131 99O 113 1594 28 Note: Close approach to Relief well #1 is across a portion of the relief well that was not cased and was abandoned with a balanced cement plug, and therefore presents no true interference problems. CONDUCTOR: AUXILIARY: SURFACE: LOGGING PROGRAM No logging is planned for this interval. No logging is planned for this interval. No logging is planned for this interval. PRODUCTION: GR/SP/Cal/DIL/LSS from 12950'-4268 '. FDC/CNL/Cal/GR from 12950'-4268'. Four arm caliper for cement volumes across open hole. LINER: GR/SP/Cal/DIL/LSS from 15271 '-12950'. FDC/CNL/Cal/GR from 15271'-12950'. Four arm caliper for cement volumes across open hole. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to per~p;~r~l. DRILLING PROGRAM CONDUCTOR: to 500 psi. 26" casing in place. Weld starting flange to 26" casing. N/u diverter and test AUXILIARY: Drill a 17-1/2" hole to 1452' RKB per the directional program. Underream hole to 22" from 975' to 1452'. Pull wear bushing. Run and cement 16" auxiliary casing. WOC. Back out and L/D landing joint. N/D diverter and install FMC Unihead w/16" pack-off and test void to 700 psi. N/U bope and test to 2000 psi. Set Unihead wear bushing. Test 16" auxiliary casing to 1850 psi. SURFACE: Drill float equipment and 10' of new formation w/14-3/4" bit. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4" hole from 1452' to 4268' per the directional program. Underream the 12-1/4" hole to 17-1/2" from 1452' to 4268'. Pull wear bushing. Run and cement 13-3/8" casing. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Set wear bushing. Test 13-3/8" surface casing to 2150 psi. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-1/4" hole from 4268' to 12950' per the directional program. Log. Pull wear bushing. Run and cement 9-5/8" casing. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 4000 psi, Test production casing to 4000 psi. Set wear bushing. LINER: Drill float equipment and 10' of new formation. Run leak off teSt. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 8-1/2" hole from 12950' to 15271' per the directional program. Log. Run and cement 7" liner. Clean out to liner top and test lap to 4000 psi. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Completion procedure to follow. 5~'.vo~'-- ~i.5 ~'~ ~q~ /~,~/~c.~ / ~ ~ CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. 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I ~ ~ I I I ~ I i 5000 I ~ I ' I ~ I I I ~ I . ~so 800 850 900 950 1000 1050 llO0 0 4000 --I--- ~. I M MARATHON Location: Trading nay, Cook Inlet, AlaskaI $1ructure: ST££LHEAD Platform Fleld: Mc. Arthur River Field -,,-... East -- > 800 0 800 I ~00244X) TD LOCARON; 1806' FNI., 2272' SEC. 21, TgN, R1.3W N 10 DEC 11 MINE 9877' (TO TO) wEST FORELAND LOCATION-'] 2235' FNI., 2195' FWL SEC. 21. TgN. R15W G ZONE LOCA~0N; 2000' F~L 2000' F'WL SEC. 21, TgNr R13W RK8 [LE'VA~ON:'160' KOP ~0-992 TMD,-992 DEP,-IO 16"CSG PT ~0--I~50 TM0~,14,52 OEP-45 1.75 DEG/IO0' DOGLEG EOC T¥0-3555 TM0--3949 0EP-1274 1.,3 5/8"CSG PT TV0-5750 TMD-4268 OEP-1525 AVERA(;E ANGLE 52 DE(; 8 MIN SURFACE LOCATION: 1 967' FNL, 520' FWt.~ SEC. ..33. 'rgN. 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(.~ I U S, P ,i ,:J ! LI S. r-a.d f u s. red i u s. P e. d 1 U !:;. r.a.d i us ,, r. a d i u s. r. a. d i u s. r'. a. d z us. F' ~ (J 1 LIS, r' (~. d I U S, Peal i U f;- ,, r',Id i LIS. pad ~ Lis. Pad i u s, t"a.d i LIS, r-a.d ~ us. r-ecl i LIS. r" a. cli u s. r" 6i. (:l ]. U S t"~:J I US F',~ (J I U r',!Tt,J 1 U S I'" & C] ! U S l"&,~ ! t_IS I'" 8.. C} ! U S r-a.d I :Is F'8. d ]. U .2:- r' ~. CJ 'I. U S l"&d i Li S t'- a. cj I id S. r-;Id '.L ij F' ,-~ ('! ILI ':.'; I"',~.~J ILI ~-'. ERSTMRN CHRISTENSEN D ..... ! ! F_i-.,.7 RB D .... .:.:' t:;.'.D D .... 19RD D--'-42 i ":'"::' D'--44 ? 2'~ Z -'.,';:~ l:;~p F.,~ .... 15R D 2 D-' 3 R 0:2 D ...... i 3 D-8 R D D--' 6 R D 0'-' i 0 K-'2,.'.i. RLF--i ?? ~I~ EFISTMFIN ~/~//~ u CHRISTENSEN 092 ,, :32 i 092 ,, C,O 1:3,., :!?:3 N :!.3 ,., 5:3 W I 0'!:':'2 ,., C,,:) .I. 0':.';'2 ,, O0 65:' ,,, i '7 E; SE:,., 1.4. F- ':',"" ,'";0 2 C, 08 N 8 E:,:::, N I .t. ':::'"::' C',,:':, :i. i 92 O0 ,'- '::' 1 7 S 88 14 ~:::' 192 '=:i .t. 1 .,:: ............................... _ 292 ':'" ''''~ '-"':' ...,. i~ 'q:'"~...- .... 29 ,, 65 ..i"d. 8 ,, .~4.. . W ic':::'c:. ,, Or)_.... I':,'::',':,.,~ ..- .,: ..... 00 /,9, '~,. '";. S 88 i4 E 39:3 ,, 83 ! :3'i;' 2,0 C, 42 ,, 67 t'"..I 4':-.':' !5.21 ! 4'P 2,, 00 59 :, 2 2 N 597,25 1 '.55:: 2,, C,O 79,, '::i: 4 N 70,:::,. i C:, t 692. C, 0 i 0:3.., ! 2 N 803 ,, 92 i '792.. C, 0 :t. :3,:7.:, ,, 65 N '?00 ,: 87 1 ::_'-; 'P ::.i: ,, 0()t 6::::: ,, C, 5 hi :,:.} ! 5 ,. 1:3 '! 'P92: ,, OC, 197,, 46 N 12:2 ,, '? 1 2 O':T-' 2 ,, ,:} 0 2:3 7 ,, ,:.'.':, :.--:: i"-.l ~ 2 :'q 2 :: 4....I- 21 92 ,, ,:::,C, :;;it:.':.! 0,, 97 N ::3 4:3 ,, 5:" '7 225" '2,, 0,:::, :325:',, .50 iq :3. C:, ,, '::'.. ,"..,_ E: ..,:."':, ..'I 8'!:"; ,, 76 217. '..';.'. ,, :34 .:'"" "::'.._.,. ,, 62 S i f:_ 5 ,74 E 40 ,, 06 r." ................ 225:' 0 ,, :3:3 2274 ,, '7 C:, "::":'-.l 24 S ':::' ! '=',. '::..'.. 1 E : F:' () 0 4 4 8 ,, Si: N ft'.--., D i .~. t a n c e. D :1 r-e c t i o B'::~' ¢',- b..:,.-: .;';:' R~" ' B.8 i[: Ld-::-:., .~.,' Nel !s W,.et ls 124 ,, 32 '.'-"; 4 12 '7.41 S49 2]:E 1:31, '7'7 'Z.:4'7 ';.i: 2 :t. 38,24 :.,'.-ii 4..q..,.__.."" ..,,:."" c. :3 5 2.6 2 S :2 6 :3 E :3 'P 6,. :3 i ._' :' ._"-'/-_, :-2 2 ti:' ERSTMRN CHRISTENSEN D i s t e. r'~ ,:: e D i r e c t i Be t ~.,.)..?: .:~, n '_(.!:.,' ..=a, t~.~e .:~. n We 1 I ~_.'. !/.Je i '! s ~::17. ,.":.~ 3 W 373. 8/.'::, S ! 3 3'7 W i :~z~ ERSTMRN ~~ CHRISTENSEN CAL. CUL. AT!ON OF' LEAST DISTANCE. BETWEEN WELLS Pos;i.'~ior', or~ tdell .~-M-.30 C!c,s<::,st ~ositi,::,r, on u.~e11 't" v ¥"~ N ~:..~ F!,.i j"i D T: .' Fl l",i S JEW ~ 803 ~ 92 ! '7':T-' 2 = 00 · 908., ::37 105:' 2 ,, 00 !: 0 :I. 5 ,: 1:3 .I. 9'!i:'2 ,. 0 0 :.' :[ 2 2 .~ '.::' i 2,:.':,'i..? 2 ,: 0 0 2 :-".!: ,.'::) = 9 7 N :3 0 ,, '!:.:' 6 E 2191., 91 2 :i. 4. 5,0 4, i '7 8, 6'7 N 2 5 E: ,, :3'7 E 329.50 i',f 4-0.06 E 2295~65 22:37. i2 211.i6 N 2 5:' :3 . :3 :::: E 3 :E: 2, 8 S-'-' N !=:i_ 0 , ~:..":'/-_, E 9~....a., 0_. ,:'::.., 0 0 2 ::.-i: 2 7 , S' fl. 2 4 6 ,, 2'7 N. :--: :2, 0 ,, 8 8 E 4 4 i, 4 8 i",.t 6 :t.. 6 6 r..: 2 5 0 3,, 16 7:!: 4 i 5. '7 7 :.7: 8:3, :3 9 l',l ::'3 70. 2 7.' E D i s t a n ,:: e D i r'-e c t i ,: 1.3 e .1:: t:.~.::..? .::.:: r'~ B e t u.~.::.:.-- ,..':.~ n Wei'!xs Wells '::.'6. :,.-.:'.8 S 6 8:30 E i12.7'7 $68 4 8E ]. 3 ! ~ 1:3 S 6:3~_=.q..,'. :! ::' 1:5 i 4::::: '::'/'' '::~ 'L7<' 17:3 '-'=' ,:::,...., :.'".'!; 6,'7 ':":" 1 E i 9 8 ,, 2 9 'S 6'7 14 E 224 ,, '?0 $66:3:3 E: ERSTMRN CHRISTENSEN P.!D T'V D N'.:2; EW 597 ,, 25 .1. 592 ,, 0 () 79:, 34 N '7 C:, o, ! C, i ~:, 92 ,, 0,.':) .1. ():B ,, ! 2 N 5,, '74. W 1490,, 64 148:3.7! .... c:, i 4 Icj I ,=i,.-..,r', 86 .1. !::'i ::::: o ,:"x3 "'"'":' , z..,::. .................... : ..... 87 N 81 '-"-' E ,, , /,. -'~'~---, . ~'i 0,31 E t `1,91 a.l 1,_,, .... :3`1, i1! ..... :, N :: ........ 4, ~' i E I v':::' ? :B:-EI i '~'''' '::' 6 () i 44. 27 N ]. 10 '7c:, ~:::' · ~ ~ ..., m,, tJ ! ~..~ .~ :~ , '::-.: 7 8c.' i :::::':'? '~:' 9 i i :r., ~..":, I -"'-' , c,c.,.:._ 6L:!: I 8 i 0~ N :27 , .:, E 15,87 E '! 99,'!,, 13 1954,4 9 2 :;;?. !. 94 N 1 zt. ,/_..,, 31 lei: 22 ,, 92 E 2 .... ,:-:, ,T,' 9 ,, .2 o.. ~=..":' o., ..,.:~ x~.. ,, ,::,, ,_,.,.. 266 :01:5 ,, 1 :B 1992.0,:} i 9'7,4. 6 N .1. 22: ,, 9 ! 2,::~ 9' 2 ,, 0 (}, 2:37 :,, 0 :'3 N : 457 ,, 8 (_':, 2 :B 92 ,, 00 3 82.8'!'.',' t"...1 ......, Fi ?' zf. ,, 27 24 '::-/13 ,, 0 0 4- 4- t ,, a,, ..,:' hl ...$,. 200 ~ c:, o 21 :B 1 i c:, 3 t. 4,7"'ff N t 8'7', 4, 9 E .... · --',;...:,'---' cj ...... ..:,'. 4.. 2_ '.';:: 2 ! 7 , t 4 3 ,!, 7 .47 t',1. .,_'--" .1. 0 ,.. ,'.t.. 4. E ....... :'":"':~ ./,9 E 241 I 0,'!, "::' :':: 0 :':: / :::: 4. 2-'.'.::., I ! N ,=..-.:,-- 2524 , ;t..4. ,:.'s"-":':r."--"._ ...,_, ..'?'--'..,,._ 490 ,79. . I",1 263,:33 tF :.2: ,, 77 2592.00 505"i~ 65 I',.i 6 78 2`1,9':2 ,.".~,.'-', ~'= .... '-- ':".-.-' N 3, ::_:: 9 2792 ~ OC:, ,/.-:.F:i 2., 7,'!. N :075 ,, :30 28'::72!: ~, '00 7:3'7 ,, 02 i',l i..i_ .-"!, :3 ,, ! 5 :B .':"';'-'," 2.0.':]:, i 554., 9',-B N Re .F = POO4&9', .,';~ HA D i s t' :;i r, c e D i r-e c t i :: B e t' w e e n El e t' c,.~ e e n ui.::, 1 I ~ Mc.' i t 74,96 S89 13E '::'"::i 28 N8'7 ...."- 96, '71 N 84 f=;'!!!: ~= 109, 29 N 82 :'-'. ' ':. .1.12:3 ,, 02 h.180 !=; I E 1 ":'w ':;' 1 1"'i7':::~ "':'"::'F 15:3.98 N78 i2E !71,29 N'77 49E I 8'iF.', 94 N'7'7:26 lie 2 09,8 4 N 7 6 5:7..:E 230, :"::0 h176 i 6 lie :B 4 2:. ':'... 7 S 7:3..,,..~. I E :B 6 4, 5 2_' S,i. 8 :.3 5 iE :3 9 0.2 C:, S 6.4 :.:: E ERSTMRN CHRISTENSEN ........................................................................................................................................................................................................................................................................................................................................... E':a, t ~"! ..... ¥' 'T'V t] N S E W M D T V ,_~'~ N.,._':; E W W .e I 393 ,, 8:"3 1392~ ()0 4.:.:..:' 5 ,, 21 i 4-92.00 5'!;' 7 ,, 25 1. 592,, 00 70 o ,, 10 i 4':..? 2 ,, 00 t ;in c e ,...q i r'. e c t i ,: Ld '.i:; ,.'i:: r'~ B .~: '~ t~ e ~:: R I s W,-.., l I s 5 0 S C', 2 3 E /.~=. ,._, ::_:; :}':.: . .':, ,:::, r:.' S-',:] S :3 2'7 E 44 .'.E; 2 28E -':..).'::.t. S '7 '7 W :3 4 :.:i; '7:3 6 W ERSTMRN CHRISTENSEN M D "i." V D 14.:::, E W 15'.,~.. '":' ,, 5 .1. .1 ........ ]. 92 ',:".~ 0 ';:' 0 ,, ()8 N 8 80 W 2':.::' 2 ,, ':.';: 7 i 2':.":' 2 ,, 00 2'.'T,', 65 N 8,, 54 W · ::, !,,28 E '.::; .i.:]:':,,56 E '.3 :,.70. '70 E ':'...., :B2,, 'ipzt.t:::'_ N '72 ,, 67 E lq 100,, 0'7 E 80:3 ,, 92 1792,, C,() 1. 30,, 65 N 4. ,, 61 E 90 S ~, 8'7 .I. S'!.::.' 2,, 00 ~ 6 :;2:., ,::)!5 N '!;:.' ,, '78 E C, i 5 ,, i 3 15:' 9 :;2.,, C, 0 i '.:;' 7,4,:!:, lq 15 ,, ::'-:'7 E 122'..., ':T,, I :;::: 0':..--' 2.'..: ~, 0 C, 2 :.37 ,, 03 N 22 ,, 9' :;2: E Re .i:: : PO,:L':,7:':.'u4,. 2P!A 58,56 S18 44E 7:3,98 Si:3 iSE 'F'2,84 S i 0 22E I i .':t...,.i..4.. S i 0 i!;:::;~."'_-~ 16 6.2 (") ..... S i 4 /-, ,_. = i 'i;:'7. ! 0 '.:!; ! 6 45E:' 2:3 i ,, 9 i S i '.'-.'~ 26 E ERSTMRN CHRISTENSEN L..A~_L.t,..,I..,..1, ~Ot"'.I f};:':'": ~'"'"" BFZTWi::ZEN WEL. LS ,- .., :s. i t' i ,:, n .,:, n :~.e 'I I -~;.~ M--:i': () r- 1 o s .e s ',~. F-* o s :i. t ± o ri o ri w e ] i M ..... ~.'~ 3 M D T V iD N S E:' W ,~'q._, P .... t ' v ' D ' NS ..... r..:' 1:3 7,, 7 ,:"} S 3 9 x.'-' '"",- w' 15;;:.:.', i 9 .'..'~;4 0 5 0 W ! '7:3,6 8 :::!; 4 2 9 W 2 C, i. Iii; 1 S 4 2 5:;3 W ERSTMRN CHRISTENSEN B E. T W E E N W l!~: I.. L. :iS; P ,::, s .i. t i o n c, r,L,.~,..'-: i I '¢~' N -' :B 0 M D T' ' '] · v ):. N S E W 9 .. t ' ,..t ,",se';."-. F',:,sitzon on ~z.~el ] M-26 M D "' ~' - I'..I :-5; r,.. 0 992 ,. 2'7 99 :;!:~ 00 1. !: 25 i'....i 6.6'7 w 092: ,~ 32 1092, oo i :B, 83 !.,1 8,, 5:3 w :i. 92 ,, 5 :!. t ! 92 = oo 2c',,, ()8 lq r-i:~ 80 w 29 :;2:. '..:.'."7 .I. 25".'.?.. 00 29.. 8 !5 N 8.54 W :I. 05'"2 4.5 'I r',99 40 :3 '- ':= N "" 4.6 :I. I. 9'.B~ 1 :l. .I. :I. 92,8'7 9, 15 N 3..I. 6 E 1293,89 t293,!5 ! 8, 97 N 4.22 E :ii:O:::: ,, 9 2 :t. 79 2,0 0 I :B C:,, ,'.'.:,5 N 4 ,, 61 E '.";'08 ,, 87 1892.00 162., C::5 N 9, 7:3 E :,:]) 15 ,, 1. 3 1 'ii:..'92,0 C, 1 ':7.,'7., 46 N !. !:.:.:.; ,, 8'7 E : 12:2 ,, 91 2092,00 2:B 7, 0:3 N 2.'.':2 ,, 92 · . .... u ~ .... . o.,, t. 190=il-" ,, 4. 81894, 0 ! 2015.,99 1996,48 ;.212:3 '-' '~ , .,:: d 2099,2:8 :2:B:,7' ,, 4. 4 219 2 = o 0 '.:B 4:3 5' 7 ""'""'-'"'" ,.":, ,, ,~A .:£. ::.' .~, ,, .. -~ '. 45'7 ,, 80 2 :B 92,00 :5'74., 27 24'ir: 2, 00 2:3 O. 'P 7 N B,:}, 96 E 2:2:32 ,, 72 220:B, 'F.' 5 :32'-7,5 0 N 4.,:') r:,,/-, p '-"-" ~':: :7 C) ............ c .~: ;::,._, .... 2:2:34. '? S :.5:02 ,, :ii!: 9 I'..1 50. 26 E 2. 265. :.5:0:22:3 fi.. 98 44..I ,, 4 :::: N A :1. ,, /._, ,_,z. ,c. .... ,::'..,'::' ..../:. ..., = , :30 22: :7.': 4., ':T,' =!5= :ii; 07 C:,7:ii:. I M A .,.q .... i s t a n c ..:-::,D i r-e c :. i ,: B e t u.~ e e r': B e t u.~ e e n b" I . J:;.: l s W e i t '.', I 0:}.':. 54 S t. :B 27ti:: 20 .'"~:, 'F' :1. S 4 '7ii..'..: :B2:3 '-' '=' . .,~ ..... :.5; ,:') :;:?&W ..... . '=; 60 !o E ]"fi. 5 4._ lq = 24.5= 45 N ,'"-,~-':~. 16 E · -=' I;,.~ ~,.'.4..:,. 4 !5 N ,'.":,0~ :. 6 E HRISTENSEN B .e t" u.~ .:a ..?: r': B e .t-.- u_~ ,e e r'~ W,.i:: ] ] :~. We I 'i..:,..~ 81, ()3 :.:.';7'7 2 7'E :i. 7'7, ! i :3'74. i :t E 5276,01 S65 36E · :,'""-'~ ,....., ':=, 7 6 S 5 . 4 7 E ERSTMRN CHRISTENSEN N'O '!"V D N S E N N D T V C1 iii S ~:'-', W R.e .~::: -: S078 ], 5. :F.::!'SA [) i s ','.' a n c e D i r- e c 'i'.' i ,::~ i.:':: e ~'~,. ~,.~.: ..... .::.: r, Be t toe .e n W c: t '! s !.,,.J e 1 t s HRISTENSEN .8 E'F W E E N I;.~ E:: L. L'S D i s t ~ n ,: e D i ~--e c t i ,: We I ! s W,,? t 't s 1ERSTMRN CHRISTENSEN MD TVD { .... ;~ .::,-' {.ZW °92,27 992 ,:'.,,::') i ! ..' . n ... . ..... ~ · · 092, L--:2 'i ,:}92 ~ CpO i. 3 ~ 83 N 8 ~ ~3 W I ?.';ii'. ,, 51 i 192,0 () ii'. O. <'.',8 N 8.80 W 2'ir-' 2 ,, 97i ;:;ilgll..'.,, C:,O 2 42,,67 N 7',, 5 3 W 5'.":>, :2:2 N 5.74. W 79~34 N 3. !4 W t O:Z': ,, 12 i",i 0. :B i EZ .I. :30 ,, 6:5 hi 4 ,, ,-'_.., i Er ! 62 ,, 05 i:,} 9, 78 E.': i 'ii:"7 ,, 4 <S N 15 ,, 87 E :':? :37 ,:",~ :':: N 22, ':::'":' ~ 7. $7 '7:, 94. 7.83 ::7....:32: ,, 4. 4 2:192 ,, 00 ::3,.':t, :3 ,, ':T.' 7 2 :;2:'P 2.'!:. 00 : 4. 5'7 ,, ',::,"', 2 :':.' ':::' 7:: ,, 0,:") 8, i 4 '7,9 '7 7, '7:-"!: 5.0C} E. 4, 'P/z, E .I. :3 E Dis Bet W e t ";:.' !. 31. ,':,i-O, · =..'i;2. 8'7, 'j. ":) i '7'c). .'"t ". 1::7 ..-. (.) ._, ,, 245,; S 0'7 9 91, E: !"."i A ~'..~ n c e D :i. r'-e ,- t i o ii.f:':-' .a' F~B.:::: 'L' L0~:: .:i:: r'i I s We 't l s 9 7 S:3:3 4. i E 74. S :ii: :! .... -:, c. '70 S :2 6 3 :!'.: E 25 S20 ! :2 E % 11ERSTMRN CHRISTENSEN B E T W E!: E N W E L..L S .H D T V D N S r:-. i-~v.~' Closes'~: Pc:sition on u..~e'll MD TVD NS EW '.'? 92 '-'-:''--:,':::,::::' ,".~,:") 'I i ":"=': N 6 6'7 W 092,,:B2 1092,,00 i3.8:B N 8.5:B W ! 92~5i i 192.00 20,08 N 8.80 W 292 ,.:,'7 i""'"'" O0 29 ,"~,~-] N 8 54 W 9!9.3() 9 ! 9.03 8.00 S 7.92 W 919.30 91 '..::'. 0:::.; 8,00 S 7.92 W 9 ! '.'-.:' ,, :BO 9 ! 9.03 ::.'::. 0C:, ::::; 7.92 W c., :I '.:" 30 '::~ '~ 9 ,, 03 8 00 S 7.9:2 W ., . .-' :~ . .: . ,a . Re.F : S07:B77.SMA -7 m 4.'7 S .'.7.: .'..~ ":' ~,~ t ',,.' t,~ ~ .t,,... i74.:]::4 S I :B6E: 2'7.4.4 ! S i 4.::'.::E: :B'74.86 S 0 57E ERSTMRN CHRISTENSEN ......... Ei.r.i.:Z, , DTSTANC:E C A L C U L A T ]'-i"'iFJ Ci F: i "" '-'"" _ B E ]" W E EZ N W E L L S M D T V D N :'.'J'i; E: W :"i_,.. T'V D N S EW :[92,,5! 1.1.9i?.,00 20, 08 N 8,,80 W .::, c.,-.;, 9'7 ]. 2'? 2 ()() ";;'9 /- ~ iq :B. 54. 4. '!.-".' 5 ,: 2 ! 14. ':'::: 2 ,, ()0 !::.:;'.::.';' ,, 22 N 5,, '74. W 597,, .,:..":":q.... :i. !:::; 9';::' .00 79 ,, :34 N 3 ,, i 4 W Dis Be t Wei 14.0, i !59 ,, 222, ..I:-_ a r, c e D i re c t i ,::, ~zJ ~:: e r'~ B ,8: t' Ld .:f: ,;2, r"~ is. W,..::: t 1.s 9 0 ::ii; 4 0 ,::.._ E. 5 6 '.!:; 3'7 5 2: 4. I S 3 q. '7 E :;21 S:]:O :35 E: 2 66.4. I S 2 7 .,._ .,9 o E · .:, I ':::'.., 4. 0 :E; 24....' ....... :, .,::.' ,:r.. .... :B 7 9, ""::, ':::'..,'.:; 2 :;?. 1:3 E ERSTMRN CHRISTENSEN :""~'~ :'"~'"~ 'x"rl OF L. EAST SiSTANCE B ii:.-'. T !,...i E E N W E: L L'."-'; R e 'F : S0677! ~ F.:I~iA M p_, 'r,.. ~,_.' F N S E W C.];n_sest ,,:-*osition on ue]]. ,~"-, ..... ! ST .i$1 · " q T V D I'-I,.. NS EW D i s t,a n ,::: e D .i. r'-e c t i ,: ..F.-J e 'f'.: L,Je e r~ Be ,4:. k.~:..': e n !..,lc ] ] .s t,.,~e ] '! s ]. '.'...~9,, 8-Q S5:..:.: 9'E 108.., 45 S 6!5:3!5 E .1 07,, ':::' 2 S 74 DE j..,.-~ n._.. ,::,.. ,_,,:::, S 83,.:l.' '-";, c.'- 2u 0,, '.-7.,7 I',1 :'3 (),, '.";' 6 3:2'.';:' ,, 50 N 4. O. 06 :3 8 2.8':';: N .':'5'.'}, 26 441., 48 N 6 :t. ~, 66 268.21 N 4:3 4,:":, E; 27:3.68 N 4:3 '7 E 27'7.//:,7 Nfl. 2 !50Ei; 280, 2:'-'!: i',142:3'!..'/E 50Sl, 6 5 N 7,..'i., 3 3: · "2- '7 ~-' . .~,, .:,. :'3 8 i\i 8 8.3 8 /_-.5 2.7 6 1"4 I 0:--.:, ':7.:5 7:37, o 2 N 121 ,, 2:2 · c:: 0:3,, :34. :3 4'? :,-3 ,. 00 i~ '[ 68 i % "::-" ~':''' ''-' 00 · ,: -. -.)-..' .-' .::Z ,, .:332:, ';':.'6:36'?2_. 0,:} :2".-:." 8, 72 N 2 :!':'F.'~ 64 426.85 N 266, '7.'4 554-. 'F' 8 N '::.!'.-'!;-' 4-,, 24 6 :.2: :2:, 12 t"...i :2:ii: i, !5:2.: 7 1ERSTMRN CHRISTENSEN .Fi'..:.:.:: 'F = ::; 0 ;5:,'7 7 2.8N A ~*'~ q T V D N S E W .M II ]' v. D N S u.w~'-I ' D i s t a n c e D :L r'.e c t i o Be t u.~ee r'~ Bet,,,.aen We 1 ! s We I I s ,:::, c,-.::, .::,7 9':.?'..';' 0,:} 1 i .,: .... N /- o / W ,:} 92, :2::2 1 C, 5' 2, ()0 i :3, 8:3 N :E:,, 5:2W 192,,!'"'5! 1 192.00 2().08 N $~80 W 292 ;, '.:.';'7 1292. ,:30 2'T/,, 65 N 8 ,, 54 W 99'7.71 '? 9,'!,, 97 46.62 S 86.5 .1. El; .1. ()'P 8,59 1 ,:} 96,54 :3 t'), 9 ~-"i S 5:' 0, ! 4 [.,-_. 1 i. 9'7 '71. I 1. 5?:"3 t 7 ,::, =;":, ,::' ,:',/,. ,:','z E , , -- .. , ._ ~....J ..* *% ~ ..* .. 1:25) :.-.5, '77! 2::2: 7. ! ,3 ! 7. '71 N i O 1.70 E ! ,:} 9.8 () S5::2: 'i;'E i O:..-.:..'..I-5 S/_., 5:3 :.[5 lie ! ,:} 7, 9 'T:: S 74. ._5l [.::.'" I .1. ,:}. 98 S ::..':: :3,4.' ":'::. ,::.'"" f-] 9 7 .-:,,r< · r,~c.,.**-, C) 0 , ~.....~ J.....i- =::. ~ . 700,, i0 I692:.00 :,:-* ! 5 ,, 1:3 1 'i:? 92, 0 o 122 ,, '--'....i. 2' 05:.' 2, 00 13':72 .-:,z '~ :'::77 ~'i'v F:;,:") :32 N IO'F' ":":' E 14. 89 ,, :3,:} ! 4 &, 6,45:' 88, 2,:} N .1. 17, 8'7 E 1585 ,, 29 !. !:.fi51.8'2 131, .1. 4 N .I. 2'7, i .1. E '"'fi'::' 1:37 '74 i/'. ?-"' 18 .1. 6 :'::,:} "--'/'. 1 '7 & ......... N 1768 ~, 69 .1. 707, 44 ":'"':' =: . .,:...., ........ 33 N 14. 9, '7 a, E t 8,56,, 7 !5 .1. 7 8 8.0 2 :2 7 9.7.':5 N ! 6 2. :32 E ,., ~::'~ '9 :u:i 0 Z , i 'i;"7:2::, LEt 2.1. ,:,, .......... :3 ::ii:'8.42 lq i 75, ,:") 4 E :;-20 ::2: 8,0,:} i '.:;' 7:2::, 1:3 :398, I 1 N I :':'!: 7. '7,:} E 2 8,:}. 9 7 N 3,:}, 9,".!.., E :325:',?.;0 N .4,:},, ,:}6 E 382 ':::":" N F:;O '>/.'-, E , ~...~ ." .. u .t ...... 44 J. ,, 4:3 N /.':, i ,, 66 E :;:-:'::2: I, 27 N4.:2 4.6E 2:3,:}, 8:2 iq 4. :3 :3 E · '::, 7-',' .1. ! N a. :':~ I 4. E 2,'2, 7,, 48 N 4:3:2:: E': E '2 5 0.5' 2 hi 4..,.'i 225.7'P N47 19:3.2.7 Ix!5 ! .!. 2 E i 5/.,._ ..., =._, = N &,,:) ~15 F- 'I :---: ! 'i . '-'~' ......... ~-.., N :7-.:4-:'7.': 8:!: E I ':.-.-: :3':7-': :2::5: N :2:: 7 &,., '! :2 E 2 067, 5 ]. N ,i C:,.-_-:, 4-;5: E 2 :[ 5' 5 ,, 6; :5 N 4:2:',,:},, 7 ]. E a ':,-~ ~' ,/', 0 ::: :'-:;.'5';:' ::: 0 ]. ,/_", 6 0 2 2 N 'T ._1 .." ..- u ....... = - .. . '~ =' "-" '-'" 2'F" :]: '.T,' :E: I :3:-':iv,:`..-.` 24 ;".! IL':' · '..i. 6;:2::.-2': ~ ~ ~- 1 't :", ~ 1:3:2:7 76 N = .,"-.., , _ ...-, .i.._t 4:3,'..!- d, ........... :7,'",-,'.i. :-24,:} 4. :: .i. '.-'-' ~'."/-, e,.:,' ERSTMRN CHRISTENSEN '782 ,, 88 ,'.'.::,392.00 747,, 69' 647:2. O0 ,::-';,:::;.-,'7 09 i 1i:.B, !0 E i 14.,.'), :B9 F: F;'..:.? 'F : F; 07022.7 I'"'! A 'q i s i:: a. n ,::: er'i :i. r'- e c '~ i o T-:{ e f.: t,,J e e r '~ .Y:'.¢ e t' ~.¢ .::e .e r'~ t,.)e 1 '~ s W.:-., 1 I 3 :B9.0:3 N 22 i. 6 W 2i6.46 N26 lrSW 98 ,, '72 N 4,:") 4 OW 6 0.9 3 S 2:3 :;? 9 W ERSTMRN CHRISTENSEN BETWEE:N WELL. S P o ~.~ .i. t .i. o n ,:, n o.' e 1 t .~. M-:]: 0 4534 ,, 54 3:334.89 4556,, ':.:.:4:3:34.9.84 45 E,'!;'. 7' 2 3:2, 58.24 458 .t.. 42:336 5.9:3 Fle-F : S06'700,,7MA D i s t,'..~, n c e D i r'.e c t i ,'- B e t ~.,J e e r, B e t u.~ e e n Wel ! s Wel I s 32'!;'. 4 ';i'. N56 252.32 S 89 ,.':i. t W 9 ¢:. -:, ('):':,, c. ~::;,, 2 :.7 3 5 9. 16 :::];41 3 6 W ERSTMRN CHRISTENSEN ......... , . 97 :B,2, 92. ,:":, 0 I=:' ,, .".: :::) ..';, ,_, .: ! OC.,. ! C,O 673,71 3292.00 E:::38, 5'.':?. :3 :B 9:2. ,, 0. 0 9:31,74. N ! ()4-5.05 N t170 =:::" N .,::. ::' :::, ,, 72 N a. 6i.'74. E I85.6,5 E 212. :B5 E: 2:3:::.". 64 E .I.r',='= Ac:' N '-"-' C,'7 W ...~ ....t ,...t u .. ,. ,g:, '.;'.: ~ · I04:3.97 N 11.20 W ! O:B'7. :[ 4 N 4 ,, 4,2 W t030.E',8 hl I..78 E Dista. nce Dir. ectio B e t ~,~ e e n B e t' u.,' e e n l.~J<'..~ I ] !::. {.,.Je 'l i S ERSTMRN CHRISTENSEN 1357:, 97 3092. O0 511,,00 3192.00 ~- '7 3.7 'I ""'"':' q'"': 0'."';, * .... .": ,::.. ,..::;. :: 8 3 8 =-''''` ........ : 3:.E:92.00 _1 ,:')4.:,,,=' u'"":-"..., N i :~i:.".'::].,...,z.~.. ....... E .':f~/., ,, 94 :]!::2:49 .84 1043 ,, 97 N 1.1 .20 bi · i I. 70 ~:: c., N ":'I 2 '-'"::; .: ..... E 4:::i,':-,:-'.:' ?Z ::::.7:58 2.4, 'I::"):'::7:1.4 N .'..~. 4'":',:.. W !. 29 :![.':, 72. N 23':?.', 64 i!.'E 458 :I.. 42 3:365, 9:3 ! 030 ,, ::-":: 8 N I, 78 Ii':; iR e .F : :...7;067('::,t:::i. '7 M A B i s t a. r: c e D i r. e c t i ,: Be t :~...' e e r': Be t ~e e n .bJe! t s We'f 1 s 329, 42 N56 9W 25:7.'_.', :2:2 S89 4. ! W 26:..:.:, 03 E;5iE: 23W 3 !59. i6 S4! 36, W Tf[ERSTMRN CHRISTENSEN /..:, 4. ,:"7 ,, :2::3 5,:.'.7'.-]:' 2,, 0 0 8 0 5 ,, 1 ..-'.t. !"515:' 2 ,, C, C., :2:z~ 76,97 N :2:605 ,, 1 () N '7,:] :"-': /-, .7 E ,/-, {") c).=; '7 :Z: 5:3:1. 0, .=; 7:3 4. ! :.::, 0 4 N '"" ':-",'':' ................ : ............ 60 E 7:2: 0,, ':'.':' 6 E 612 2 ,, 5 4 ~:"; 4 0'7,5 4 :3 q. :';--.."F.', 4 5: N ,:.1. 4 6,, :3 0 E ERSTMRN CHRISTENSEN BETWEEN t/..,1I:.~ ...... :, Pos i t.,.'i on on u.~e 'i 't*M-.3,::) ,_.r'" 1 o'.'.'.e:.=. ...... t Pos :i. t i on on u~e 't t r.:;~! F:-i T V b N ::'3 E W H D T V D N S E W ':;' ,:") 8 ,. F:F7 if::'::':";:' O0 !A? O S:i N 9 7'.'::.' EZ 5,, t :3 ! 9'9'Z.'., 0 0 i ?::'7, .et. 6 N 15.8 7 E ";"..'::', 91 '7.' ("~9'.--' r),:") 2 B 7 0:3 N '-"-' 9 2 2 ,. 4 4 :,219 2 ,, 0 0 2 8 0 ,, 9'7 N :]:,::)., 9 6 E 2195.63 19,'::,9.86 2282~79 2()31.:35 '.';:' :3 6 6 :'::": 0 "':' ;")'::"':" ,, ,,,:.... ,.:, .:, . :.::/ 2:366. :!::0 2089.37 '4. 5'7,, 8,::) :2:3 9 2 ,, ,:") C) :3 8:2, 8 9 N ..,= U "' ,, 2 6 '-c. 2:2: &, 6. :i-:0:2089. :37 W e 'I t s W.::.:: t i s ERSTMRN l CHRISTENSEN R.e .F : S 0 7 6 4 4- .. 8 M A 340 ,, 72 S 68 3:2 E 256,9!5 S'71 43E 17 :.3 6 :iii: '::; 7 !:::i '= ''":- 'P :I.. O0 ...... $83:25E '2 5.5::!: '.::;8 0 5 3 E 1 I :;?. 0 (') S :3 7 '.:::' iii: 214-,, ::ii: 8 S i 6 4.'F' E :318. ,_/-,'::'.. S 7 ERSTMRN CHRISTENSEN STEELHEAD .PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT A I I I I I I I I I I I TO SHALE SHAKERS f CHOKE LINE I I I I A...-.I · ' SWACO ALL VALVES IN FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA Kill Line Fillup Line 16-3/4' 10,000 psi Doubiegate Check Valve Pipe Rams Blind Rams ' I1' Flow Line Hydril 16-8/4' 5000 pei Type GK Annular Choke Line Gate Valve Gate Valve Gate Valve HCR Valve Pipe Rams 16-3/4' 10,000' $1nglegate 16-3/4' 5000 pal Riser STEELHEAD PLATFORM Preventer Schematic -T I Ball Valve Wellhead Plan View STEELHEAD PLATFORM . . DiVERTER SYSTEM 'Rig Substructure Ceramite filled ~ ~ ~' . Ceramite filled 'Div. erter Line ' ~ ~ ~'-~ 16' 'Dlverter 16' Remote Line Operated Ball Valve Riaer -., · ~ 29-1/2' 500 psi Flange Section View 1 Conductor. STEELHEAD PLATFORM BOP SChematic WELL: FROM MUD PUMPS . HYD. CHOKE ADJUSTABLE CHOKE PRESS. ~ SENSOR CHOKE MANIFOLD DRILLFLOOR . TO MUD SEPARATOR 3' TO DERRICK VENT 3' TO 8HALE SHAKER KILL LINE Co FLEXIP HOSE W LINE -~ HYDRIL TYPE GK ~16 3/4'X 5000 PSI *IPE RA 3' CHOKE LINE Co FLEXIP HOSE RAM PREVENTOR$ ARE HYDRIL TYPE V 16 3/4' x 10,000 PSI -~ .. 16 3/4'-5000 PSI RISER 16 3/4' - 5000 PSI 20" CONDUCTOR 16' CONDUCTOR 13 3/8' SURFACE CASING ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc ~ £./~'//~/ [2 thru 8] le (3) Admin s'- 9. [9 thru 13] 10. [10 & 13] 12. 13. (~) Casg ~.~.~,,~'-~$o~l' '14. [14 thru 22] 15. (5) BOPE ~-~,,~,~-~7~, ~b~- tc~- ~ t [23 thru 28] YES NO Is permit fee attached ............................................... __~ 2. Is well to be located in a defined pool ................... . ........... /~_4 3. Is well located proper distance from property line ................... /~. 4. Is well located proper distance from other wells ..................... ~_ 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... ~ 7. Is operator the only affected party.~ ................................. 8. Can permit be approved before 15-day wait ............................ . (6) Other (6) Addl 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26 27. 28. geology' RPC '"q/91 . '[29- thru 3][] 30. 31. REMARKS Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLmber appropriate .......................................... Does well have a unique name & number ................................ eng i neer i ng :_ MTM/~ LCS'~'~>' dH ./ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor $ surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ..... · ........................ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE_at~ached .... · ~ ~ ,~ __ .D° ~0 · Does BOPE have sufficient pressure rating test to ~ ~ ~s~g. ~ - Does choke manifold comply w/APl RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORT & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE o / ~- 0 -H TZ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER ****************************** *------- $Ci'~bUMSERGER ****************************** COMPANY NAME : MARAT~ON OIL COMPANY WELL NAME : TBU M-30 FIELD NAME : ~CART~UR RIVER BOROUGM : KENAI STATE : ALASKA AP1 NU~BER ~ NONE REFEREMCE ~0 : 92521 RECEIVED SEP OB 1992 Alaska Ol~ & Gms Cons. Commission Anchorage Tare Verification Listinq chlumberc~er AlasF, a Computing Center 12:19 REEL ~:'-~AaE : 92491 CO:~TI'N[:~ATiON ~ P~ EV'I:DgS REEL cOr~,~EN'T : ~4~PATHON OIL CO~4P~NY,MCARTHUR RIVER,TBU **** TAPE UEADER **** SEPVICE ~.JAME : EDIT DATE : 92/08/31 ORIGIN ,'. FLIC T~PM N~E : :9249]~ COhTIM~TION PREVIOUS T~PE CO~'~'~EM'.C : qAR~THON ~Ib CO~qP~f~!Y,~CARTHOR RIVER,TBU ~-30 **** FILE HEADER **** FILE .NA~E ., EDIT ,001 SE[,~VrCM : ~I..,!C DATE : 92/08/31 MaX 'aEC SIZE : .10~4 FILE TYPE : LnST FILE : ******************************************************************************* ******************************************************************************* ** ** ** $C~LU~BERGE~ WELL SERVICES ** ** ,~ ******************************************************************************* ******************************************************************************* COXPANY N~F: w~EATHOD OIb CO~PANY FIEI, D: ~C~RTH[.IR RIVER ~OROUGH: KENAI STATE: AL~SK^ APl NU~E~: NO~E !.,ncAT!OM: LEG a-l, SI,~? q SECTIOn: ]3 T!)WNS}!IP: 9N RANGE: 13W P,:~RMANENT DATU,'d: ~.~,S[, ELEVATION LOG }~EiASURED FR9~, ~.,~,!6'3 ABOVE PERMA}JENT IS ~raoe Verificatlo,~ bistlnq ~h!umberqer Alaska Computinq Center 31-AU~-1992 1~:19 ELEVaTiONS KB: 0 DF: GL: TD DR!LLE~: T~ LOGGE~: i4368 CASI~gG l: C~SING 3: 16" 75 LB 0 ORIGbER DEPTH OF 0 TO t439 1].375" 61 bB g DRILLER DEPTH OF 0 TO 4223 9,625" 47 LS ~ DRILLER DEPT~i OF 0 TO 12247 AND LOGGER DEPTH OF 12~34 SIZE 1: 9.5" (a 1,4370 TYPE vLUID IN HOLL]: FRESH GEL ?~t.!D DENSITY: 10 1 VISCOSI%~,~: 50 PH: 10,1 F!~UID LOSS: 5 RESISTIVITY: F!L, TRATE RESISTIVITY: CAKE RESISTIVITY: 2,02 ~ 69 1,68 ~ 69 1,75 ~ 69 TIqE CIRCULATION ENDED: 1140 08-JUN T!~E LOGGER 0~ 8OTTO~: SEE LOG MAXIi~{JM TEMP RECORDED: 177 LOGGING DISTRICT: LOGGING ENGINEER: WTTNESS: ~CCROSSAN TOOL NUMBERS: DIS-~C 42 SLS-WA i4 SGC-Sa !294 A~M-AA 837 SL~-i)~ I630 !~C-UA 156 TCC-8 837 TC~-A8 216 PHA$OR INDUCTION AND BOREMOLE COMPENSATED SONIC ~ERE P!JN IN C~:~I~ATION TOO(,, STRING WAS RUi'~ CENtRaLIZED, USING 1.5" STANDOFFS ALL PRESENTA'rlO~}$ APPROVED BY CLIENT. [~AfE JO8 STARTE~: I4-AU~- ........... , 92 OO~ REFERENCE ~0: 92a91 t,~P/A~!A: DEES ****************************************************************************** , * FTbE ' EDIT,O01 * ~AR~THON qlb CO~PA~iY IS Tape ver].ficat.ion l,istJ~no :hlumbermer Alaska Computlnc~ Center 31-AUG-t992 t2:19 ~CARTHOR RIVER PASS DATA IS FRO:"~ FIE[,D FILE; ,006 DATA SAMPLE[) EVERY -.5000 FEET DATA INCLUDE!) TOOL {×TENSION TOOL 8HC ,BHC DIT-E ,DTE BOREHOLE COgPENSATED SONIC DUAL INDUCTION SFL ****************************************************************************** PAGE: 3 TYPE ~' CONS CN F~ APIS~ FL SMC'T TmWU MATT LATI L 0 W I T ~ EPD APO EKP. EOF ECL TDb BL I TL I DFT DF D DFP~ F~ FT FI' FT FT FT mT FT G/C3 MARATHON OIL COMPANY M'CARTHUR RIVER TBU M-30 NONE LEG O-!, SLOT 9 33 9M ~!. 3 ~' ALASKA US A UNDERWOOO/KLOOSTERMAN 5485]3 -999.25 14370 14368: 14328, 12234. FRESH GEL ~UD 10,1 10,1 Company Name Field Name Well Name AP1 Serial Number Field Location Section Township Range Countv State or Province Nation Latitude Longitude Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From A~ove Permanent Datum Elevation of KellY_Bushing Elevation of OerriCR Floor Elevation of Ground Level Total Depth - Driller Total Depth Logger Bottom LoG I; ' terval T~ Log Interval D lling Fluid Type Drillin~ Fluid Density Drilling Fluid Ph its Tape verification Listing chlumber~er Alaska Computing. Center 3t-AU0-199~ 12:19 PAGES 4 TUNI VALU DEF:I DFV CP 50, Drilling Fluid Viscosity .DPI., FI ~. Prill, i.~ Fluid ~OSS R~S Oa~4 ~,.02 ResistlVi. t~ of MUd sample ~sT ~E~F g9 ~ud Sammle Temperature }~,F'S~ [}i.~_) ~i 1~8 Reststlvit~ o~ MUd Filtrate ~FST DEGF 69, 'Mud~ Filtrate Sample Temperat~ R~C,S OH~ 1 75 Reststivlt~ Of M~d Ca~e 8ampl ~C~-T [)EGF 6~ ' MUd Cake SamPle Temperature TCS !1~0 OS-jUN Time Circulation StopPed TbAB '~ SEE ~,,OG Time bogger at Bottom STE~ ~g.,~ 60 Surface Temperature TABLE TYPE ; CURV DT TT1 TT2 ~RES ClOP CI~P CIL~ CIL~ IL~ IFRE IOOF I~OF IIXD IIX~ SWLU SP G~ TENS ~TEU i~PES H T E ~ Deoth DEbTA-T TRA~SIT TIME 1 TRANSIT T!~{E 2 TRANSIT TI~E 3 TRANSIT TI~E 4 S ontaneous Potential G~mma Ray Tension ~{ud Temperature ~UD Resistivity Head Tension INDUCTION DEEP PHASOR C[}NDUCTIVITY I~DUCTION DEEP PHASOR RESISTIVITY INDUCTION gEDIUM PMASOR CONDUCTIVITY INDUCTION ~EDI!]~ PMASOR RESISTIVITY Conductivity IL Deem Standard Processed Deep Induct!on Standard Processed Resistlvlty Conductivity IL Medium Standard Processed Medium Induction Standard Processed Resistivity Induction Calibrated Frequenc~ IOOF DEEP !NDUCTIOM OUA[,!TY F CTOR IMQF MEn I~DUCTION (~[tALITY FACTOR neep Induction Real Intermediate Conductivity Deed Induction Q[~ad Inter~ediate Coad~ctivitv Yedtum Indt~ction Real Intermediate Conductivity ~edium I~duction Quad Intermediate Conductivity SFL ~esistiv~tv Unaveraged Spontaneous Po%ential Gamma Ray Tenslon ~ud Temperature ~[!9 Resistivity ~ead Tension IS Tape Verification Listing :hlumberQer AlasKa Computing Center 3!-AUG-1992 12:19 PAGE: ** DATA F©RMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 2 66 0 3 73 !36 4 66 5 66 6 7 65 ~ 65 1t 66 7 12 68 !3 66 0 14 65 FT 15 66 68 1,6 66 1 0 66 0 ** SET TYPE - CaAN ** ~E SERV UNIT SERVICE AP1 API AP1 APi FILE NUMB NUmB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS ~OD NUMB SA~P ELEM CODE (HEX) ..... ................... ..... ............. ..... ..... [)~PT FT 54~5~3 0 000 00 0 1 1 4 8 00000 0 DT BNC TTi TT~ BHC TT4 SP BHC G~ BHC TENS BHC IDP~ C!~P DTE I~P9 DTE C!LD DTE !I,D DTE CIL~ DTE ILM DTE IPPR DTE US/F 548533 US 548533 O0 US 548533 O0 US 548533 00 US 548533 O0 ~v 548533 O0 GAP! 5485~3 O0 LB 54~533 00 DEGF 548533 OH ~,~ ~ 548533 O0 LB 548533 a{~O 548533 O~a~ 548533 ~MHrJ 548533 54~533 000 O0 0 I 1 1 4 68 000 O0 0 1 1 1 4 68 000 O0 0 ! I 1 4 68 000 O0 0 I 1 1 4 68 000 O0 0 I 1 I 4 68 000 O0 0 l 1 1 4 68 000 O0 0 1 1 1 4 68 000 O0 0 1 1 1 4 68 nO0 O0 0 I ! 1 4 68 o00 00 0 1 1 1 4 68 O0 000 O0 0 1 I 1 4 68 O0 000 O0 0 1 1 ! 4 68 O0 000 O0 n 1 I 1 4 68 00 00O O0 0 I 1 ! 4 68 r)o o00 O0 0 1 I 1 4 68 O0 000 O0 0 I 1 1 4 68 00 000 O0 0 1 1 1 4 68 O0 000 O0 0 1 1 1 4 68 O0 000 O0 0 1 I 1 4 68 o0 000 00 0 I 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 wade verification [,istlnq :hlumberQer AlasKa Computing Center 31-AUG-1992 12:19 PAGE: ID GRDER ~ bOG ~.Y E CbASS MOD NUMB SAMP ELEM CODE (HEX) IDOF DTf 548533 i)O 000 O0 0 I 1 1 4 68 0000000000 I~O~ DTE 548533 O0 000 O0 0 1 1 1 4 68 0000000000 IIRD DTE MMHO 548533 O0 000 O0 O 1 I I 4 68 0000000000 IiXD DTE MMHO 54~51~3 O0 000 O0 0 1 1 1 4 68 0000000000 I,!R~ DTE ~qMHO 5~533 00 000 00 0 I 1 1 4, 68 0000000000 I!XN DTE ~HO 548533 O0 000 O0 0 1 I ! 4 68 0000000000 DU~.E OHM 48533 O0 00~. O0 0 i 1 I 4 68 0000000000 SP DTE MV 548533 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAP! 54~533 O0 000 O0 O 1 1 1 4 68 0000000000 TENS DT~ LB 54~533 O0 000 O0 0 I 1 1 4 68 0000000000 ~TE~ DTE DEGF 548533 O0 000 O0 0 1 1 I 4 68 0000000000 ~PES DTE OH~ 5485~3 O0 000 O0 0 I ! 1 4 68 0000000000 ~TE~ DTE LB 548533 O0 000 O0 0 1 1 ! 4 68 0000000000 D~pT. 14440.500 DT,BHC 76,063 TTI,BMC 483..000 TT2,BHC TT3,BHC 505'500 TT~,B~C 352.7~0 S:P'B~C -5! 094 GR'BHC TENS.BHC 2900,000 ~TEM,BHC 174'8.5 MRES.'BitC 01734 HTEN'BHC C!DD.DTE 143.750 IDPH.DTE 6,949 CIMP,DTE 121.938 IMPH.DTE CILO.DTE 146.125 ILD.DTE ~,840 CILM.DTE 124.000 ILM"DTE IFR~ DTE 20.000 IDO~,OTE 3.000 IMOF.DTE 2.000 IIRD.DTE II×OlDTE 15.992 IIRg,DTk 117,250 IIXM,DTE 4.031 SFLU.DTE SP.DTE -51.094 GR DTE 4~,469 TENS,DTE 2900'000 MTEM.DTE ~RES,.DTE 0,7~4 ~TEN[DTE -207.875 ' ~ . . ~ 76,06~ TT1,BHC 483.000 D.,PT 14400 000 DF,BHC TT2,BHC ,T3 g}!c 505.500 Tw¢ B~C 352,750 SP.BHC -5~,188 GR.BHC T~NS~B{qC 7500,000 ~TE~BBC 174,875 MRES,BHC ~. 734 HTEN,BHC C!DP.DTE 14].g75 IDP~ DTE 6.949 CI~P.DTE 121 938 I~PM,DTE CILD DTE 146 125 l.bD~~' ' ' [..rE 6,840 CIL~ DTE 124 000 IbM DTE IFR~.DTE 20.000 'IDOF.DTE 3.000 IMOF OTE 2.000 IIRD.DTE IIXD.BTE 15.992 I!~A~.OTE 117.250 IIXM:DTE 4.031 SFLU.DTE SD.DT~ -51.1~8 GR.DTE 41.469 TENS,DTE 7500.000 MTEM.DTE NPESoDTE 0,'734 HTEN.DTE 437.250 [DEPT. 1430<).000 DT.BHC 73.3i3 TT!,BRC 468.000 TT2.BMC TT3.BHC 471.,300 TT4.BHC 324 750 SP dHC -47.688 GR.BHC TF~S.B~iC 7710.000 gTEM.BHC 174~875 NRES:6HC 0.734 HTEN.BHC CIDP,DT~ 1~0.000 !i)PH DTE 7.137 CIM[:,OTE 129.375 I~PH.DTE CII.,D.DTK 144.125 ILD~DTE 6.934 CILM.DTE 132.375 ILM.DTE IFR~,DT~ 20,000 !r)QF.DTE 0,000 !~QF,DTE 0.000 IIRD,DTE ITXD,OTR 16,5q4 II~.I3TE 125.063 IIX~i,DTE i0 052 SFLU.DTE SP.DTE -4'1.6~8 ~. DTE 45 188 TENS.DTE 77 0~000 MTEM.DTE MPES.DT~ 0.734 H'FE~i>TE 584~O00 ' ' 3al,500 469 128,375 9,945 174'875 331.500 41,469 437,250 8,195 8,055 128.375 9,945 174,875 321,000 45,188 584.000 7,723 7.551 127,813 11.742 174.875 IS Tape verification Listinq chlumber~er AlasKa Comvutinq £.~nter D~PT'. t4200,000 OT, TT3.BHC 442.25{i) TTI. ~{HC T~S.aHC 7400.000 CI9~. DT[ 75,125 t[)PH. [>T~2 IFRE.DTE 90.000 ![)QF.DTE IIXD.DTE ~.492 IIR~4. DTE MP.DT~ -6,4. 063 GR.DTE ~'i~ES. DTE 0,'738 HT~N,I)T6 DEPT. 14000,000 DT.8HC TT3.BHC 471.000 TT4.BMC TE~S.BHC 7180.000 ~TE~.~C CIDP.DTE 96 313 IOPM [)TE CILD.DT.~M 99' ,. .688 ILO.DTE IFRM.DTE 20.000 I!XD.f)TE 8.813 !IR~.DTE SP.D'~ . I~. -76.813 (;R DTE aRMS'DTE 0.739 aTEN.OTE DEPT. 113900.000 DT.BMC TT].BHC 471,000 TT4.BMC TEN$.BHC 7020.000 ~TE~.~HC CID~.DT~ 133.125 IOPH,i)TE CIb~.DTE !35.000 ILO.DTE IWRE.DT~ 20.000 IOQF.OTE IIXO.DT~ 8,250 i!R~.DTE SO.DTE -77.125 GR.DTE MRES.DTE 0.733 ~TE~.DT~ DEPT. 13800.000 DT TT3.BHC 4ga.000 TENS.B~4C 7150.00(~ ~4TEM.BHC CID°.DT~ 292.750 !DDa.t)TE CILD.DTE 207,000 ILO.DTE IFR~.DTE 20,000 !DOF.DTE II×D.DTE 31.438 SP.DT~ -91.750 GR.DTE N~ES.DTE 0.731 HTEN.DTE 31-~[!G-1992 12:!.9 67.625 TTI.BHC 11,000 $'P.~HC ~7 ,763 ~RES,~tC 1.3.305 CI~P,DTE 12.117 CiLa,9TE ,¢" OTE 68,125 II~,QTE 24.719 TENS,OTE 558,000 71,125 TTI.BHC 32~.750 SP,SHC 17 ,212 ~RE$,:BHC 18.406 CI~,DTE 17.922 CIL~,DTE 0 000 IMOF'DTE DTE 59 031 iI×~,i 48 906 TEN$,]TE 549 500 71.813 TTI..BHC 3~3,000 SP.:BHC 1 4,425 MRES.BHC 10,375 CIa~,DTE 10,023 ClL~,D'TE 0,000 IM~F,DTE ~7,375 IIX~'DTE 37.375 TENS,DTE 541,000 76.250 TTI.BHC 339.500 SP,BMC 174'200 MRES.BHC 7.508 CI~P,DTE 7.406 CII,~.DTE 0,000 I~0F,OTE 130.500 IIX~.DTE 46.594 TENS.DTE 516.000 78 000 TTI.~HC 344i750 SP.BHC 174 087 ~RES.~HC 3.414 ClMP.DTE 3,365 CIL~.DTE 0.000 I~OF.DTE 245.000 IIXM.OTE 51.625 TEN$.DTE 543.500 78,438 TT!.8HC 338.750 SP.BgC 173.750 10,773 CI~P,DTE 10.680 CII,,q. DTE 441-500 0,738 ~8,188 1.813 0.000 1 360 7. o:ooo 449.000 -55 500 0 736 64,938 62'188 0.000 0.609 7270,000 477.500 -76,813 0.739 87.438 92,250 0.000 -1.038 7180.000 ~60:~007 25 136.~75 138.250 0 000 -0:55O 7020.000 496.250 -91.750 0.731 258.750 261.500 0.000 10.359 7150.000 477.500 -107.000 0.737 96 625 92:500 TT2.BHC GR.BHC HTEN.BHC !~PH,DTE II, M'DTE IIRD.DTE SFbU.DTE MTEM.DTE TT2.BHC GR.BHC HTEN,BHC IMPH,DTE ILM,DTE IIRD.DTE SFLU'DTE MTEM,DTE TT2.BHC GR,BHC HTEN,BMC I~PH.DTE ILM.DTE IIRD,DTE SFLU,DTE MTE~.DTE TT2.BHC GR.BHC HTEN'BHC IMPH.DTE ILM'DTE IIRD.DTE SFLU.DTE ~TEM.DTE TT2.BMC GR.BHC HTEN,BHC I~PH.DTE IL~.DTE IIRD.DTE SFLU.DTE MTE~.DTE GR,BHC HTEN.BHC I~PH.DTE IL~.DTE 306.250 24'~i9 558,000 t4,648 !3,914 75;500 18.'813~ 174,763 61,750 3{8,906 549,500 15'38~ 16,06 0'500 ~4'281 175,212 322.250 37.,~75 541',00 li 430 10 836 91 875 21 406 174,425 330.250 46,594 516,000 727 7:2~7 ' 625 1172,:180 174,200 338,250 51,625 543.500 82O 247'375 8,289 174,087 330,750 40,031 542,000 10,344 10,805 IS Tape verification bistinq cblumberqer AlasKa Computinm Center P T, 1360 !~ · 000 D T, B H C DTT. 3. BHC 44z, 250 TT4, ~.. TENS,RHC 7000,:~00 C!DP.DTE 41.!88 IDPH,DTE C t~ o Dr ~; 45.5 o o SP,DTE -94,063 GR.DTE ~q~ES.DTE 0.733 HTE~, UTE DFPT. 13500,000 DT,BHr T~[~,BH¢ 443'500 TT4'BH~ TEN8,B~C 6935,000 ~TEr~. BHC CIOP,D E ' 51.094 IDPH.DTE C!bD D',.,.E 52 7i9 15,3 DTE IFRM.DTE 20,000 IDOF.DTE IIXD,DTE 6,~31 IIR?~'DTE SP.DTE -86, 50 GR, DTE MRE .... DTE O, 734 HTEN. DTE DEPT, ,t. 3400 000 DT.BHC TT3.BHC .~30.'500 TT4, BHC TENS.BHC 6860.000 MTEN.BHC CIDP.DTE 46.875 IDPH,DTE CIh .... DTE 49 219 IbD DTE .IFR~OTE 20,000 IOOF,DTE IIXD.DTE 3,225 IIR~,DTE SP. DTE -84,438 GR. DTE ~ ES. DTE 0.739 HTEM,DTE DEPT 13300.00L) PT BHC TT3 :BHc 486,750 ,['T4: BHC TENS. ~HC 6860. 000 CIDP.~TK 53.563 IDPH.DTE CILU.DTE 55. ~44 IbD.DTE IFRE.DTE 20.000 :~nE8. DTE O. 737 HTEN.DTE DKPT. 13200. 000 DT. BHC TT3. ~HC 465. 000 TT4, TE~,IS. BHC 6855.000 HTEM.BHC ClPP.~TE 45,094 !DPM.OTE CILD. DTE 46,563 ILD. DTE IF'RE. DTE 2G, O00 !DOF, DTE IIXD.DTE 2.545 I !~ ~. ~)TE: SP. DT~ -gq, 438 GR. DTE ~.~RES. DTE 0.743 31-AUG-!992 0,000 I~4OF. DTE 87, 25 40. 31 TENS.,..'.~E O, 000 71 000 307'~66 88 TTI. BHC ~50.250 ., 00 SP'gHC 94':063 , ~RES, 1,73 1.88 '~ BHC 0'733 4,250 CIMP.DTC 36.906 21.969 CIb~,DTE 41,844 0,000 IMOF.DTE 0.~000 39,781 II×~'.DTE 0.671 46,781 TENS,DTC 7000.000 518.ooo 67,250 TTI,B, C 31:1.500 SP,.aMC !72,962 MRES,BHC 19.563 CI~P'DT:£ 18.95'3 CIL~,DTE 0 000 I~QF,DTE 50.'375 IIX~:, DTE 41.938 TENS,DTE 5!!,750 .312. 0 172 625 21 313 20 297 0 000 45 625 ~3~844 496,250 75.938 332.250 172 175 181656 18.063 0,000 56 094 524,500 '' SHC MRES,B~C CI~P.DTE CILM.DTE I~QF,DTE IIXM,DTE TENS,DTE TT1 BHC sp:~c ~RES.BHC CIMP.DTE CILM.DTE IS~F.DTE IIXM.DTE TENS,OTE SP,BHC uRES.BHC CI~P,DTE CIL~.DTE I~OF,DTE IIXM,DTC TENS,DTE 60.063 316.750 71.275 !22.172 21,469 0.060 4~.906 4 .761 594.500 39'000 ~86,250 0,734 50.875 53,031 0,000 4.438 6935.~000 52 250 0 739 48.000 0'000 6860 O0 485.000 -100.625 0 737 5~.094 .000 -2.502 6860.000 45~.750 -99.43@ 0 743 42:219 45,125 0.000 68~6 969 5~000 IIRD,DTE SFbU,DTE MTEM,DTE TT2.BHC GR,BHC HTEN,BHC IMPH.DTE ILM.DTE IIRO,DTE SFLU.DTE MTEM.DTE TT2,BHC GR;B~C HTEN.BHC I~PH.DTE ILM~DTE IIRD,DTE SFLU,DTE MTE~,DTE TT2.B~C GR'BHC HTEN'BHC IMPHiDTE ILM,DTE IIRD.DTE SFLU DTE MTEM:DTE TT2.BHC HTEN,BHC IMPH,DTE ILM.DTE IIRD.DTE SFLU,DTE MTE~,DTE TT2 BHC GR:BHC HTEN,BHC IMPH,DTE IbM DTE IIRD:DTE 8FLU.DTE MTEM,DTE 81,438 . '078 1½6~.75o 308,250 46'781 518,000 27,078 23~87:5 4~.0.94 42,1.88 ~73;188 305'000 41'.' 5!1:'~ 0 4~:844 59,4 28;68~ I72.'962 '375 .813 44'656 28.500 ~72'625 °°., t7,391 !6,906 50,219 23,359 172,175 304,750 45,781 594,500 23,672 I~'141 ,281 44 438 171:275 Tape Verj, fication L, istJnc]. c.~lumberger Alaska Co,~!t,~utino Center DEPT. 13 ! 00,000 i.)T. B}!C TT3, BP~C 51 I.. 500 TT4, BHC T.ENS,BHC 6@30,000 C!DP,DTE 90,625 !DPH,DTE CILD aTE 92.875 ILD, OTE IIXD.DTE 6,172 SP. aTE '~ 14,625 GR. DTE MRES'DTE 0,743 HTE~'J, aTE DE;PT, ! 3000,000 aT. BHC TT3, BEC 520,000 TT4 TENS.BMC 6500,000 ~4TE~4, BHC CIDP,DTE 153.750 IDPH,DTE CILD.DTE 154. 375 ILD,DTE IFRE'DTE 20,000 IDDF,DTE IIXD DTE 9 328 IIR~,DTE ~RES,DTE 0,742 HTEN,DTE DEPT, 1 ~900,000 DT TT3, BHC 442,750 TT4, BEC TENS.BHC 6515,000 CIDP.DTE 92,188 IDPH,DTE CILD.DTE 96,0n0 ILD. aTE IFRF.DTE ~0,000 IDOF.DTE DTE ~I 000 !IRE aTE IIXO. , . SP. ') ' ' [. 7. E -113.963 GR. DTE '~PES, aTE 0.750 HTEM.DTE D~TPT .! 2800. nO0 aT. BHC T?3 .' "'~ .... , ' ..... , B.~C 756 C)Oo TT4 BEC TE~'~S,B~C 6500,OO0 r.~TEM. BHC CIDP,DTE lq.500 IDPH.OTE CILD. DTE 23,82$ ILO, DT~3 IFRE.DTE 20,000 IOOF.aTE I IXP, aTE 3.361 IIR~. aTE SP. DTE -65.189 GR, DTE ~4RES.DTE O. 76'.~ ~TEN.DTE DEPT. 12600 000 DT' · T'r3. BHC 492:750 TT4:BHC TEt~S.B~C 62!5.000 C! DP. DTE nO. 18~ If)P~. I':'TE 3 i-;.%L:G- 1992 !,2:19 75,3!3 TTI.B~C 504,,750 357,550 SP,BMC -114.625 !71,163 MRES,BMC 0.74~ !1'023 CI~P,.DTE 83-563 10.758 CIL~,OTE 85.$13 0,000 i~QF'DTE 0.000 ~.313 IIX~,DTE 0 481 3~,938 TE~S,DTE 6830[000 577.0(i)0 82,4.38 TT!,BHC 365'5oo 8p. BHC 170.263 .~RES.BHC 6,500 I~P,DTE 6,473 CIL~.DTE 0,000 I~O. ,aTE 45,875 IiXM,DTE 154,969 TENS,aTE 440,250 3~ ,813 .000 170 263 10 836 10 414 0,000 76,375 47,563 520.0O0 126 ~.13 s56: aa 1:69.587 51.250 41,938 0.000 30.344 38,063 579,000 124 750 550:000 169 587 51~406 g3,750 0.000 23 313 371531 431.000 76.813 345,000 !68.688 11.086 TTI,BHC SP,BHC MR. ES.,B!4C CIMP,DTE T' II×~,DTE TENS,aTE TTI.BHC SP.BHC CI~P,DTE CIL~,DTf IMOF.OTE IIXM.OTE TENS.aTE TTI.SMC SP.BHC ~RES,BHC ClaP,aTE CIL~,DTE IMQF,DTE TE~$.OTE TTI.BMC SP,BHC CX p'.0T 522 000 -57:563 0.742 149,125 154,625 0.000 -~.114 650 .000 435.500 0 75O a:soo 80 563 0~000 0,579 6515.000 36 0 0 31.906 0,000 -8.477 6500.000 !~8.500 4.813 0.750 25.266 24.500 0.000 -6.949 6280.000 492.000 -109.438 0.753 84.875 TT2,.BHC GR,BHC HTEN.BHC IMPH,DTE IILM.DTE IRa.aTE SFLU,DTE MTEM,DTE TT2.BHC GR.BHC HTEN,BHC I~PH.DTE Ih~,DTE IIRD,DTE SFLU.DTE ~TE~,DTE TT2BHC MTEN,BMC I~PH,DTE Ib DTE SFLU DTE MTE~:DTE TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILP,DTE IIRD,DTE SFLU.DTE MTEM.DTE TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILM.DTE IIRD.DTE SFLU.DTE MTEM.DTE TT2.BHC GR.BHC HTEN BHC I~,PH:DTE PAGE: 339.500 36,938 '000 '961 ,'984 ! ,163 368,25'0 54;969 440'250 6~699 6'465 I35'250 170i2 563 .s 6'ooo ~27 .063 ,000 51~.313 3 ,328 2~,688 241,625 169'587 544,500 37,53! O0 40.781 21,563 115.500 169,587 337 500 64:000 402.750 11,773 I$ Tape Veri. f!cation Listing chl. t]~berqer Alaska ComDutlno Center DEP?. 12500. ©00 DT, 8HC TT3' BHC 44! .000 TT4. TENS.~HC 6!35 000 CID'. DTE 62.9'38 IDPH. DTE CILD. DTE 65. 875 IbD, DTE DOF IFRE.DTE 20,000 I I!XD.DTE 3,385 II SP, DT~ '102.250 M~ES DTE 0,753 . ........... , DTE DEPT. 12400,000 DT,BHC TT3' BHC 523. 500 TT4.BHC TENS.BHC 6400,000 CIDP.D' E , r~ !J7 688 IDPH,DTE CILD. DTE 1 ! 9' 500 ILD. DTE IFRE. .[)T~' ...... 20,000 IDOF,b.:E I!XD.DTE 6.719 I SP. DTE -1 ~8. i 25 GR,DTE ~%~ES.DTE 0.764 8TEN,DTE DEPT. 12300,000 DT. BHC TTB,RHC 5~9 000 I 4 BHC ,r E vt,~ BHC 6330.000 MTEt~; BMC · C!D~,DTE 4! .06~ IOPH.OTE C I [, D. D T E 46.031 I I,, D. O T E IFRE.DTE 20.000 IDOF.DTE I!XD.DTE 8.266 IIRM.DTE SP.DTE -115,875 GR.DTE MRES.DTE 0.807 HTEN.DTg DEPT. 12200. 000 DT. BHC TT3. BMC 364. 250 TT4. BaC TENS.BMC 6400,oo0 ~TE~4,BHC CYDP.DTE ~3,438 IDPI-{. DTE C!bD. DTE 85. uO0 !LD. DTE IFRE.DTE 20.000 I!)QF.DTE IIXD,DTE -460.750 IIRDI.OTE SP. DTE -116. 563 GR, DTE ~E;S. [)TE O,g03 HT~qN. DTE DEPT, 1.2102.OO~) DT.BHC TT3.EHC 366.750 TT4.B~C TENS.B~C 6400,000 ~TE~.BHC CIDP.DIE 94.~25 IDDM.~TE CILD.DT~ 96.750 ILg. DTE IFRE.DTE 20.000 IDOF.DTE IIXD.DTK -460,250 I!RM.DTC SP,DTE -120.938 GR.DTE ~RE$,DTE 0,807 HTE~.OTE 31-AUG-1992 12:19 t0,93@ CIbM,DTE 0.000 IMQF.DTE ~2,813 IIXM,DTE 64,000 TENS,DTE 402,750 67 000 331 000 168 350 15 ~75 15 164 0,000 67,688 67,125 420'250 84,688 356'750 167,900 8,492 8,367 0.000 100,438 52,375 486'750 38.4'000 167.675 24 344 0,000 63.781 1,875 5~8.500 56.094 250 250 ~66:663 11 977 11~758 0 000 -320:750 19.063 543.500 56 625 254i625 166 325 10 563 lo: 2s 0 000 -446~500 42.656 505.250 TTI,BHC MRES,SMC CIM~.DTE CI[~i~'OTE !~QF,DTE I'IX~,QTE TEN$,DTE TTI.B~C SP,BHC MRES,~OHC CIMP,DTE CIbM,DTE IMQF,DTE II×~.OTE TENS,DTE TT1.BHC SP.BHC CI~P DTE I~QF,DTE IIXM,DTE TENS, DTE TT1,SHC SP.BHC CI~P.OTE CILM,DTE I~QF.DTE IIX~,DTE TENS,OTE TTi.BNC MRES,SHC CI~P.OTC CIL~,OTE IMQF.DTE IIXM,DTE TENS,DTE 87,375 0,000 -3.65 6~15,000 440.~50 69.750 71'375 .0.000 428 525,500 -128,125 0.764 !03 9 0 000 0 390 6400,000 502 000 - 5 ~75 110 07 61. 063 67 188 0 000 -0 641 6330 000 363.000 -116.563 0.803 -328.000 -328.750 0 000 4 :5oo 6400.000 364.000 -120.938 0.807 -447.250 -453.500 0.000 1256.000 6400.000 IteM, DTE IIRD*DTE SFLU ,DTE MTE~'DTE TT2.BHC GR.BHC HTEN,BMC I~P~,DTE IL~'DTE IIRD.'DTE FLU,DTE ~TE'M.DTE TT2,BHC G~,BHC BHC HTEN, T~ !MPM.D.,,,E IL~,DTE IIRD,DTE SFLU,DTE NTEM,DTE TT2,BHC GR.BHC HTEN.BHC IMPH.DTE IL~.DTE IIRD DTE SFLU:DTE MTE~,DTE TT2.BHC GR.BHC HTEN.BHC IMPH..DTE IL~,DTE IIRD.DTE SFLU.DTE ~TEM.DTE TT2.BHC GR.BHC HTEN,BHC .IMPH.DTE IL~.DTE IIRD.DTE SFLU.DTE MTEM.DTE PAGE: I0 I ,438 810;938 14,828 168,688 3111'500 67.t, 25 420"'250 14.328 !4'008 60.~9 14;797 168.350 356,250 52,375 486,i750 105,313 14.211 167,900 16,359 !41'86.7 ,063 167.675 2501,000 19.063 543;500 1950'000 1950.000 75'125 9696°000 166,663 249.500 42,656 505,250 1950,000 1950,000 86'188 9696.000 166.325 Tape Veriflcat. io:~ 5isting chlum~erqer AlasKa Computing Center 31-AUG-].992 t2:1.9 PAGE: **** FILE TRAIbER **** FILE NA,~E : EDIT ,001 SERVICE : FLIC DATE : 92/0S/31 MAX REC SIZE : 1024 FILE TYPE : LO L~ST FILE : **** TAPE TRAILER SERVICE NA~E : EDIT DAT~ : 92108/31 ORIGIN : FLIC TAP~ NA~E : 92491 CONTIN[~ATION # : 1 PREVIOUS TAPE : CON~ENT : ~ARAT~.~ON OIL COMPANY,~CART~OR RIVER,TBU **** REEb TRAILER DATE : 92108/31 ORIGIN : ~LIC REEL ~A~E : 92491 CONTtNUATIf~ # : PREVIOUS REEf, : CO~ENT : ~ARATH05i OIL COMDANY,~CARTNUR RIVER,TBU M-30
