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183-053
~ge Project Well History File~ver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ~3- ~)5-,~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZ~J!51on-Scannable) [] Other: .![],!//J,x~s o! various kinds NOTES: '~ Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: [S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Scanning Preparation BY: BEVERLY BREN VINCENT SHERYL (MARIA~LOWELL Production Scanning Stage BY: Stage 2 PAGE COUNT FROM SCANNED FILE: ~ OUNT MATCHES NUMBER IN SCANNING PREPARATION: YE...S ;~ BREN VINCENT SHERYL MARIA LOWELL DATE'.II,~)'O~ ,S'~/~ IF NO IN STAGE 'l, PAGE(S) DISCREPANCIES WERE FOUND: ~ NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or 'Comments about this file: Quality Checked • ~~,.®~~ FrarTCisco Castro Chevron North America Exploration and Production a Technical Assistant 3800 Centerpoint Dr. Suite 100 '~ Anchorage, AK 99503 Tale: 907 263 7844 =~?~; Fax: 907 263 7828 ~.:~i~a::.~:=, E-mail: fcastro@chevron.com DATE September 9, 2010 To: AOGCC Mahnken, Christine R 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 PERMIT # WELL LOG TYPE LOG DATE INTERVAL LOGGED 8- LINE CD 183-0530 TBU D-42 MEMORY GRADIOMETER 8/20/2010 200-9190 X X .. . 1~3-os3 aosd ~ S - ~'~ ~3~ ~ ~ ~K`3 Please acknowledge receipt by signing and returning one copy of this .transmittal or FAX to 907 263 7828. Received ey: Date: .. •~ :~~~ m ~;.~'~ba . '" ~~!Æ~E : F !Æ~,Æ~~~~ AT1ASKA. OIL AlVD GAS CONSERVATION COMMISSION Jerry Bowen Advising Drilling Engineer Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Dolly Varden D-42 Sundry Number: 304-390 Dear Mr. Bowen: {~3 .~ (),tj3 FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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. BY ORDER OF THE COMMISSION DATED this~ay of October, 2004 Encl. -/" SCANNED OCT vI 2 2004 1. Type of Request: STATE OF ALASKA E EIV D i ALASKA OIL AND GAS CONSERVATION COMMISSION . ~r. APPLICATION FOR SUNDRY APPROVAL OCT 2 2 20~ Jè)J 20 MC 25.280 p"~~ir~ nil $I.. r~1)~ p(~n? C"mm~::~~ Operational shutdown U Perforate U ...........;i "'Wär~ë~'W:rk~~""~nufãrÖíšpo'š.'LJJ;ii Plug Perforations D Stimulate D Time ExtensiókëY' o'ì;.J6 Other D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Suspend L::J Repair well D Pull Tubing 0 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' AMSL Development Stratig raphic 0 D Exploratory D 83-53 Service D 6. API Number: 42?V1 50-733-20205 - 'J \ ,U f ). J 8. Property Designation: Trading Bay Unit 11. Total Depth MD (ft): 9. Well Name and Number: Dolly Varden D-42 10. Field/Pools(s): McArthur River I Hemlock Pool Total Depth TVD (ft): PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): Casing Structural Conductor Length Size MD TVD Burst Collapse Surface Intermediate 3,000' 10,510' 13 3/8" 3,000' 2,601' 95/8" 1 0,51 0' 8,033' 7" 12,828' 9,870' . 3,090 psi 6,870 psi 1,540 psi 4,750 psi Production Liner 2,652' Perforation Depth MD (ft): (see attached) Packers and SSSV Type: 8,160 psi 7,020 psi Tubing MD (ft): 9,179' (ESP base at 9,279') Perforation Depth TVD (ft): Tubing Size: Tubing Grade: (see attached) 41/2" 12.6 ppf L-80 IBTC None - ESP artificallift wI live annulus, No-Flow Packers and SSSV MD (ft): status approved 7/24/2002 NIA 12. Attachments: Wellbore Schematic Description Summary of Proposal ~ 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: Oct. 21, 2004 (approximate date) Date: 13. Well Class after proposed work: Exploratory D Development 0 Service D 15. Well Status after proposed work: s.~~t'\~.) /i}?M. \ò(~":> Oil D Gas D Plugged 0 Abandoned WAG D GINJ D WINJ D WDSPL D D 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~Je. Bowen /J Title Advising Drilling Engineer Signature I~ Phone 907-263-7640 Date COMMISSION USE ONLY Jerry Bowen 20-0ct-04 Conditions of appro I' N t'fy .. va. 0 I Commission so that a representative may witness ') V\<t..":>~~ ~~~~~ '\~ r- BOP Test 1171 M h . I~ ec anlcallntegrity Test D Location Clearance D Other: ~\)()()~.;\ M.\ "-\M~~ \S'C)'? ~">.\-- ~~.\<t:.S.-\ \"'~~ \ L.. ~ ~'f';:., Sundry Number: 3oý'- 39¿;; y Plug Integrity ~ 8fl OCt! 0 R I 61 NALvORDEROF COMMISSIONER THE COMMISSION SCANNED~C ¡ 2A,Q4L Date: If) ~ 7 () T Su mit in Duplicate Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE . UNOCAL8 Dolly Varden Platform Well D-42, AFE 163121 Recover ESP Completion OBJECTIVE Recover the failed ESP in well D-42 & abandon completion. PROCEDURE SUMMARY 1. Skid rig from D-47 to D-42. 2. Slowly de-pressurize the tubing and casing to minimize damage to the ESP cable. 3. Load well wi 3% KCl. Circ oil out of annulus. Spot LCM pill, if necessary, to manage losses and keep hole full while POR wi tbg & ESP cable. 4. Set BPV. ND tree. NU & test 13 5/8" 5m BOPE to 250/3000 psi as per attached diagram. 5. Verify well dead and FL can be maintained at surface. Circ well clean to verify no oil has entered tbg or annulus. 6. POR & LID 4 'li" tbg, cable & failed ESP. 7. RU E-line unit. Set CIBP (or EZSV) above top offish at +1-9400'. 8. Pressure test wellbore & CIBP to 1500 psi.. .,. <:.. "'~~ .\~~\- ~ ~O",\c,.C:\- þ...\)~~C 10. RIR wi 300' kill string. -\0 " \: 11. Install BPV. ND BOPE. NU & test tree. ~\ ~\cS.~ 12. Dump bail 30' of cement on top of CIBP while de-activating rig & backloading equipment. SCANNED OCT 7 2 2004 AOGCC D-42 ESP Workover Summary.doc 1 of 1 October 20, 2004 .. Page 10f3 >Information >Well >Directional Surveys >Full Survey Select Well: I D-42 2:1- ~~~ Report Name Well Date Created Position Log D-42 10/20/2004 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) Interpolate D-42 OIL 507332020501 106 208,384 2,490,829 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 106 0 0 208,384 2,490,829 0.0 0 100 99 7 0 0 208,384 2,490,829 0.4 359 200 199 -93 0 1 208,384 2,490,830 0.5 358 300 299 -193 0 2 208,384 2,490,831 0.8 315 400 399 -293 -1 1 208,383 2,490,830 0.3 176 500 499 -393 0 0 208,384 2,490,829 1.9 110 600 599 -493 5 0 208,389 2,490,829 5.1 70 700 699 -593 13 5 208,397 2,490,834 5.6 32 800 798 -692 17 16 208,401 2,490,845 7.3 12 900 897 -791 20 31 208,404 2,490,860 10.6 8 1,000 995 -889 22 52 208,406 2,490,881 13.4 357 1,100 1,092 -986 21 77 208,405 2,490,906 15.8 358 1,200 1,187 -1,081 21 105 208,405 2,490,934 17.4 358 1,300 1,282 -1,176 20 138 208,404 2,490,967 20.1 358 1,400 1,375 -1,269 20 175 208,404 2,491,004 23.6 357 1,500 1,465 -1,359 19 217 208,403 2,491,046 27.0 358 1,600 1,553 -1,447 18 266 208,402 2,491,095 31.0 357 1,700 1,637 -1,531 17 320 208,401 2,491,149 34.9 357 1,800 1,717 -1,611 15 379 208,399 2,491,208 37.4 356 1,900 1,798 -1,692 11 439 208,395 2,491,268 35.7 354 2,000 1,879 -1,773 8 497 208,392 2,491,326 35.5 357 2,100 1,959 -1,853 8 557 208,392 2,491,386 38.4 358 2,200 2,035 -1,929 7 622 208,391 2,491,451 42.2 358 2,300 2,107 -2,001 7 691 208,391 2,491,520 46.0 358 2,400 2,175 -2,069 7 764 208,391 2,491,593 47.4 359 2,500 2,245 -2,139 12 836 208,396 2,491,665 44.5 7 2,600 2,317 - 2,211 27 903 208,411 2,491,732 43.4 14 2,700 2,389 - 2,283 48 969 208,432 2,491,798 44.4 20 2,800 2,460 - 2,354 76 1,034 208,460 2,491,863 45.3 24 2,900 2,531 -2,425 107 1,098 208,491 2,491,927 45.1 24 3,000 2,602 -2,496 138 1,161 208,522 2,491,990 44.2 25 3,100 2,674 -2,568 168 1,224 208,552 2,492,053 43.6 25 3,200 2,747 -2,641 198 1,285 208,582 2,492,114 42.8 24 3,300 2,820 -2,714 227 1,346 208,611 2,492,175 43.0 24 3,400 2,893 -2,787 256 1,408 208,640 2,492,237 42.5 24 3,500 2,967 -2,861 286 1,469 208,670 2,492,298 42.8 24 3,600 3,040 -2,934 315 1,530 208,699 2,492,359 42.4 24 3,700 3,114 -3,008 343 1,591 208,727 2,492,420 42.6 24 3,800 3,188 -3,082 372 1,652 208,756 2,492,481 42.3 24 SC,8\NNE.D OCT 72 2004 3,900 3,262 -3,156 40i 1,714 208,785 2,492,543 42.9 23 http://kodiak.anchortown. unocal.comJ da/templates/positionLog.asp 10/20/2004 " Page 2of3 4,000 3,335 -3,229 429 1,776 208,813 2,492,605 43.3 23 4,100 3,407 -3,301 458 1,839 208,842 2,492,668 44.3 23 4,200 3,478 -3,372 487 1,902 208,871 2,492,731 44.6 23 4,300 3,548 -3,442 516 1,967 208,900 2,492,796 46.0 23 4,400 3,618 -3,512 546 2,032 208,930 2,492,861 45.8 23 4,500 3,687 -3,581 576 2,098 208,960 2,492,927 46.8 23 4,600 3,756 -3,650 605 2,164 208,989 2,492,993 45.5 23 4,700 3,826 -3,720 634 2,230 209,018 2,493,059 45.7 22 4,800 3,897 -3,791 662 2,295 209,046 2,493,124 45.2 22 4,900 3,968 -3,862 690 2,360 209,074 2,493,189 44.1 22 5,000 4,039 -3,933 717 2,424 209,101 2,493,253 44.7 22 5,100 4,111 -4,005 745 2,488 209,129 2,493,317 43.6 22 5,200 4,183 -4,077 772 2,551 209,156 2,493,380 43.6 21 5,300 4,256 -4,150 798 2,615 209,182 2,493,444 43.4 21 5,400 4,329 -4,223 824 2,678 209,208 2,493,507 42.7 21 5,500 4,402 -4,296 850 2,741 209,234 2,493,570 42.8 21 5,600 4,476 -4,370 875 2,803 209,259 2,493,632 41.9 20 5,700 4,551 -4,445 900 2,865 209,284 2,493,694 41.8 20 5,800 4,626 -4,520 924 2,927 209,308 2,493,756 41.7 20 5,900 4,701 -4,595 949 2,989 209,333 2,493,818 41.1 20 6,000 4,775 -4,669 973 3,050 209,357 2,493,879 41.8 20 6,100 4,849 -4,743 998 3,112 209,382 2,493,941 42.7 21 6,200 4,923 -4,817 1,025 3,175 209,409 2,494,004 43.1 21 6,300 4,996 -4,890 1,051 3,238 209,435 2,494,067 42.9 21 6,400 5,068 -4,962 1,078 3,302 209,462 2,494,131 44.1 21 6,500 5,140 -5,034 1,104 3,366 209,488 2,494,195 44.2 21 6,600 5,212 -5,106 1,131 3,431 209,515 2,494,260 44.7 21 6,700 5,283 -5,177 1,157 3,496 209,541 2,494,325 44.8 21 6,800 5,353 -5,247 1,184 3,562 209,568 2,494,391 45.6 21 6,900 5,423 -5,317 1,212 3,628 209,596 2,494,457 45.8 21 7,000 5,492 -5,386 1,239 3,694 209,623 2,494,523 46.6 21 7,100 5,561 -5,455 1,267 3,762 209,651 2,494,591 46.9 21 7,200 5,629 -5,523 1,298 3,828 209,682 2,494,657 46.8 25 7,300 5,698 -5,592 1,334 3,891 209,718 2,494,720 46.5 32 7,400 5,767 -5,661 1,374 3,951 209,758 2,494,780 45.8 33 7,500 5,837 -5,731 1,414 4,010 209,798 2,494,839 45.5 33 7,600 5,907 -5,801 1,454 4,069 209,838 2,494,898 45.4 33 7,700 5,977 -5,871 1,494 4,128 209,878 2,494,957 45.0 33 7,800 6,048 -5,942 1,534 4,186 209,918 2,495,015 44.9 33 7,900 6,119 -6,013 1,573 4,244 209,957 2,495,073 44.5 33 8,000 6,190 -6,084 1,613 4,302 209,997 2,495,131 44.8 33 8,100 6,262 -6,156 1,652 4,360 210,036 2,495,189 43.9 33 8,200 6,334 -6,228 1,692 4,417 210,076 2,495,246 43.9 34 8,300 6,407 -6,301 1,732 4,473 210,116 2,495,302 43.0 34 8,400 6,479 -6,373 1,772 4,529 210,156 2,495,358 43.6 34 8,500 6,552 -6,446 1,812 4,585 210,196 2,495,414 43.9 34 8,600 6,624 -6,518 1,852 4,641 210,236 2,495,470 43.6 34 8,700 6,696 -6,590 1,893 4,697 210,277 2,495,526 43.5 35 8,800 6,769 -6,663 1,934 4,753 210,318 2,495,582 44.0 35 8,900 6,840 -6,734 1,975 4,809 210,359 2,495,638 44.3 35 SCANNED OCT 7 2 2004 http://kodiak.anchortown. unocal.com/ da/templates/positionLog.asp 10/20/2004 "" ~, Page 3 of3 9,000 6,912 -6,806 2,017 4,865 210,401 2,495,694 44.8 35 9,100 6,982 -6,876 2,060 4,922 210,444 2,495,751 45.5 36 9,200 7,052 -6,946 2,103 4,979 210,487 2,495,808 45.7 36 9,300 7,122 -7,016 2,146 5,036 210,530 2,495,865 46.0 36 9,400 7,191 -7,085 2,191 5,093 210,575 2,495,922 46.7 36 9,500 7,259 -7,153 2,235 5,150 210,619 2,495,979 46.9 37 9,600 7,328 -7,222 2,280 5,208 210,664 2,496,037 46.6 37 9,700 7,397 -7,291 2,325 5,265 210,709 2,496,094 46.0 37 9,800 7,467 -7,361 2,369 5,321 210,753 2,496,150 45.3 37 9,900 7,538 -7,432 2,413 5,375 210,797 2,496,204 43.7 37 10,000 7,611 -7,505 2,456 5,429 210,840 2,496,258 42.8 38 10,100 7,685 -7,579 2,499 5,481 210,883 2,496,310 41.4 38 10,200 7,761 -7,655 2,540 5,532 210,924 2,496,361 40.6 38 10,300 7,837 -7,731 2,580 5,581 210,964 2,496,410 39.0 38 10,400 7,916 -7,810 2,619 5,629 211,003 2,496,458 37.5 38 10,500 7,996 -7,890 2,658 5,675 211,042 2,496,504 36.0 39 10,600 8,077 -7,971 2,695 5,719 211,079 2,496,548 34.8 39 10,700 8,160 -8,054 2,732 5,763 211,116 2,496,592 34.4 38 10,800 8,243 -8,137 2,767 5,806 211,151 2,496,635 33.8 37 10,900 8,326 -8,220 2,802 5,850 211,186 2,496,679 33.8 37 11,000 8,409 -8,303 2,836 5,893 211,220 2,496,722 33.0 38 11,100 8,493 -8,387 2,871 5,935 211,255 2,496,764 33.1 38 11,200 8,576 -8,470 2,907 5,978 211,291 2,496,807 34.5 38 11,300 8,658 -8,552 2,943 6,022 211,327 2,496,851 36.3 38 11,400 8,738 -8,632 2,982 6,068 211,366 2,496,897 37.5 38 11,500 8,817 -8,711 3,021 6,116 211,405 2,496,945 37.9 38 11,600 8,896 -8,790 3,060 6,163 211,444 2,496,992 37.9 38 11,700 8,975 -8,869 3,100 6,210 211,484 2,497,039 37.8 39 11,800 9,054 -8,948 3,139 6,255 211,523 2,497,084 36.5 41 11,900 9,135 -9,029 3,179 6,299 211,563 2,497,128 36.0 41 12,000 9,216 -9,110 3,219 6,341 211,603 2,497,170 35.1 42 12,100 9,298 -9,192 3,259 6,383 211,643 2,497,212 35.5 42 12,200 9,379 -9,273 3,299 6,425 211,683 2,497,254 36.1 42 12,300 9,459 -9,353 3,340 6,469 211,724 2,497,298 37.2 42 12,400 9,539 -9,433 3,382 6,513 211,766 2,497,342 37.8 42 12,500 9,618 -9,512 3,425 6,557 211,809 2,497,386 38.2 43 12,600 9,696 -9,590 3,469 6,601 211,853 2,497,430 38.4 44 12,700 9,774 -9,668 3,513 6,644 211,897 2,497,473 38.5 44 12,739 9,805 -9,699 3,531 6,661 211,915 2,497,490 38.6 44 12,830 9,876 -9,770 3,571 6,701 211,955 2,497,530 38.6 44 SCANNED OCT 17 2 2004 http://kodiak.anchortown. unocal.com/ da/templates/positionLog.asp 10/20/2004 .FW: Question - D-42 ESP downhole securing & suspension Subject: FW: Question - D-42 ESP downhole securing & suspension From: "Bowen, Jerry" <jbowen@unocal.com> Date: Tue, 19 Oct 2004 14:44:45 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> C'\ .\ C\ \..) ~~<>. \ ~'\.,. ~ "'" ~ "'" (èß \,<ë.l'.cJ \- \-... '\ "> ~ Ct.l ~ ('C.¡'¡ rs Tom;\>ö>CS;\~ \ ~ S\~~ -\,~t;-~, ~~\\ ~~\~, f'P- \ '6. ~~~~ 'ÑÛ-~ \~*""~ð~~ -\€.~ \~ \..' . Tim re-read you're earlier e-mail, reaa ~t~en ~lie .lines ~nJ~ecide~to W'\~ ~ ~ . * go ah~ad and approve the AFE. We will send you a form 10-403 for well 0 O<b.-o... ,,~<\.CS D\ (\~ D-42 ln a week or so. ~ \ ~ 0 Thanks. Th'( ~<$ \X.-~~t.Ù~c..J ~ \\-~\e:'?~\ \\ \> ~~~\£ Jerry G7.D\<.é fJ~~ \ \-"'- \h-.e l).Jé\.\, ~'1 c:9-{\~~~ -----Original Message----- (À~\>\Ù~Q \ -\0 "ð,,\\\'- O-\----\-~~ \\: e-<-<ê \ bo-t--tk 'VJé\.\ From: Bowen, Jerry r--(tJr~\~s ~\c1.P Q::... Sent: Tuesday, October 19,2004 1:47 PM ;-L- \l \ _. \ n /1 \-~_\t _1 t To: 'Thomas Maunder' \ \"V.-~,,\ V?-S Q o..~<éJ-\.-\-;; "-~\ r,~y Y'%\6 Subject: RE: Question - D-42 ESP downhole securing & suspension ~V\~~~~JD~\\ CA~ 'D1è ~~. \~ ~",,^-\:x:~lS. ~~'è()'\- '1 Torn; ~\\ 5(\'Ð~~ \ ~~\-S \-~ ~\~S~~ ~~\\;t:~'M(è~~ ~ - Dave Cole would love to drill some oil wells in the Cook Inlet. d'S \ \ ~ ~~)" \ )rr' Unfortunately, the bulk of our (manpower and financial) resources are' '" )"(.J~ focused on meeting the Enstar and Agrium gas contracts at present. ~\\ According to Dave, no money has been budgeted in 2004 or 2005 for TBU ~~ ~~û~~- G-zone or Hemlock drilling proj~cts (or expensive, fishing jobs). Some ~\~ . ~~ money was budgeted for ESP repalrs and/or converSlons, but D-42 was not , ~ ~ one of them. Although a positive payout can be calculated, based only d5 \ \D (r.' (' ~"f ~ on the expected G-zone production (the Hemlock apparently watered out at ,. ~)~,)~ th~s l~cation), the R?I does not current~y, mee~ the corpor<;tte thre~hold *'-\~~ ~«.\ \ \ <"::> CJ crlterla compared to lnvestment opportunltles ln other buslness unlts. ~ \. - \" . "\ We will have to wait for the oil price to surge a bit higher. ~~\ ~(k~~~~ Confidentially, we do hope to drill a couple of wells offshore next ~~\\~~ year, but we are looking for more than we would get by re-drilling D-42. ~t\\()~)'\')~ Before my new boss, Tim Brandenburg, will approve the AFE, he wants to know if the AOGCC accepts our viewpoints and (probably) will approve a Sundry Notice (form 10-403) to recover the completion, set a CIBP above the fish and dump bail 25-30' of 'cement. I realize that nothing is official until it's signed. x:.- ~~{)~~ C-f~~ J! ~CC'" \ ~ '-Jt~ \- , , ~?¡vto(~~-o\ securing & suspenslon Thanks. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom .maunder@ad.rnin.state.ak.us] Sent: Tuesday, October 19, 2004 9:27 AM To: Bowen, Jerry Subject: Re: Question - D-42 ESP downhole Jerry, Your message looks interesting. It appears that some positive analysis and discussion may have taken place at your shop. Is there a potential of some hole making work being proposed?? Look forward to hearing from you. Tom Maunder, PE AOGCC Bowen, Jerry wrote: SCANNED OCT '1 2 2004 1~5 10/22/2004 1 :43 PM # FW: Qöestion - D-42 ESP downhole securing & suspension Tom; Based on your comment, we have taken another look at our plans to make sure we are doing the right thing. Please consider the following points: 1. We suffered a lengthy unsuccessful fishing job on well D-17. Based on that experience, we aborted the attempt to add G-zone perfs in well D-42 in March 2003 when it became evident that recovery of the 2500' long fish was a high cost and high risk endeavor. The last seven joints of tubing recovered from well D-42 were severely corroded, and the tubing parted with no significant overpull. In addition, the inside of the remaining fish is plugged with multiple S-line fishes which are expected to complicate the effort. 2. The cost to fish the well clean and run an ESP is estimated to be in the range of $2M, with a mechanical P~S in the range of 25% - 50%. 3. The estimated cost to re-drill is estimated to be in the range of $3.OM including additional rig preparation costs, with a mechanical POS of 90%. 4. The lower risk weighted cost of the re-drill case, combined with a more predictable outcome, leads us to believe the best option to recover G-zone reserves at this location is to re-drill the bottom 3000' of hole. Dave Cole and I will call you in a few minutes to discuss. Thanks. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, October 08, 2004 3:40 PM To: Bowen, Jerry Cc: Jim Regg Subject: Re: Question - D-42 ESP downhole securing & suspension Jerry, Based on the information available regarding this well Jim and I are of the opinion that setting the retainer and placing the cement on it as you propose while technically feasible is likely not the prudent approach from a conservation point of view. As you noted, part of the original workover in 2003 included perforating the G zone. That part of the workover was not accomplished due to the fish and only one run was performed in an attempt to get it. In order to consider the retainer and cement, Unocal will need to present some economic justification that it is not economically justified to attempt to re-complete in the G zone as originally planned. If the economics aren't there, then it appears that mechanically, the retainer and cement placed as you propose would satisfy the requirements of 20 AAC 25.112. As I indicated, I will be out of pocket next week. If you wish to discuss, please contact Jim Regg at 793-1236. Tom Maunder, PE AOGCC SCANNED OCT? 2 2004 2of5 10/22/2004 1:43 PM . FW: Question - D-42 ESP downhole securing & suspension Bowen, Jerry wrote: Tom, Any decision whether suspending and/or abandoning the completion in D-42 with a CIBP & dump-bailed cement will be acceptable? Thanks for your help with this. Jerry -----Original Message----- From: Bowen, Jerry Sent: Wednesday, October 06, 2004 4:22 PM To: 'Thomas Maunder' Subject: Question - D-42 ESP downhole securing & suspension Tom; Please refer to the attached graph. The 9 5/8" SIP in well D-42 is 520 psi. The 13 3/8" SIP in well D-42 is 150 psi. A slow pressure build-up has occurred over the past year. Not sure if the gas lift inlet valve has a slight leak or if there is some seepage >from downhole. Presumably, the buildup rates would again be slow if bled to 0 psi. One could jump to the conclusion that the 13 3/8" SIP is increasing due to the slowly ballooning 9 5/8" casing, but there does not appear to be direct communication between the two. They didn't give me a SITP. Will go back and get it if you still need it. The well's most recent No-Flow test was in June 2000. Please e-mail if additional info is needed. Thanks. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, OctobOero,,, 06, 2004 12: 01 PM ..0_..00. To: Bowen, Jerry Subject: Re: Question - D-47 ESP downhole securing & suspension Jerry, What are Is there If there levels?? Tom the surface pressures on the tubing and IA?? any pressure on any of the other annuli?? is no surface pressure on tubing or IA, do you know the fluid Thanks, 30f5 SCANNED OCT 722004. 10/22/2004 1 :43 PM . F.W: Question - D-42 ESP downhole securing & suspension Thomas Maunder wrote: Jerry, I will have a look at this. Tom Bowen, Jerry wrote: Tom, As you are aware, we submitted a form 10-403 to replace the failed ESP in well D-47 within the next few weeks. Well D-42 is another well with a failed ESP. It is located in the same leg of the platform and is immediately adjacent to well D-47. Well D-42 performed miserably on ESP, and we can not justify further attempts to make it profitable at this time. Therefore, the Asset Team and I have recommended skidding over this well to: 1. Recover the ESP completion (before it becomes corroded and useless). 2. Set a CIBP above the fish & perforations. 3. Dump bail 20-30' cement. 3. Pressure test the wellbore & suspend with a short kill string & dryhole tree. I understand that cost can not be a factor in your interpretation of the rules. However, it is a huge factor in our world the cost, so that it is mostly covered by the equipment value, is important if we are to receive management and approval. I estimate there is only a 50/50 chance this approved at this point. Minimizing salvage partner AFE will be Do you see a problem with this plan? Specifically, would we be required to spend extra money to set a retainer and perform a high pressure squeeze downward around the fish? Thanks. *Jerry F. Bowen, P.E.* *Advising Drilling Engineer* Office: 907-263-7640 Cell: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 «D-42Schematic20030417.pdf» SCANNED OCl 7 2 2D04 40f5 10/22/2004 1 :43 PN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: x Alter casing: /Repair well: Other: Run ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' IRT above MSL feet 3. Address Exploratory: ~ 7. Unit or Property name Stratigraphic: , P.O. Box 196247 Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface Leg A-2, Conductor 7 8. Well number 749' FSL & 1125' FWL Sec. 6, T8N, IR13W, SM D-42 At top of productive interval 9. Permit number/approval number 3311' FWL & 1886' FSL Sec. 32, T9N, IR13W, SM 83-53/303-046 At effective depth 10. APl number 50- 733-20205-01 At total depth 11. Field/Pool 3660' FWL & 2661' FSL Sec. 32, TgN, R13W, SM McArthur River Field 12. Present well condition summary Total depth: measured 12,830' feet Plugs (measured) true vertical 9,876' feet Effective depth: measured 12,749' feet Junk (measured) See attached Schematic true vertical 9,811' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 20" Surface 3000' 13-3/8" 1000 sx 3000' 2601' Intermediate 10510' 9-5/8" 1900 sx 10510' 8033' Production Liner 2652' 7" 750 sx 12,828' 9870' Perforation depth: measured 11984'- 12022', 12070' - 12084' (squeezed), 12160' - 12280', 12280'-12370', 12400' - 12520' true vertical 9,202' - 9,233', 9,272' - 9,284', 9,345' - 9,442', 9,442' - 9,514', 9,537' - 9,632' Tubing (size, grade, and measured depth) 4-1/2" 12.6~ L-80 BTC MOD to 9,279' RECEIVED Packers and SSSV (type and measured depth) none APR ?, .q ?003 13. Stimulation or cement squeeze summary ..... none Intervals treated (measured) Alaska 0il & Gas Cons. Commission none Anchorage Treatment description including volumes used and final pressure none 14. RePresentative Daily Avera,qe ProdUction or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 320 126 5104 1081 160 Subsequent to operation 148 359 8553 118 120 15. Attachments: Schematic X 16. Status of well classification as: Copies of Logs and Surveys run: Dali)/Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Si~lne~'~ ~/~l Title: Drillin~t Engineer Date: 4/25/2003 FormlO~(~/l~/~.~.. APR~[J ,[l~J' ORIGINAL SUBMIT IN DUPLICATE Technical Schematic Dolly Varden Platform, D-42 last revised 4/25/03 by Diane Dunham, Unocal Alaska B-3 B-4 B~5 Casing and Tubing Detail Size Weight Grade Conn ToD Btm 13-3/8" 61 K-55 BTC 0 3,000 9-5/8" 47 N-80 BTC 0 10,510 Liner 7" 29 N-80 & P-110 BTC 10,176 12,830 Tubin,9 4-1/2" 12.6 L-80 BTC-Mod 0 9,179 Jewelry No. Depth (ft) ID Item I 40.97 -- 11" x 4-1/2" BTC CIW DCB Tb~] Hgr 2 2,556 3.833 4-1/2" GLM #1, RK Latch and R-2 Valve 3 3,938 3.833 4-1/2" GLM #2, RK Latch and R-2 Valve 4 5,056 3.833 4-1/2" GLM #3, RK Latch and R-2 Valve 5 5,989 ~, 3.833 4-1/2" GLM #~, RK Latch and R-2 Valve 6 6,735 3.833 4-1/2" GLM #5, RK Latch and R-2 Valve 7 7,305 3.833 4-1/2" GLM #6, RK Latch and R-2 Valve 8 7,668 3.833 4-1/2" GLM #7, RK Latch and R-2 Valve 9 8,435 3.833 4-1/2" GLM #8, RK Latch and Oriface Valve 10 9,178 3.958 4-1/2", 12.6#, L-80 BTC SCC Pup Joint 11 9,188 -- 600 HP (725 Series) ESP Assembly 12 9,279 -- Alumnium Anode (end of assembly) Fish Depth Fish 9~412' Parted 4-1/2" tubing 9,587' Mandre~ #~w/Glesco valee w/20/64" port w/RK latch. 10,2821 Mandrel #8 w/Glesco valve w/24/64" port w/RK la[ch. 10~906' Mandrel #9 w/Glesco valve w/24/64" port w/RK latch. 11,876' Mandrel #11 wi Daniets valve w/1/2~ orifice. 11.891' Baker Locator Seal Assy, 10' long, 11,8921 Baker "FB-I" Pkr, size 80-40. 413~8-8511 11,895' Baker Seal Bore Ext,, 10' long, size 80-40 Crossover tl,905' Baker Millout Exl. 5.40' long. Crossover 3-1/'Z' X 10' Pup Joint 11,921 Otis "XN" Nipple, size 2.81 3-112" X 10' Pup Joint. 11,933' Baker Shear-out Sub. 12,493' WLM Fill Tagged w/a 2.50" GR 12,400' DIL Fill Tagged w/2-1/8" strip guns (prior to the scale treatment 12,530' WLM 20' 2-1/8" Strip Gun 12,493' WLM (2} GLV's 9628' WLM Tool Stdng, DD Bailer, Cutter Bar 9600' WLM Tool Sffing, LIB 9586' WLM Cutter Bar, Too~ String (fishing tools) 9586' WLM Cutter Bar 12,493' WLM (2) GLV's Perforations Zone Top TD Bottom TD Condition B-1 11 ~984 12,022 4 SPF B-2 12,046 12,122 Squeezed B-3 12,160 12,280 4 SPF B-4 12,280 12,390 4 SPF B~5 12,400 12,520 4 SPF PBTD @ 12,749' TD @ 12,830' Max Hole Angle: 47 degrees RKB to TBG Head: 106.90' Tree connection: 4-116" 5,000# Unocal Alaska Business Unit Drilling Department Dolly Varden Well D-42 ESP Conversion Daily Summary 3/24/03 Skid rig to the D-42 slot. R/D the flowlines and N/D tree. 3/25/03 N/U BOPE and test to 250/3000 psi OK. M/U landing joint and 6nseat tubing hanger - observe for losses. 3/26/03 Mix and spot 50 bbl LCM pill. Pull and VD 4-1/2"tubing completion. Left 7 ea. Joints of 4-1/2" tubing, 1 ea. 4-1/2" GLM and all of the 3-1/2" tubing completion in the hole - estimated TOF at 9,347' 3/27/03 P/U Rolling Dog overshot and RIH. 9,412'. POOH with no recovery. CBU with 3% KCL (8.6 ppg) and wash over fish to 3/28/03 ~M/U 8-1/2" BHA clean-out assembly and olean-out to 9,300' with 3% KCL (8.6 ppg) brine. POOH. 3/29/03 R/U and run 4-1/2" tubing ESP completion. 3/30/03 Continue running ESP completion. P/U tubing hanger. 3/31/03 Land and test tubing hanger. N/D BOPE and N/U and test tree. Release rig. 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: X Variance: Perforate: X Other: Install ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X RT above MSL 106 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number Dolly Varden D-42 Leg A-2, Conductor 7, Dolly Varden Platform 9. Permit num,~ 749' FSL, 1125' FWL, Sec. 6-T8N-R13W, SM 83-53 v ~ ¢' ..~ 10. APl number 50- 733-20205-01 11. F~eld/Pool McArthur River 12. Present well condition summary Total depth: measured 12,830'~'~' ~"et true vertical 9,876' *.~feet Effective depth: measured 12,749' feet Tagged Fill (measured) 12,493' true vertical 9,811' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 20" Surface 2,558' 13-3/8" 1,000 sx 3,000' 2,601' Intermediate 7,991' 9-5/8" 1,900 sx 10,510' 8,033' Production Liner 2,494' 7" 820 sx 12,063' 10,077' Perforation depth: measured 11984' - 12022', 12070' - 12084' (squeezed), 12160' - 12280', 12280' -12370', 12400' - 12520' true vertical 9,202' - 9,233', 9,272' - 9,284', 9,345' - 9,442', 9,442' - 9,514', 9,537' - 9,632' Tubing (size, grade, and measured depth) 4-1/2" 12.6# BTC tubing to 10142' & 3-1/2" 9.3 ppf L-80, EUE 8rd, 11,934' Packers and SSSV (type and measured depth) Baker F-1 Pkr @ 11,892' & Camco 4-1/2" TRDP-4A SSSV @ 326' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 3/15/2003 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of appr~ Date approved Service: ESP Conversion Si~e¢l: ~, I..~,~ ~,r.~Larry Buster Title: Drilling Engineer Date: J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represent.a, tive may witness ~~'~,. ~.~O '~ f~-~ IApproval No. . Plug integrity BOP Test *'t(, Location clearance .... Mechanical Integrity Test ~u'bsequent form required 10- ~[(~-~. ~ ~' ~"-~ ~ ~ ~' _ Alaska 0i~ Approved by order of the Commissioner ~ L ~;" Commissioner Date Form 10-403 Rev 06/15/88 DOLLY VARDEN D-42 ESP CONVERSION WORKOVER PROCEDURE ISkid Rig ISkid rig to the D-42 Well. I I(Bleed offtbg & csg pressure & kill well prior to skid) IPull Completion 1 2 3 4 5 6 Install BPV, N/D Tree and flow line. N/U BOPE, replace BPV w/2-way ck valve - test blind ram to 3,000/250 psi Retrieve 2-way check valve - m/u ldg jt. Test BOPE to 3,000/250 psi B/O hold down screw on tbg hanger. Pull seal assy out of production packer POOH and L/D 4-1/2" x 3-1/2" completion string M/U clean-out assy. RIH and clean out casing. Perforate 7 IM/U TCP Gun Assy. RIH, correlate with E-Line, set packer in 9-5/8" csg. 8 ITest 9-5/8" casing to 1500 psi. I 9 IFire TCP guns to perforate G-Zone. Circulate well and POOH. IRun Completion 10 IM/u ESP Motor Assembly and RIH with 4-1/2" tubing. 11 IMU hanger, make splice and land hanger. 12 Ilnstall BPV. i 13 INipple down BOPE 114 Ilnstall & test tree to 3000 psi DOLLY VARDEN D-42 ESP CONVERSION RKB to TBG Heed = 106.90' PBTD = 12,749' TD = 12,830' MAX HOLE ANGLE = 47 ? BEFORE WLM PERFORATION DATA ZONE TOP lt'rM AMT SPF DATE AFTER RKB to TBG Head = 106.90' New Peffs: 11455 11475 11520 11560 B4 PBTD = 12,749' TD = 12,830' MAX HOLE ANGLE = 47 ? Dolly Varden D-42 Workover to Add G-Zone Perfs & Convert to ESP Unocal Alaska requests Sundry Approval to add G-zone perforations to the existing Hemlock perforations during the upcoming ESP conversion workover of Dolly Varden Well D-42. Specifically, Unocal Alaska requests permission to run a 4 1/2" ESP completion without a; 1. subsurface safety valve (20 ACC 25.265) 2. production packer (20 ACC 25.200). Justification: 1. The current gas lifted Hemlock completion passed a No-Flow test on June 16, 2000. 2. The G-Zone is known to be partially depleted and is expected to be a thief zone with a SIBHP of 2,595 psi at -8,850'SS. The well is expected to produce +9000 BFPD with a high watercut (+/- 90 to 95%) after the ESP is installed. Therefore, reservoir pressure in the vicinity of the subject wellbore is predicted to decline, thus the potential for unassisted flow is predicted to decrease. Dolly Varden Stack up D - 42 Table Hydr8 5M 4.54~ 1/16" 5M Foster HCR Valve 1116" 5M Manuat gate valve 1116" 5M Manual gate Kill tine t/t6" 5M Manual gate Kill line Btm of Trolly beam 1.15 Top of drill deck 1860 to tb9 spool 23' 2.0 spacer spool 2.0 spacer spool 1.5' 13 5/8" x 11" xo spool Dolly Static BHPs from Platform Shut Down Beginning 9/22/01 G-Zone Pressures Hal Martin Wells G-Zone Benches Shut In Period Datum Pressure D-3RD2 G-2.3, 4 13 Days 2518 psia D-4RD G-2, 3.4, 5.6 16 Days 3017 psia 1~-5RD No Pressure Taken Yet '~ D-26 G-2, 3, 4 11 Days 2520 psia D-31RD G-2, 3, 4 12 Days 2595 psia D-32 G-2, 3, 4 12 Days 3225 psia D-4.6 G-2, 3, 4 15 Days 2984 psia Rate of A Pressure at End of Survey 1.16 psi/hr 0.40 psi/hr 0.34 psi/hr 0.78 psi/hr 0.26 psi/hr 0.50 psi/hr Notes: Datum at -8850' SS. Pressure Gradient Between Bottom ,Two Survey Points 0.325 psi/ft 0.360 psi/ft 0.428 psi/ft 0.325 psi/ft 0,349 psi/ft 0.427 psi/ft MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan seamount, Commissioner r~ · Blair Wondzell, P. I. Supervisor FROM: John Crisp? ~ ~. SUBJECT: Petroleum In~ij~ector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due t© header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthUr River Field. 24 wells, 57 components tested, 3 failures Witnessed.' 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON"CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Submitted By: John Crisp Date: 6/22/00 Operator Rep: Mark Murietta Field/Unit/Pad: Mc.Arthur Ry. / Dolly Vardc AOGCC Rep: John Crisp Separator psi: LPS 110 HPS Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 801 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740: 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830! 110 80 80 P P OIL ~~ 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 90 Day Remarks: 'Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jcl ALASKA OIL AND GAS CONSERVATION COPlPIISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 20, 2000 Chris Meyers/Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification MRF Wells D-25R and D-42 Gentleman: On June 16, 2000 our inspector Lou Grimaldi witnessed "no-flow test on UNOCAL's McArthur River Field TBU wells D-25R and D-42. Prior to his arrival, both wells had been routed to the "Well Clean" tank, which is about 2 psig back pressure. Both wells had bled down when Lou arrived. He observed both wells for several hours and recorded gas rates far below the "no-flow" limit of 900 scf/hr. He noted rates of 190 to 600 scf/hr on D-25R and 180 to 275 scf/hr on D-42. Neither well had any fluid production. He recommended that "no-flow" status be given to both wells. McArthur River Field TBU wells D-25R (178-087) and D-42 (183-053) meet the criteria of"no- flow" performance test and as such, are considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A) they are not required to have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Sincerely, Blair E. Wondzell ~' Sr. Petroleum Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Chairman DATE: June 16, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi¢-~ SUBJECT: Petroleum In%pector No Flow Verification Unocal, Dolly Varden McArthur River Field D-42 PTD#183-053 D-25RD PTD#178-087 NON-CONFIDENTIAL Friday, June 16, 2000; I traveled to Unocal's Dolly Varden platform to verify the No- Flow status of wells D-42 and D-25 in the McArthur river field. I had been in contact with Greg Geller and Dave Kerkvleit (production operators) over the past two days checking on the wells status. I arrived to find both wells routed to the "Well Clean" tank which is the lowest back-pressure separator (approx. 2 psi) available on the platform. These wells had been bled down and both had negligible pressure on there production casing. At first we checked the gas flow using a small gas meter, which was rigged up using a ~ high pressure hose. I felt we would lose flow due to the length of the hose and asked it be removed from the inlet of the meter. Greg Geller (Lead Operator) complied and mounted the meter directly to the cap of the wellhead. I feel this gave a much more accurate flow rate reading. D-42 · 0900 check gas flow <180 scf/hr, install 100 psi gauge and shut-in well @2 psi. · 0925~SI @5 psi. · 1010-SI @11 psi. · 1045-SI @15 psi, bled to 10 psi (fast), shut-in flow line. · 1100-S1@13 psi, bleed to 2 psi. Check flow 275 scl/hr. Put well back to production. D-25 · 0910-Check gas flow 190 scf/hr, install 100 psi gauge and Si well @ 3 psi. · 1005-SI @Tpsi, check gas 300 scl, SI. · 1040-SI @9 psi. · 1055-SI @9 psi, bleed to 5 psi (fast). Check flow 600 scf/hr. Put well back to production Both wells had no fluid production and slight gas flow but were below our 900 SCF maximum. I recommend these wells be granted No-Flow status. Summary: I verified the No-Flow conditions on Unocals wells D-42 and D-25RD in the McArthur River Field, Both wells passed. Cc; Bill Smith (Unocal Dolly Varden foreman) 1 No Flow TBU UNOCAL D-25 D-42 6-16-00 LG1 Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL( February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Dolly Varden Platform, Well D-42 APl Number 50-733-20205-01 This is to inform you that Unocal withdraws the Sundry Request to perforate, with Approval No. 93-236. Please cancel the Request for sundry Approval Very truly yours, Candace Williams ?,.:.:!) tj Li-LI ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR .... 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7,542 June15,1994 Russell Schmidt Union Oil Company of California P O Box 190247 Anchorage, Alaska 99519 RE: 81-0099 83-0O53 85-0311 SOLDOTNA CREEK UNIT 31-08 TRADING BAY UNIT D-42 TRADING BAY UNIT D-43RD Dear Mr. Schmidt, A review of our well records and correspondence indicates the referenced wells are missing directional Surveys. This requirement was indicated on the permit to drill. The survey should be submitted with the form 10-407 Well Completion Report. This is a compliance check I conducted for missing required data as stated in 20 AAC 25.050 (f). This data has not previously been requested. If you have the surveys, please make a copy and mail to me to correct this problem and update our well files. Sincerely, Steve McMains Statistical Technician STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~,~GION REPORT OF SUNDRY WELL OPERATIONS · Operations Performed: Operations Shutdownm Stimulate m Pluggingm Pull Tubing Alter Casing Repair Well Perforate Other Scale Cleanout 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5· Type of Well: Development Exploratory Stratig rap hic Service 4. Location of well at surface 749' FSL, 1,125' FWL, Sec. 6-8N-13W-SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32-9N-13W-SM At effective depth Leg A-2 Cond. #7, Dolly Varden Platfrom At total depth 3,660' FWL, 2,661' FSL, Sec. 32-9N-13W-SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-42 9. Permit number/approval number 83-53 / 91-190 0. APl number 50- 733-20205-01 1. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 2,830' feet 9,870' feet 12,749' feet 9,811' feet Length Plugs (measured) Junk (measured) Size Cemented 3,000' 13-3/8" 1,000 sx 10,510' 9-5/8" 1,900 sx 2,652' 7" 750 sx See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' Packers and SSSV (type and measured depth) -, None None Measured depth True vertical depth 3,000' 2,601' 10,510' 8,033' 12,828' 9,870' RECEIVED Camco 4-1/2" TRDP - 4A SCSSV @326' MD; Baker F-1 Prod Pkr (size 85-40) w/SBE @11,892' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 102 J' 152 575 1,110 Subsequent to operation 300 '/j 627 1,360 1,040 160 130 ! 15. Attachments 116. Status of well classification as: I Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas Signed j Title Suspended Service Date '~/~h~'' Form 10-404 Rev 06115/88 SUBMIT IN DUPLICATE Attachment #1 Well D-42 Perforations B-1 B-2 B-4 B-5 11,984'- 12,070'- 12,280'- 12,400'- 12,022' 12,084' 12,370' 12;520' 9,202'- 9,272'- 9,442'- 9,537'- 9,233' 9,284' 9,514' 9,632' [SUN DRY9.XLW] Perf Database DAILY WELL OPERATIONS D-42 10/2/91 Held Operational and Safety meeting. RU CTU. PT 1/2" CT, lines and lub to 5000 psi. OK. RIH w/ well flowing. Started pumping at 10,100', 78 gpm, 1400 psi. Drilled through tbg tail @ 11,934'. Average drilling was at 1.8 BPM, 2600-3000 psi using FIW w/ 3/4 gal/lO00 gal FR26L. Several 10 bbl SCD sweeps were pumped. Reamed hole at 20 fpm from 10,100' through tbg tail. Circ 30 bbl polymer sweep followed by 50 bbl 24 KC1 -- FIW at 12,000'. RIH to 12,300'. POOH w/ CT. SDFN. 10/3/91 PT lines. CT and lub to 4000 psi. OK. RIH w/ well flowing, pumping 1/4 BPM to 10,100': RIH 0 40 FPM. Slow down across mandrels to 15 FPM to 11,890'. POOH. RIH. Made total of 4 passes across mandrels. POOH. RD. Return well to production. H: \wp\NE L LOPS\D42 STATE OF ALASKA ALAS, ~ OIL AND GAS CONSERVATION COMN,,..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing Change approv---~ program Pull Tubing Variance__ 2. Name of Operator I 5. Type of Well: UNOCAL (Marathon Oil Company- Sub Operator) I Development X Exploratory __ 3. Address Stratigraphic M P.O. Box 196247 Anchorage, AK 99519 Service __ 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platfrom 749' FSL, 1,125' FWL, Sec. 6-8N-13W-SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32-9N-13W-SM At effective depth ORIGINAL At total depth 3,660' FWL, 2,661' FSL, Sec. 32-gN-13W-SM Suspend Operation shutdown Re-enter suspended well Repair welt Plugging -- Time extension Stimulat-~' P-"~rforate X Othe'-~' 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-42 9. Permit number/approval number 83-53 O. APl number 50- 733-20205-01 1. Field/Pool Hemlock feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 2,830' feet Plugs (measured) 9,870' feet 1 2,749' feet Junk (measured) 9,81 1' feet Length Size Cemented 3,000' 13-3/8" 1,000 sx 10,510' 9-5/8" 1,900 sx 2,652' 7" 750 sx See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' Packers and $SSV (type and measured depth) None None Measured depth True vertical depth 3,000' 2,601' 10,510' 8,033' 12,828' 9,870' s E P - 1993 Alaska 0ii & Gas Cons. C0mm~SSi0n Anchorage Camco 4-1/2" TRDP - 4A SCSSV @326' MD; Baker F-1 Prod Pkr (size 85-40) w/SBE @11,892' MD 13. Attachments Description summary of proposal X Detailed operations program__ BOP sketch X Estimated date of commencing operation Sept. 5, 1993 If proposal was verbally approved Name of ap~rover I hereby c~ th~hl i°~ ~e(~t Signed Date approved 15. Statis of well classification as: Oil X Gas Service to the best of my knowledge. Suspended __ 17. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commision Form 10-403 Rev 06/15/88 Original Signed By [')avid W_ ,inhn.ston SUBMIT IN TRIPLICATE IApproval No.? ,,~ "--~,~-~ ApproveQ Copy Returned Commissioner Date 7/~'/ ~ Attachment #1 Well D-42 Perforations B-1 B-2 B-3 B-4 B-5 11,984'- 12,070'- 12,160'- 12,280'- 12,400'- 12,022' 12,084' 12,280' 12,370' 12,520' 9,202'- 9,272'- 9,345'- 9,442'- 9,537'- 9,233' 9,284' 9,442' 9,514' 9,632' RECEIVED S E P - ~ 199;5 Alaska Oil .& Gas (3oDs. CommissioD ;Anchorage [SUN DRYg.XLW] Perf Database REPERF PROCEDURE D-42 · e e Obtain a 24-hour test with a minimum of four (4) W.C.'s. Skid rig 77 over D-42. Hold safety/environmental meeting. RU E-Line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, complete the reperforating checklist. Recomplete the perforating checklist w/ guns at 1,000' when POOH· SI well to RIH & POOH. RIH with 2-1/8" phased retrievable strip guns, 4 SPF, and perforate the following intervals underbalanced: RUN BENCH INTERVAL (DIL) FOOTAGE I HB-3 12,185' - 12,218' 33' 2 HB-1 11,984' - 12,011' 27' RD E-Line unit. Return well to production and obtain well tests. H: \wp\WLPRO\D42 MARATHON OIL COMPANY TRADING BAY UNIT DOLLY VANDEN WELL D-42 Completed 4/90 405' measurements ore RKB to top of equipment. Completion Str`ing: 326' CAMCO 4.5' TRDP-4A SCSSV. (3.813' I.D.) 0'-10,142' 4.5' L-80, Butt Tb9 w/ AB Mod Cplg. X/13 4.5' x 3.5'. 10,142'-11,934' 3.5' L-80, EUE 8RD Tb9. 33' Conductor` 3000' 13-3/8', 68~, K-55 Butt. Cs9. 10,510' 9-5/8', 47~, N-80 ~ P-110 Butt. Csg. Gas liP% mandrels 1-7 ore CAMCD 4.5' HMG, 8-11 are CAMCD 3.5' MMG-P. Gas LiFt Valves are 1-1/2' w/ RK Latches. 10,176' 7' Liner- Top Depth Valve 2662' 1 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' 10 11876' 11 Type La¢ch DanieLs RK DanieLs RI< Por't Size 1P/64 12/64 12/64 16/64 16/64 P0/64 20/64 24/64 a4/64 28/64 32/64 OriFice B-1 B-2 B-3 B-4 B-5 11,892' 11,934' F-1 Prod Pkr size 85-40 w/SBE; Seal Bore/Mil[out X-ovep; NitLout Ext; Mil[out/EUE 8RD X-over`; 10' pup, I.D. = 2.75' - Fltls XN Nippte; 10' pup. out sub/WL entr`y guide. REEEIVED Failed squeeze (4/1P/90) Leaking inter'vat @ 12,070'-12,084' PERFBRATED INTERVALS Zone In'l:ePvot SPF SEP - 199 ~ p¼asln9 B-1 11,984'-12,028' 4 0 B-2 12,046'-1;~,122' 4 0 B-3 1L0,160'--12,~80' 4 0 B-4 1P,~80'-1~,370' 4 0 B-5 12,400'-12,520' 4 0 Alaska Oil & Gas Cons. Comm~ssiot~ Anchorage Date 7/24/90 Cmt Squz 10/8/91 6/84/90 6/21/90 Tagged ¢iLt ~ 12,556' WLN 11-17-91 PBTD @ i2,749' TD ~ 12,830' 1P, SPS' 7' Pg~, N-80 Butt. Linen Revision Date: 11/21/91 Revised By: JDM/evo Reason: Change out GLV's Ppevious Revision, 11/04/91 ~-,~OLLY VARDEN Pi ..... ~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) , OR BRiCAT · 4'~1~'~.6'~. 5000 psi CHISTMAS TREE POSITIVE CHOKE S E P - Alaska OJJ & Gas CoJ~s. Anch0ra~ ~ 2' 5000 psi ~.__-- 2' 3000 psi L~ 13 3/8' CASING ALASKA OIL AND GAS CONSERVATION CO~I~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Ddiling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, . · In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. ; To be in compliance with AS'20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversatio_ns concerning the subject, it had been_explained to me that either ARCO or Marathon had been th~operator on the majodty of the work proposed; hoWever, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application-of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application on file can'be marked accordingly. . · · ~tatistical 'l'ect~nician .. ~) pfinled on recycled paper b y . Well Permit No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 '83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit Description Perforate 2-91 Perforate 5-91 Workove~ 4~91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 67-71 3/15-91, 91-086 G-6 82-33 G-17 G-19 G-21 G-27 78-3 69-17 72-42 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 K-9 68-38 10-30-91, 91-325 4-21-92, 92-093 11-1-91, 912331 11-10-92, 92-238 4-21'92, 92-094 6-17-93, 93-154 . 4-21'92, 92-95 !,6193, 92-203 · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this wel~ . Perf. 10-19-91 Perf 4-92 - G. Bush G. Bush G. Bush Perforate G. Bush Temp. log 10-15-92 G. Bush Perf 4-92 Coil tubing cleanout Perforate Convert to inj. -. " G Bush · ....:' ~' -" · .. G2 Bush__'_. R S chmidt Production profile . G. Bush Perforate 2/90 R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, · perforate R. Roberts · Operations Performed: STATE OF ALASKA ALAb,,A OIL AND GAS CONSERVATION COMh,,,,.;SION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown __ Stimulate __ Plugging __ Perforate ~ Pull Tubing Alter Casing Repair Well Other 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory -- Stratigraphic -- Service -- 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platfrom 749' FSL, 1,125' FWL, Sec. 6-8N-13W-SM At top of productive interval EEEIVED 3,311' FWL, 1,886' FSL, Sec. 32-9N-13W-SM At effective depth MAR tl 399; At total depth Alaska 0il & Gas Cons. 3,660' FWL, 2,661' FSL, Sec. 32-9N-13W-SM ;Anchorage 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 6. Datum elevation (DF or KB) /( f 106' KB above MSL '~ feet 7. Unit or Property name Trading Bay Unit 8. Well number D-42 9. Permit number/approval number 83-53 / 93-025 0. APl number 50- 733-20205-01 1. Field/Pool Hemlock 12,830' feet Plugs (measured) None 9,870' feet 1 2,749' feet Junk (measured) None feet Length Size Cemented Measured depth 3,000' 13-3/8" 1,000 sx 3,000' 10,510' 9-5/8" 1,900 sx 10,510' 2,652' 7" 750 sx 12,828' See Attachment #1 True vedical depth 2,601' 8,033' 9,870' Tubing (size, grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' Packers and $SSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV @326' MD; Baker F-1 Prod Pkr (size 85-40) w/SBE @11,892' MD ¸13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation 1/16/93 Subsequent to operation 1/26/93 Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure 376 211 1,142 1,195 367 259 1,475 1,220 Tubing Pressure 135 130 15. Attachments Copies of Log and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service Form 10-404 Rev 06/15/88 correct to the best of my knowledge Title Date ~o ~'i~,:.,..i,'I , /~ SUBMIT IN DUPLICATE Bench B-1 B-2 B-3 B-4 B-5 Attachment #1 Well D-42 Perforations MD 11,984' - 12,022' 12,070' - 12,084' 12,160' - 12,280' 12,280' - 12,370' 12,400' - 12,520' TVD 9,202' - 9,233' 9,272' - 9,284' 9,345' - 9,442' 9,442' - 9,514' 9,537' - 9,632' RECEIVED MAP, 11 ~,993 Alaska Oil & Gas Cons. Commission; Anchorage [SUNDRY.XLW]D-42 DAILY WELL OPERATIONS D-42 1/21/93. Hold safety meeting. Pressure test lubricator to 2500 psi. Good test. Lock gun SCSSV w/ auxiliary pump. Establish CBO. Arm 2-1/8" strip guns 0 degree phase 30 degree offset 4SPF. Flow well to obtain underbalance and perforated the following intervals. RUN # ZONE INTERVAL FOOTAGE RESULT i HB-~,4 12,270' - 12,300' 30' Fired 2 HB-3 12,250' - 12,270' 20' Fired RD. Return well to production. RECEIVED MAR ! 1 199 Alaska .Oil .& Gas Cons. Commission' Anchorage H: \wp\WE LLOPS\D42 STATE OF ALASKA 'J' ~' ,-~;' "'., ALASKA OIL AND GAS CONSERVATION COMMISSION ~ .~'-~; APPLICATION FOR SUNDRY APPROVALS Operation shutdown 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Plugging __ Time extension ~ Change approved program __ Pull tubing __ Variance __ Perforate t ri' Type of Well: 2. Na~jeN~)/~lera~aratho, 0il Co - Sub 0perat Development_~. , Exploratory __ 3. Address Stratigraphic ~ P. 0. BOX 190247 Anchorage, AK 995~9 Service__ Re-enter suspended well )tim ulate __ Other 6. Datum elevation (DF or KB) 10§' KB above MSL 7. Unit or Property name Trading Bay Unit feet 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platform 749' FSL, 1,135' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32- 9N- 13W- SM At effective depth At total depth 3,660' FWL, 2,661' FSL, Sec. 32 - 9N - 13W - SM 8. Well number 0-42 9. Permit number 83-53 10. APl number 50-- 733-20205-01 11. Field/Pool ~\ L ~,., L II V 12. Present well condition summary Total depth: measured 12,830 ' feet Plugs (measured) true vertical 9,870' feet JAN -2 8 1995 Effective depth: measured [2,749' feet Junk(measured) Alaska 0il & Gas Cons. true vedical feet Anchorage Casing Length Size Cemented Measured depth Structural Conductor Sudace 3,000' 13-3/8" 1,000 SX 3,000' 2 Intermediate 10,510' 9-5/8" 1,900 SX 10,510' 8 Production Liner 2,652' 7" 750 SX 12,828' 9 Perforation depth: measured B-1 11,984' - 12,022' MD 9,202' - 9,233 8-2 12,070' - 12,084' HD 9,272' -9,284 true vertical B-3 12,160' - 12,280' MD 9,345' -9,442 B-4 12,280' - 12,370' MD 9,442' -9,514 B-5 12,400' - 12,520' MD 9,537' - 9,632 Tubing (size. grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' Packers and SSSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV ~ 326' MD Baker F-1 Prod PKR (size 85-40) w/SBE 0 11.892' MD 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch _~_ True vertical depth ,601' ,033' ,870' TVD TVD TVD TVD 'TVD 14. Estimated date for commencing operation 1/21/93 16. If proposal was verbally approved Oil Blair Wondzel 1 1/20/93 Name of approver Date approved Service ~i' Inhe~reb~?~J~~ng is true and c°rrect t° the best'~ mY kn°wledge'k'~f Title 'g ./-,,~.-./'~C.V',.,~______ FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended __ Conditions of approval: Notify Commission so representative may witness Date Plug integrity __ Mechanical Integrity Test Location clearance Approved by order of the Commission Form 10-403 Rev 06/15/88 BOP Test Subsequent form required 10- ~.¢~ Originni 3l.-,,',ed By David W. ,~,-~:.: ..... SUBMIT IN TRIPLICATE REPERF PROCEDURE D-42 I · · · · Obtain a 24-hour test with a minimum of four (4) W.C.'s. Skid rig 77 over D-42. Hold safety/environmental meeting. RU E-Line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication black-out. Re-establish the communication black-out when guns are La 1000' when POOH. SI well to RIH & POOH. RIH with 2-1/8" strip guns, 4 SPF, O-Phase offset 30° and perforate the following intervals underbalanced: .RUN BENCH INTERVAL (DIL) FOOTAGE i HB-3,4 12,270' - 12,300' 30' 2 HB-3 12,250' - 12,270' 20' 3 HB-3 12,220' - 12,250' 30' 4 HB-3 12,190' - 12,220' 30' 5 HB-3 12,160' - 12,190' 30' RD E-Line unit. Return well to production and obtain well tests. H: \wp\WLPRO\D42 JAN 2 8 199 ~laska Oil & Gas Oons. Commission Anchorage MARATHON OIL O' ~ANY TRADING BAY f DOLLY VARDEN WELL D-42 RECEiV D . Alaska Oi! & Gas Cons. Anchorag,~ CompLeted 4/90 405' Att measurements are RKO to top oF equipment. Comptetlon String: 3;~6' CAMCO 4.5' TRDP-4A SCSSV. (3.813' I.D.) 0'-10,142' 4.5' L-80, Butt Tbg w/ AB Mod Cpig. X/D 4.5' x 3.5'. 10,142'-11,934' 3.5' L-80, EUE 8RD Tbg. 33' Conductor 3000' 13-3/8', 68~, K-55 Butt. Cs9. 10,510' 9-5/8', 47t~, N-80 & P-ilO Butt. Csg. Gas LiFt mandrels 1-7 are CAMCO 4.5' MMG, 8-11 are CAMCO 3.5' MMG-2. Gas LiFt Va[yes are 1-1/2' w/ RK Latches. Depth Valve N Type Latch Port Size 2662' 1 Danle[s RK 12/64 10,176' 7' Liner Top B-1 B-2 B-3 B-4 4252' 2 5639' 3 &861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 I1375' 10 11876' 11 Danie($ RK 12/64 12/64 16/64 16/64 20/64 20/64 24/64 24/64 ~8/64 32/64 OriFice 11,898' 11,934' Baker F-I Prod Pkr size 85-40 w/SBE; Seat Bore/Mit[out X-ovem Mi[Lout Ex[; Mitlout/EUE 8RD X-overj 10' pup, · Mir I.D. = 2.75' - Otis XN NippLe; 10' pup. Baker shear out sub/WL entry guide. Faired squeeze (4/12/90) Leaking intervat @ 12,070'-12,084'. PERFORATED INTERVALS Zone Interval SPF ~ Phaslnq Date B-1 11,984'-12,02P' 4 0 7/24/90 B-2 12,046'-12,122' 4 0 Cmt Squz B-3 12,160'-1~,280' 4 0 10/8/91 B-4 1~,~80'-1~,370' 4 0 6/P4/90 B-5 12,400'-12,580' 4 0 6/81/90 Tagged Fat @ 1~,556' WLM 11-17-91 Revision Date: 11/81/91 PBTD @ 18,749' Revised By: JDM/evo TD 8 18,830' Reason: Change out GLV's 12,828' 7' 29ff, N-80 Butt, Liner Previous Rev;slam 11/04/91 DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE · GREASE HEAD (Hydraulically Activated) , LUBRICATOR MANUALLY OPERATED BOP CHISTMAS TREE POSITIVE CHOKE Alaska OJJ & ~au,~ GO[IS. GOiTII~liS$iL~: Anchorage L 3000 p;i 13 3/8' CASING ~ - STATE OF ALASKA AL...~KA OIL AND GAS CONSERVATION COMMIbJION '~ /-(' ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casmg __ Change approved program __ 2. Name of Operator I IM~'~A I I i ,~ .., ..~...., 4. I,~ ,.... ,..~ 3. ~Qoress P. O. 4. ~cation of well at sudace At to7pZto~ ~rol~i~/e i'~t~'¢~5' At ef~dc~ v~e~c~e p~'hWL' Suspend __ Repair well __ Pull tubing __ Variance __ I 5. Type of Well: Development X_._ r~.; q r',., c,,k r~ .... + ~ Exploratory Stratigraphic __ Anchorage. AK 9951~_/ Service__ Leg A-2 Cond. #7, Dolly Varden Platform FWL, Sec. 6 - 8N - 13W - SM 1,886' FSL, Sec. 32- 9N - 13W- SM Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate ~ Other __ At total depth 3,660' rW! ? 6R1 ' FSI . .Sec. 32 - qN - 13W - SM 12. Present well c°nditi"on s~mmary ' Total depth: measured 12,830 ' feet Plugs (measured) true vertical 9,870 ' feet Effective depth: measured feet Junk (measured) true vertical 12,749' feet Casing Length Size Cemented Structural Conductor Surface Intermediate 3,000' 13-3/8" 1,000 sx Production 10,510' 9- 5/8" 1,900 s x Liner 2,652' 7" 750 sx Perforation depth: measured B-1 11,984' B-2 12,070' true vertical B-3 12,160' B-4 12,280' Tubing (size, grade, and measured depth) B-5 12,400' 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 Packers and SSSV (type and mea. sured depth) Baker F-1 Prod PKR (size 85-40 Reperf 6. Datum elevation (DF or KB) 106' KB a_bov~ 7. Unit or Property name Tradino Bav Unit 8. Well number - 9. ~'~t number 10. "~'1~1 ~"u"m bet 50-- 7R3-202g~-O1 11. Field/Pool Hem ]oc k Tagged Mea u,W&/ fill (a 11,812' WLM True vertical depth 3,000' 10,510' 12,828' Camco 4-1/2" TRDP - w/SBE ¢ 11,892' MD - 12,022' MD 9,202' - - 12,084' MD 9,272' - - 12,280' MD 9,345' - - 12,370' MD 9,442' - - 12,520' MD 9,537' - EUE 8rd tbg to 11,934' 4A SCSSV 0 326' MD feet 2,601' 8,033' 9,870' 9,233' TVD 9,284' TVD 9,442' TVD 9,514' TVD 9,632' TVD 13. Attachments 1, 2, Description summary of proposal X 3 14. Estimated date for commencing operation December 9, 1991 16. If proposal was verbally approved 6, 1991 Russ Douglass December Date approved J Name of approver Detailed operations program __ 15. Status of well classification as: Oil ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~" c r;-') ~' Title -~c, ~ ,. ~ ,r-~. Signed IO~ ~ ~ ,. ~ ,..,_,~,v,.. ~ .~ ~ .~ . rjr f~ FOR COMMISSION USE ONLY-' Conditions of a~a~rova~.' Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH BOP sketch I::Cl:: I'tlPnl m'~ im. ~.d m-- m II Jm l~ l Approved by order of the Commission Gas __ Suspended__ DEC 20 1991 Alaska Oil & Gas Cons. Com~] Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bs~on Attachment #1 1) 2) 3) 4) 5) D-42 REPERF PROCEDURE Obtain a 24-hour test with a minimum of four (4) WC's. Skid rig 77 over D-42. RU E-Line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 PSI. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE @ 1000' WHEN POOH. SI WELL TO RIH & POOH. RIH with 2-1/8" strip guns, 4 SPF, O-Phase and perforate the following intervals underbalance: RUN BENCH INTERVAL (DIL) FOOTAGE HB #4 12,270' - 12,300' 30' HB #3 12,250' - 12,270' 20' HB #3 12,220' - 12,250' 30' HB #3 12,190' - 12,220' 30' HB #3 12,160' - 12,190' 30' 6) RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. \oe60\83.doc DEC 0 1991 ~,nchorags A ~ ~acn...en'c ,, ~- MARATHI~ OIL' CrlMPAN TRAOIN6 BAY UNIT DOLLY .VARI)LrN VEIL D-4~ Completed 4/90 405' ~lt measure~en~cs ore RKB to top oF equipment (;gmnLe~clon String. 32.6' CAMCO 4.5' TRDP-4A SCSSV. (3.813' I.D.) 0'-10,142' 4.5' L-80, Bu~t Tbg w/ AB Mod Cpig. X/O 4.5' x 3.5'. 10,142.'-ll,934' 3.5' L-80, £UE 8RD Tbg. 33' Conductor 13-3/8', 68#, K-55 Butt. Csg. 3000' 10,510' 9-5/8', 47#, N-80 & P-Il0 Butt. Csg. 10,176' 7' Liner Top B-1 ])-4 G:S (iF~ mondrets 1-7 ore CAMCO 4,5' MMG, 8-11 ore CAMCO 3.5' MMG-2. Gas LiFt Voives ore 1-1/2' w/ RK Latches. Deoth Volv~ # Type Latch ~ ~662' 1 Doniels RK 12/64 B-5 425P' ER 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 1028;~' 8 10906' 9 11375' 10 12/64 12/64 16/64 16/64 ~0/64 20/64 24/64 P4/64 28/64 11876' 11 Donieis RK 32/64 OriFice 11,892' 11,934' Baker F-I Prod Pkr size 85-40 w/SBE; Seoi Bore/Millout X-over; Millout Ext; Mitlout/EUE 8RD X-over; 10' pu~ a MIn I.D. = 2.75' - Otis XN Nipple; 10' pup. ])aker shear out sub/WL entry guide. squeeze (4/12./90) Leaking interval ~ 12,070'-12,084'. pIrRFORATE]] INTERVALS Zone Interval SPF ' Phasing ~ B-1 ll,g84'-lE, O2.P' 4 0 7/2.4/90 B-2 12.,046'-lE, l~P' 4 0 Cm~ Squz B-3 1~,160'-1~,~80' 4 0 10/8/91 B-4 1~80'-1~370' 4 0 6/~4/90 B-5 1~400'-1~5E0' 4 0 6/E1/90 Tagged Cdt ~ 1~,556' VLM 11-17-91 PBTD E 1~749' TO e IP,,B30' l~BES' 7' Egl, N-80 Butt. Liner Revision Date, II~E1~91 Revised By, JDM/evo Reosom Change out GLV's Prevmus Revls~or~ 11/04/91 Attachment ~3 ~ -- .. ~OLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) · LUBRICATOR MANUALLY OPERATED BOP .4' ~17.-1.6~. 5000 CHISTMAS TREE POSITIVE CHOKE RECEIVED DEC 20 1991 .0il & Gas Cons. CommisSiOn ~nchorage ~ 2' 5000 psi 2' 3000 13 3/8' CASING STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION O REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Pull tubing Alter casing __ Repair well ~ 2. Name of Operator / 5. Type of Well: Development ~ UNOCAL (Marathon 0il Co - Sub 0perat~r) Exploratory__ 3. Address - ! Stratigraphic ~ P. 0. Box 190247 Anchorage, AK 99519 Service__ 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden P]atform Plugging __ Pedorate __ Other _Eeperf HB-3 Datum elevation (DF or KB) 106' KB above MSL Unit or Property name Trading Bay Unit 8. Well number feet 749' FSL, 1,135' FWL, Sec. 6 - 8N At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32- At effective depth At total depth 3,660' FWL, 2~661' FSL, Sec. 32- - 13W- SM 9N- 13W- 9N- 13W SM - SM r~-42 9. Permit number/approval number ,f,'-_~" 91-318 ~ 10. APl number so- 733-20205-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 12,830 ' feet Plugs(measured) 9,870' feet feet Junk (measured) Effective depth: measured 12,749 ' true vertical feet Tagged fill ~ 11,812' 5/4/91 Casing Length Size Cemented Measured depth Structural Conductor Surface 3,000' 13-3/8" 1,000 sx 3,000' Intermediate 10,510' 9-5/8" 1,900 SX 10,510' Production Liner 2,652' 7" 750 sx 12,828' Perforation depth:measured B-1 11,984' - 12,022' MD B-2 12,070' - 12,084' MD true vertical B-3 12,160' - 12,280' MD B-4 12,280' - 12,370' MD Tubing (size, grade, and measured depth) B-5 12,400' - 12,520' MD 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg Packers and SSSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV Baker F-1 Prod PKR (size 85-40) w/SBE @ 11,892' MD; 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 2,601' 8,033' 9,870' 9,202' 9,272' 9,345' 9,442' 9,537' - 9,233' TVD - 9,284' TVD - 9,442' TVD - 9,514' TVD - 9,632' TVD to 11,934' C I lV E D Alaska Oil & Gas Cons. Comm'[ssio~ Anchora§o 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9/30/91 102 152 575 1110 160 Subsequent to operation 10/11/91 1302 311 1432 1100 150 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x__ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ ~. (~,¢,.~ Title I::nrm in.aha I~_v nR/1.~ ~ 'J Date ~,~,- &~ -~ SUBMIT IN DUPLICATE Attachment #1 TBU Well 0-42 Daily Summary of Operations RU on Well D-42. Tested lubricator to 2500 psi. PU perf guns, 30' length, · 4 spf, 0 degree phase· RIH, tagged ~12,400, Correlated guns, flowed well 75 minutes to stabilize. Perforated Bench 3 & ~, 12,270, _ 12,300'. POOH to 12,000,. F/owed well for 30 min. SI well POOH with wireline 10/7/91 ' . RIH w/ 20' " - unyastrap 2-1/8", 4 spf, 0 degree phase,d, 20.5g g,un. Flow we/1 - I hour for underbalance. indication of firing. Fire gun across 12,250 - 12.270 DIL. Positive POOH. Comm. B/O (a 1000,Fl°w well 25 minutes to clean up.' SI (a manumatic & .&_~RIH. w/ 30' of same Dvn; +LO gu.n._. All. shots fired. · ..... j SAr _~,a snoot across I , ap g_u.n as above. Est_abl?sh comm. B . manu ..... 2,220 12.2~0~0n,, .. Flow we]] fo-~n _. ut~!O- MU fire nd O 'ab ' 0 1~(~ "'. asnhoU~Ps ;n s~n5! · iow well for 40 min.. the, +~^ .3recl: MU & RIN w gun. No indication of firing Line shows ' '. ~,:-]n ano attempt to · dead short, but CCL still working. SI manumatic & POOH. Comm B/O [a 1000 10/8/91 ' '. OOH, gun did not fire. NLS preparing to arm guns. PT lubricator again to 2500 psi/ weight bars only· Hold safety meetin . 30' o ~.,,o,, g. 4000# on CL auxiliary pump· Establish comm. B/O & arm f ~ ~/o Dynas~rap gun loaded 4 spf, 0 degree phased w/ 20.5g JRC charges. RIN, flow well 40 12,220, OIL. F1 min. for nderbalance, then fire across 12 190 - slowly throu,h ~o~,~ add'l min. u all shots f~red. Bottom nose wa~f°r c)eanup. SI well & POOH. Had to' i .~" ~-~/~ as gun was dragging through GLM's come more of same gun & RIH to 12,160 loose & hanging b .... ~ Con~n. B/O ~ 1000'_ y un,y one ~re~' bo)t. , · 0 - I2,190' OIL. F/ow we/) 30 min & Wait 20 min for cleanup. SI well & POOH· Comm. B/O g 1000 , continue OOH. All shots fired· RD HLS. , \dvp\d42.doc RECEIVED DEC - 6 199t Alaska.Oil & Gas Cons. Commission ;Anchorag~ A~cachment ~ MARATHON OIL COMPANY TRADING BAY UNIT -'DOLLY VARDEN ~/ELL D-42 Comoteted 4/90 Att measurements are RKB to top oF equipment. Comp(etion String: 326' 0'-10,142' I i0,142'-11,892' 405' 33' Conductor CAMCO 4.5' TRDP-4A SCSSV. 4.5' L-80, Butt Tbg w/ AB Mod Cp[g. X/O 4.5' x 3.5'. 3.5' L-80, EUE 8RD Tbg, SO00' 13-3/8', 68~, K-55 Butt. Csg. 10,510' 9-5/8', 471~, N-80 & P-ilO Butt. Csg. Gas [;Ft mandrels 1-7 are CAMCO 4.5' ,'4MG, 8-11 are CAMCO 10,176' 7' Liner Top m~.~' MMG-2. Depth "/aive ~l 2662' 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' lO 11876' !1 Type Latch GLESCO RK GLESCO DanieLs DanieLs RK Port Si~e 12/64 12/64 12/64 !6/64 16/64 20/64 20/64 24/64 24/64 7/16 1/2 OriFice 11,892' Baker F-1 Prod Pkr size 85-40 w/SBE; Seat Bore/Mitlout X-over; MitLout Ext; Mittout/EUE 8RD X-over; 10' pup, Bt;s XN nippte, !0' pup. 11,934' 3aker shear ou'~ sub/g/L entry guide. FoiLed squeeze (4/12/90) Leoklng interval @ 12,070'-12,084'. PERFORATED INTERVALS Zone Interval SPF ' Phasing Date 3-1 1],984'-12,0P2' 4 0 7/24/90 3-2 12,046'-12,122' 4 0 CmL Squz B-3 12,160'-12,280' 4 0 10/8/91 B-4 t~,280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 0 6/P_..1/90 Togged ?itt [~ 11,812' WLM 5/4/91 PBTD @ 12,749' TD ~ 12,830' ~. ~ .......... Revision Dote: 10/30/9I Revised By: SSL/evo Reason: Per? HB-3,4 Pnpvi~lJ~ R~vlqinn: ~/IQ/ql 1. Type of Request: Abandon m Suspend __ Alter casing __ Repair well ~ Change approved program __ Pull tubing ~ Variance __ 2. Name of Operator ! 5. Type of Well: Development ~ IINI~r'AI (M~r,~fhnn (11-;1 ('n - ~:,,k ~rn'~'~'l' r) Exploratory__ 3. Ad d r~'~' ............... ! Stratigraphic P. O. Box 190247 Anchoraoe. AK 9q.~Jl~ Service__ 4. Location of well at sudace Leg A-2 Cond. #7, Dolly Var'den Platform Atto749'p FSL, .1.,135' FNL, Sec. 6- 8N- 13N- 514 Of proouc[Ive interva Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate__ Other -X-- Reperforai;e HB, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .3 3,311' FWL 1,886' FSL Sec. 32 - 9N - 13W- SM At effective depth ' ' FSL. Sec. 32 - 9N - 13W- SM At total depth 3,660' FWL, 2,661' 12. Present well condition summary Total depth: measu red true vertical 12,830 ' feet Plugs (measured) 9,870' feet Effective depth' measured 12 749' feet Junk (measured) true vertical ' feet 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number Casing Length Size Cemented Structural Conductor Sudace Intermediate 3,000' 13-3/8" 1,000 sx 10,510' 9-5/8" 1,900 sx Production Liner 2,652' 7" 750 sx Perforation depth: measured 9. ~'r~ number 83-53 10. APl number 50-- 733-2070E-f11 11. Field/Pool Hemlock feet Tagged fill 0 11,812' WLM Measure~~ True vertical depth 3,000' 2,601' 10,510' 8,033' 12,828' 9,870' B-1 11,984' - 12,022' MD 9,202' - 9,233' TVD 8-2 12,070' - 12,084' MD 9,272' - 9,284' TVD B-3 12,160' - 12,280' MD 9,345' - 9,442' TVD B-4 12,280' - 12,370' MD 9,442' - 9,514' TVD TVD true vertical Tubing (size, grade, and measured depth) B-5 12,400' - 12,520' MD 9,537' -9,632' 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' pa..ck,ersand._SS. SV~(type, an~,d_rne§su.redde~t..h).,, Camco 4-1/2" TRDP - 4A SCSSV ¢ 326' MD ~aKer r-I vroo v~ [s~ze ~-~u) w/SBE ~ 11,892' MD 13. Attachments 1, 2, Description summary of proposal -.-X &3 14. Estimated date for commencing operation 16. If proposal was verbally approved Lonnie Smith 11/1/9.1. , Name of approver ume approved Service 17. I hereby ce/¢i~ that the foregoing is true and correct to the best of m,./ knowledge. · ' { % ' ' ~ "~,_~_~,,,,. Title S, gned ~'k~ ~~ ,~_~. ~ -~ FOR COMMISSI0~I USE ONIt¢' Conditions of aplS~bval: ~N~tify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Detailed operations program __ BOP sketch 15. Status of well classification as: Oil ~ Gas ~ Suspend~d~ Date Commissioner [ A pp roval N~,/- .,~'.,f"~¢¢' Date Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Wel 1 D-42 Reperforate HB-3 Procedure 1) 2) 3) 4) 5) 6) 7) Obtain a 24-hour test with a minimum of four (4) WC's. Skid rig 77 over D-42. RU E-Line unit. Hook up platform PA system in unit. Pressure test Lubricator and BOPE to 2500 PSI. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE ~ 1000' WHEN POOH. SI WELL TO RIH & POOH. RIH with 2-1/8" strip guns, 4 SPF, O-Phase offset 30 o and perforate the following intervals underbalance: RUN BENCH INTERVAL (DIL) FOOTAGE i HB #3-4 120270' - 12,300' 30' 2 HB #3 12,250' - 12,270' 20' 3 HB #3 12,220' - 12,250' 30' 4 HB #3 12,190' - 12,220' 30' 5 HB #3 12,160' - 12,190' 30' RD E-Line unit. Return well to production and obtain two 24-hour well tests obtaining 3 WC's per 12-hour test. RU to pump scale inhibitor treatment post 2nd 24-hour well test. ** Work Request and procedure for scale inhibitor treatment attached. \docs\oe57\22. doc DOLLY VARDEN PLATFORM .. Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) BRICATOR POSITIYE CHOKE -4'~1~-1.6~. 5000 psi CHISTMAS TREE ~--2' 5000 psi 13 3/8' CASING t- MARATHON OIL COMPANY TRADING BAY UNiT DDLLY VARDEN WELL D-42 Comp[eted 4/90 B-1 B-2 B-3 ~ B-4 B-5 ALL measurements are RKO to top oF equipment. Completion String: 326' CAMCO 4.5' TRDP-4A SCSSV. (3.8]3' I.D.) 0'-10,142' 4.5' L-BO, Butt Tbg w/ AB Mod CpLg. X/FI 4.5' x 3.5'. ]0,142'-]1,934' 3.5' L-80, EUE 8RD Tbg. 405' 33' Conductor 10,510' 9-5/8', 47t*, N-80 & P-110 Butt. Csg. Gas LiFt mandrels 1-7 are CAMCO 4.5' MMG, 8-11 are CAMCO 3.5' MMG-2. Gas LiFt Valves are 1-1/2' w/ RK Latches. Depth Valve ~ Type Latch Port Size 2662' [ GLESCO RK 12/64 10,176' 7* Liner Top 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' 10 GLESCO Daniels 12/64 12/64 16/64 16/64 20/64 20/64 24/64 24/64 28/64 11876' 11 Danie[s RK 32/64 OriFice 1!,892' Baker F-1 Prod Pkr size 85-40 w/SBE; Seal Bore/Mittout X-over; Mittout Ext; Mittout/EUE 8RD X-over; tO' pup, · Mir I.D. : 2.75' - Otis XN NippLe; 10' pup. 11,934' Baker shear out sub/';L entry guide. FaiLed squeeze (4/12/90) Leaking interval @ 12,070'-12,084' PERFORATED INTERVALS Zone Intervat SPF ° Phasing Date B-1 11,984'-12,022' 4 0 7/24/90 B-2 12,046'-12,122' 4 0 CmL Squz B-3 12,160'-12,280' 4 0 10/8/91 B-4 12,280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 0 6/21/90 Tagged Fat ~ [2,400' WLM 10-6-91 PBTD @ 12,749' TD @ 12,830' lPR;:)R' 7' ;::)q~ iXl-~N 12, J++ I ;nc>v- Revision Date: 11/04/91 Revised By: JDM/evo Reason: PerForations Added Previous Revision: New Completion STATE OF ALASKA ""~' ALASKA OIL AND GAS CONSERVATION COMMISSION I"~ ~ ~% APPLICATION FOR SUNDRY APPROVAES" 1 § I -[/ 1. Type of Request: Abandon __ Suspend __ Alter casmg __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator ~ 5. Type of Well: Development ~ UNOCAL (Marathon Oil Co - Sub oPerat r) Exploratory__ 3. Address Stratigraphic __ P. O. Box 190247 Anchorage, AK 995:1,9 Service__ 4. Location of well at sudace 749' FSL, 1,135' Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extens,on __ Stimulate __ Pedorate__ Other.Eeperf HB-3 Leg A-2 Cond. #7, Dolly Varden Platform 8. FWL, Sec. 6- 8N- 13W- SM . Datum elevation (DF or KB) 106' KB above MSL Unit or Property name Trading Bay Unit Well number D-42 feet At top of productive interval 3,311' FWL, 1,8.B6' At effective depth FSL, Sec. 32- 9N - 13W- SM At total depth 3,660' FWL, 2,661' FSL, Sec. 32 - 9N - 13W - SM 9. Permit number 83-53 10. APl number 5o- 733-20205-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vedical 12,830 ' feet Plugs (measured) 9,870' feet Effective depth' measured 12,749 ' true vertical Casing Length Size Structural Conductor Surface 3,000' 13-3/8" Intermediate 10,510' 9-5/8" Production Liner 2,652' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) feet Junk (measured) feet Cemented 1,000 sx 1, gOO sx 750 sx Tagged fill ~ 11,812' WLM M eas u ,eSyd4e/p~h]' True vertical depth 3,000' 2,601' 10,510' 8,033' 12,828' 9,870' B-1 11,984' - 12,022' MD 9,202' - 9,233' TVD B-2 12,070' - 12,084' MD 9,272' - 9,284' TVD B-4 12,280' - 12,370' MD 9,442' - 9,514' TVD B-5 12,400' - 12,520' MD 9,537' - 9,632' TVD 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,934' Packers and SSSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV ~ 326' MD Baker F-1 Prod PKR (size 85-40) w/SBE 8 11,892' MD 13. Attachments I Description summary of proposal .Z._ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 10/5/91 16. If proposal was verbally approved Russ Douglass Name of approver 10/4/91 Date approved 15. Status of well classification as: K L L Oil X__ Oas__ Suspended __ 0 CT Service ,, ,--,.- n'~ ~_,.,,;,,,, ,,h ~, Gas 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ %., (~,,..t,.z:~ Title..("~.e..~r,,-~ ~:)~-~, /x 1 ~ FOR COMMISSION USE ONLY Conditions of,~Spro~'l: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- .. Approved Gop'~ Returned ORIGINAL SIGNED Anchorage Date tO -to-~ lApprova' No. ¢/-~/~ II-G-?I~ Approved by order of the Commission LONNIF ,n ~'-'":"": Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE OB Attachment #1 Wel 1 0-42 Reperforate HB-3 Procedure 1) Obtain a 24-hour test with a minimum of four {4) WC's. 2) Skid rig 77 over D-42. 3) RU E-Line unit. Hook up platform PA system in unit. Pressure test Lubricator and BOPE to 2500 PSI. 4) Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE 0 1000' WHEN POOH. SI WELL TO RIH & POOH. 5) RIH with 2-1/8" strip guns, 6 SPF, O-Phase and perforate the following intervals underbalance.- RUN BENCH INTERVAL (DIL) FOOTAGE HB #3-4 12,270' - 12,300' 30' HB #3 12,250' - 12,270' 20' HB #3 12,220' - 12,250' 30' HB #3 12,190' - 12,220' 30' HB #3 12,160' - 12,190' 30' 6) RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. \docs\oe57\22. doc R £EIVED Alaska Oil & Gas Cons. Commkss\o~ Anchorage DOLLY VARDEN PLATFORM ._ Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) · BRICATOR · 4'~.s-'..-*' 'Sooo ,,, CHISTMAS TREE POSITIVE CHOKE n~ [~~~____~. ---- 2' 5000 psi L .--- 2' 3000 psi 13 3/8' CASING .r MARATHON OIL CDF,, ~NY TRADING BAY UNIT ]]nLLY VARDEN V/ELL ]]-42 Comp[e%ed 4/90 405' All meesuremen±s are RKB to top aP equipment. Completion String: 326' CAMCO 4.5' TRDP-4A SCSSV. 0'-10,142' 4.5' L-80, Butt Tbg w/ AB Mod Cpig. X/FI 4.5' x 3.5'. 10,142'-11,892' 3.5' L-80, EUE 8RD Tbg. 33' Conductor 3000' 13-3/8% 68~. K-55 Butt. Cs9. 10,510' 9-5/8', 47~, N-80 & P-il0 Butt. Cs9. Gas LiFt mandrels 1-7 are CAMCO 4.5' MMG, 8-11 are CAMCO 10,176' 7~ Liner Top 3.5' HMG-2. Depth Valve 2662' 1 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' 10 11876' 11 Type Latch GLESCD RK GLESCB RK Port Size 12/64 12/64 12/64 16/64 16/64 20/64 20/64 24/64 24/64 24/64 24/64 B-1 B-2 3-4 B-5 11,892' Baker F-1 Prod Pkr slze 85-40 w/SBE; Sea[ Bore/Mil[au% X-over; Mittout Ext; Mittout/EUE 8RD X-over; 10' pup, Ii]tis XN nippte, 10' pup. 11,934' Baker shear out sub/g/L en%ry guide, Failed squeeze (4/1E~/90) Leakin9 intervat @ 12,070'-1EL084'. PERFORATED INTERVALS Zone Interva[ SPF ° Phasing Date B-1 11,984'-12,022' 4 0 7/24/90 B-2 12,046'-12,122' 4 0 Cmt Squz B-4 12.280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 0 6/21/90 T699ed Fi[[ I~ 11,812' WLM 5/4/91 Revision Date; 6/13/91 PBTD ~ 18,749' Revised By~ EVB TD @ 12,830' Reason: Tag Flit 12,828' 7' 29~, N-80 Butt. Liner Previous Revision: 10/90 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter cas, rig __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: 6. Development X__ UNOCAL (Marathon 0il Co - Sub 0Perat r) Exploratory__ 3. Address Stratigraphic __ 7. P. O. Box 190247 Anchorage, AK 995:1r9 Service__ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extensIon __ Stimulate __ ,. Pull tubing __ Variance __ Perforate __ Other _.h_ca 1 e Cleanout 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platform 749' FSL, 1,135' FWL, Sec. 6 - 8N - 13W - SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32- 9N- 13W- SM At effective depth At total depth 3,660' FWL, 2,661' FSL, Sec. 32 - 9N - 13W- SM Datum elevation (DF or KB) 106' KB aboye MSL Unit or Properly name Tradin9 Bay Unit Well number _n-42 9. Permit number 83-53 10. APl number so- 733-20205-01 feet 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 12,830 ' feet Plugs (measured) 9,870' feet Effective depth: measured 12,749 ' true vertical Casing Length Size Structural Conductor Surface 3,000' 13-3/8" Intermediate 10,510' 9-5/8" Production Liner 2,652' 7" PerfQration depth: measured true vertical feet Junk (measured) feet Cemented 1,000 sx 1,900 sx 750 sx Tagged M easu rebyd4e/p?h1 3,000' 10,510' fill ~ 11,812' WLM True vertical depth 12,828' 2,601' 8,033' B-1 B-2 B-4 B-5 9,870' 11,984' 12,070' 12,280' 12,400' - 12,022' MD - 12,084' MD - 12,370' MD - 12,520' MD Tubing (size, grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to Packers and SSSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV @ Baker F-1 Prod PKR (size 85-40) w/SBE 6 11,892' MD 13. Attachments 1, 2, Description summary of proposal ..,y,. Detailed operations program __ &3 9,202' 9,272' 9,442' 9,537' - 9,233' TVD - 9,284' TVD - 9,514' TVD - 9,632' TVD 11,934' 326' MD BOP sketch ..X_ 14. Estimated date for commencing operation 15. Status of well classification as: June 20, 1991 16. If proposal was verbally approved Oil X Gas __ SuspendeJ:U.L- 1t99t Name of approver Date approve(J Service Alaska 0JJ & Gas Cons. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. An~hurag~ Signed ~.~ ~ ~...~,,. Title Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance __ Mechanical Integrity Test __ ~ubsequent form required~l~t~P¥ - . - Original signed Dy .-r Approved by order of the Comm~.~ '~ - . Commissioner Form 10-403 Rev 06/15/88 I ApprovalNo. q/. /9/) SUBMIT IN TRIPLICATE Attachment #1 WELL D-42 PROCEDURE CLEAN OUT SCALE IN LOWER' TUBING ® e e Skid rig over Well D-42 RU coiled tubing unit. RU communicaton system. Pressure test BOPE and lubricator to 2500 psi. Pressure test surface lines and i 1/2" coiled tailing to 5,000 psi. Test downhole motor. Disconnect SCSSV from wellroom panel and lock open SCSSV at 4,000 psi with mobile test unit. Monitor pressure to ensure no bleed-off occurs. SI lift gas and manumatic. Open swab valve. RIH with 1.5" coiled tubing with fishing neck, check valve, 2 3/8" downhole motor and 2.70" diamond bit to 10,000'. 0 Open lift gas and flowline routed to well clean tank. Establish circulation with FIW at i BPM. Move coiled tubing downhole and cleanout tubing through tail at 11,934'. Pump a 10 bbl polymer pill every 200' while clearing out the 3 1/2" tubing. Circulate hole clean at tubing tail. e Decrease pump rate to 1/4 BPM FIW and slowly POOH with coiled tubing downhole motor and bit. SI lift gas. 7. Close swab valve when at surface. Bring well on production. 8. Break out and inspect 2.70" bit and downhole motor. 9. RIH with hydrablast tool on coiled tubing and jet across lower gas lift mandrels. POOH. 10. RD coiled tubing \docs\ dvp\d42, doc RE EEIVED d UL - 1 1991 Alaska Oil & Gas Cons. Comm'tss~on Anchorage Attachment #2 DOLLY VARDEN PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS .:4-L1/16:5000 psi CHISTMAS TREE I -, POSITIVE CHOKE RECEIVED JUL -1 Alaska 0il & Gas Cons. Commissio~ Anchorage 2' 5000 psi - 2" 3000 psi 13 3/8' CASING COMp{e~ced 4/90 Attachment #3 MARATHON DIL COMPANY TRADING BAY UNIT DOLLY VARDEN WELL D-42 All meo. sureMen'ts ar~e RKB to -top oP equipment. .. ComDletlon Str'~ng, 3~6' CAMCD 4.5" TRDP-4A ~CS~V. 0'-10,142' 4.5' L-80, But~ Tbg w/ AB Mod Cptg. X/O 4.5' x 3.5'. 10,~42'-11,89~' 3.5' L-80, EUE 8RD Tb9, 405' 33' Conc~uctor 3000' 13-3/8', 68~, K-55 Butt. Cs9. 10,510' 9-5/8', 47#, N-80 & P-Il0 3u%t. Csg. G~s lift m(indrets I-7 are CAMCO 4.5' MMG, 8-11 (ire CAMCO 10,176' 7' Liner Top 3.5' MMG-2. Depth Votve ~ 2662' 1 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' 10 11876' 11 Type L(itch GLESCO RK GLESCD RK Pop~ Size 12/64 12/64 12/64 16/64 16/64 20/64 20/64 24/64 24/64 24164 24/64 B-1 11,892' Baker F-1 Prod Pkr size 85-40 w/SBEj Seal Bore/M;ilout X-over; Miilout Ext; Millout/EUE 8RD X-over; 10' pup, Otis XN nippte, 10' pup, 11,934' Baker shear out sub/~/L entry guide. R. Alaska Oj Failed squeeze (4/12/90) Leaking_interval @ 12,070'-12,084'. . " PERFDRATED INTERVALS ]3-4 B-5 Zone Interv(il SPF ' Phos;ng Dote B-1 11,984'-12,088' 4 0 7/24/90 B-8 12,046'-18,188~ 4 0 CMl Squz B-4 12,280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 - 0 6/21/90 .Tagged Fill 8 11,818' ~/LM 5/4191 Rev;sion Date, 6/13/91 PBTD 8 18,749' Revised By. EVO TD 8 12,830' Reason. Tag Fill ............ Pr'pvln~ R~vl~;Ion, 10/90 ¢EIVED JUL - 1 199! & Gas Cons. Commission Anchorage i STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION 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 __ Name of Operator ! 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon 0il Co - Sub 0perattr) Development2~_ 106' KB above MSL Exploratory __ Address Stratigraphic __ 7. U nit or Property name P. O. Box 190247 Anchorage, AK 995~9 Service__ Trading Bay Unit feet Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platform 749' FSL, 1,135' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec, 32 - 9N- 13W- SM At effective depth At total depth 3,660' FWL, 2,661' FSL, Sec. 32 - 9N - 13W- SM 8. Well number D-42 9. Permit number 83-53 10. APl number 5o- 733-20205-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: meas'ured true vertical 12,830 ' feet PI ugs (measured) 9,870' feet Effective depth:measured 12,749 ' true vertical Casing Length Size Structural Conductor Surface 3,000' 13-3/8" Intermediate 10,510' 9-5/8" Production Liner 2,652' 7" Perforation depth: measured feet Junk (measured) feet Cemented 1,000 sx 1,900 sx 750 sx Tagged 7/86 Measure(:l depth 3,000' 10,510' 12,828' fill @ 12,548' WLM True vertical depth 2,601' 8,033' 9,870' true vertical Tubing (size, grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' Pack.ers and SSSV (type and mea. sured depth) . Baker F-1 Prod PKR (size 85-40) B-2 12,070' B-4 12,280' B-5 12,400' - 12,084' - 12,370' - 12,520' MD 9,272' MD 9,442' MD 9,537' MD; 3-1/2" L-80 EUE 8rd tbg to Camco 4-1/2" TRDP - 4A SCSSV e w/SBE e 11,892' MD 11,934' 326' MD 9,284' 9,514' 9,632' TVD TVD TVD 13. Attachments #1, 2, & 3 Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 5/91 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed G~.~ '~, (~'1~ Title (~,,~_._~, U~EO~ - FOR COMMISSION Conditions of ab, l~roval:~otify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ 15. Status of well classification as: Gas__ Suspended__ Date %_ p_(~ _ % \ IApproval No. ~'/- Mechanical Integrity Test __ Subsequent form required 10- ... '¢¢~ ORIGINAL SIGNED BY LONNIE C: ~UITI4 Approved by order of the Commission Approved Copy Returned Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE Attachment #1 WELL D-42 PROCEDURE 1) 2) 3) 4) 5) 6) Obtain a 24-hour test with a minimum of four (4) WC's. Skid rig 77 over D-42. RU E-Line unit. Hook up platform PA system in unit. Pressure test Lubricator and BOPE to 2500 PSI. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. SI WELL TO RIH & POOH. RIH with 2-1/8" strip guns, 6 SPF, O-Phase and perforate the following intervals underbal ance .' RUN BENCH INTERVAL (DIL) FOOTAGE I HB #4 12,250' - 12,280' 20' 2 HB #4 12,220' - 12,250' 30' 3 HB #4 12,190' - 12,220' 30' 4 HB #4 12,160' - 12,190' 30' RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. docs\dvp\d42, doc ~'~ ·-~Attachment- #2-~z ']' -~-'~ - . DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR .4' ~.1/~-1~6~. 5000 CHISTMAS TREE- t j POSITIVE CHOKE 2' 5000 psi 13 3/8' CASING 2' 3000 psi Attachment #3 C°mple%ed 4/90 MARATHON OIL COMPANY TRADING BAY UNIT ]DOLLY VAR]DEN WELL D-48 405' Ail measurements ~re RKB ~o ~cop oF equipment. 3000' 13-3/8°, 68#, K-55 Butt. Cs9. 10,510' 9-5/8', 47#, N-80 & P-Il0 3u~;'c. Csg. Gas t;Ft mandrets 1-7 are CAMCO 4.5' MMG, 8-11 are CAMCO 10,176' 7' Liner Top 3.5' MMG-2. DeOth Valve 2662' 1 4252' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10282' 8 10906' 9 11375' 10 11876' 11 Type Latch GLESCD RK GLESCO RK Port S;ze 12/64 12/64 12/64 16/64 16/64 20/64 20/64 24/64 24/64 24/64 24/64 B-I 11,892' ]3oker F-1 Prod Pkr size 85-40 w/SBD Seat Bore/MHtou~ X-over; MIItoui; Ext; Mlttoui;/EUE 8RD X-overs 10' pup, Otis XN nlppte, 10' pup, 11,934' Boker sheor ou% sub/WL entry guide, 3-2 FoJted squeeze (4/12/90) Leaking mtervo, t @ 12,070'-12,084'. PERFORATED INTERVALS Zone Interval SPF ' Phasing Date ,3-4 B-I 11,984'-12,022' 4 0 7/24/90 B-2 12,046'-1E, 122' 4 0 Cm~ Sou-' B-4 12,280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 0 6/21/90 B-5 Tagged Fltl ~ 1~635' WLM 4/18/90 PBTD @ 1~749' TD @ 12,830' 12,828' 7' 29#, ~-80 Butt. L;ner Revls;on Da~e, 10/90 Revised By, Sgt/neF Reason. New Compte~lon Previous Revision. 1/89 Summary of Daily Op~ °Lions Well D-42 Page 3 04/19/90 Removed pipe rams and N/D BOPs. N/U and tested tree. LD dopo and d.c. out of derrick. Started deactivating rig. 04/24/90 RELEASED RIG 04/23/90. Final Report. 06/22/90 R/U lubricator. Pull BPV. Unload well. R/U E-line Perforate Hemlock Bench 5, 12,490' - 12,520'. POOH. 06/23/90 Fin perf Hemlock Bench 5, 12,400'-12,520' (120') a total of 4 runs with 2-1/8" Enerjet III, 0 phasing, 4 SPF. Flowed well after first run and during runs 2-4. Switched well to test separator monitoring fluid rates and WC4. Current rate: 1392 BFPD, 91.94 WC, 113 BOPD. 06/24/90 On 16 hour test, well produced at a rate of 1221 BFPD, 92.24 WC0 95 BOPD. 06/25/90 Perf Hemlock Bench 4, 12,280'-12,370' (90'), 3 runs w/ 2-1/8" Enerjet III, 0° phasing, 4 SPF. Flowed well during perforating. Switched well to test. 06/26/90 On 24 hrs test well produced at a rate of 1582 BFPD, 89.94 WC, 160 BOPD. Preparing to shoot Hemlock Bench 3. 06/27/90 Producing HB-4 and 5 to test. Production for past 24 hours was 1653 BFPD at 854 WC (246 BOPD, 1407 BWPD) w/ 248 MCFPD formation gas. Lift gas used was 1930 MCFPD. FTP = 160 psi and CP : 1170 psi. 06/28/90 Turned well over to production. ~ummary of Daily Op~ ~tions Well D-42 Page 4 7/17/90 RU wireline equipment and run gas lift survey and PBU survey. 7/24/90 RU ~lectric l~ne, PT lubricator to 2500 psi, OK. RIH w/ 2-1/2" Enerjet strip gun 4 SPF, 0 phasing. Correlate and perforate Hemlock Bench 1, 11,984' - 12,022' DIL. Flow well, POOH, RD. 8/27/90 Ran production log and determined HB-2 leaking through perforations, squeezed in 4/90, at 12,070' - 12,084' MD. \docs\dvp\d42.doc ATTACHMENT #2 Completed 4/90 B-1 3-8 3-4 B-5 MARATHON OIL COMPANY TRADING BAY UNIT DOLLY VARDEN WELL D-42 A[[ meosuremenfs ore RKO to ~op oP equipment. Comptetlon Strlng~ 326' CAMCO 4.5' TRDP-4A SCSSV. 0'-10,142' 4.5' L-80, Butt Tb9 w/ AB Mod Cp[g. X/O 4.5' x 3.5'i 10,142'-11,892' 3.5' L-80, EUE 8RD Th§. 405' 33' Conductor 3000' 13-3/8% 68~, K-55 Butt. Cs9. 10,510' 9-5/8% 47#, N-80 & P-110 Butt. Csg. Gas LiFt mondreLs 1-7 ore CAMCO 4.5' NMG, 8-11 ore CAMCO 10,176' 7' Liner Top 3,5' MMG-8. Depth V~[ve ~ 2662' 1 4258' 2 5639' 3 6861' 4 7880' 5 8709' 6 9587' 7 10888' 8 10906' 9 11375' 10 11876' 11 Type Lotch GLESCD RK GLE~ C0 RK Port S;ze 18/64 18/64 18/64 16/64 16/64 80/64 80/64 84/64 84/64 84/64 84/64 11,892' Baker F-I Prod Pkr size 85-40 w/SBE; Seat Bore/MlRou~ X-over; MiLLout Ext; MiLLout/EUE 8RD X-over; 10' pup, Otis XN nipple, 10' pup, 11,934' Baker shear out sub/~/L entry guide. FaiLed squeeze (4/18/90) Leakln9 Interval I~ 12,070'-1ES084'. PERFORATED INIERVALS Zone Interval SPF ' Phasing Dote B-1 11,984'-18,088' 4 0 7/84/90 B-2 12,046'-12,122' 4 0 CMt Squz B-4 12,280'-12,370' 4 0 6/24/90 B-5 12,400'-12,520' 4 0 6/21/90 Tagged FiU, 8 12,635' ~/LM 4/18/90 Revision Dote, 10/90 PBTD 8 1P~749' Revised By, S;SL/neF TD @ 12,830' Reason. New CoMp(e~lon 12,828' 7' 29~, N-80 Butt. Liner Previous Revision. 1/89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF-SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging ~ Perforate __ Pulltubing __ Alter casing __ Repair well _ Other ~ Workov8r 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KE~) UNOCAL (Marathon Oil Co - Sub Operate,r) Development X__ , Exploratory__ 106' KB above MSL feet 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 190247 Anchorage, AK 995'..9 Service__ Tradin~ Ba~/ Unit . 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platform 8. Wellnumber 749' FSL, 1,135' FWL, Sec. 6- 8N- 13W- SM 11-42 At top of productive interval 9. Permit numbedapproval number 3,311' FWL, 1,886' FSL, Sec. 32 - 9N - 13W - SM 90-188 At effective depth 10. APl number 50-- 733-20205-01 ,, At total depth 11. Field/Pool 3,660' FWL, 2,661' FSL, Sec. 32 - 9N- 13W- SM Hemlock , 12. Present well condition sUmmary Total depth: measured 12,830 ' feet Plugs (measured) true vertical 9,870 ' feet Effec!ive depth: measured 12,749 ' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3,000' 13-3/8" 1,000 SX 3,000' 2,601' Intermediate 10,510' 9-5/8" 1,900 SX 10,510' 8,033' Production Liner 2,652' 7" 750 sx 12,828' 9,870' Perforation depth: measured truevertical B-2 12,070' - 12,084' MD 9,272' -9,284' TVD B-4 12,280'-12,370' MD 9,442' -9,514' TVD B-5 12,400' - 12,520' MD 9,537' - 9,632' TVD Tubing (size. grade, and measured depth) 4-1/2" L-80 Butt Tbg to 10,142' MD; 3-1/2" L-80 EUE 8rd tbg to 11,892' Packers and SSSV (type and measured depth) Camco 4-1/2" TRDP - 4A SCSSV Ia 326'MD Baker F-1 Prod PKR (size 85-40) w/SBE @ 11,892' MD; .. ,._ .,._. ~.~ i,~,~? ~-~-',,~ 13. Stimulation or cement squeeze summary !-~:~ ~'i~' ~ ~]~ ~ "~.J Intervaistreated(measured) See Daily Summary of Operations Treatment description including volumes used and final pressure -, . r.,., :?.-q',o.-,'.. · 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation3/11/90 301 16 3479 1120 160 Subsequent to operation 9/3/90 355 146 2028 1200 120 15. Attachments I & 2 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations X Oil ~ Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.t~~ ~, ~ t.J.,8~ Title (~-,,(~;o~, %~r~_~, ~k-,olrf-, Date Form 10-404 Re~ ~ SUBMIT IN DUPLICATE Attachment #1 TBU Well D-42 Daily Summary of Operations 04/05/90 Rigged up wireline and tested lubricator. RIH w/ retrieving tool for K-storm choke. Unable to retrieve after several attempts. 04/06/90 Attempted to pull storm choke. Bled tbg 1120-100 psi and annulus 1150-0 psi. Pumped 211 bbl 8.6 KCl in annulus. Bullheaded 240 bbl KCl in tbg. Reverse circ lift 700 bbl 8.6 ppg KCl. Monitored well. Tbg built to 125 psi. Csg held 0 psi. Bullheaded 225 bbl 8.8 ppg KCl. Monitored well. Bled tbg to 0 psi. Bled annulus from 100 psi. 04/07/90 Monitored well. Well flowing. Pumped 77 bbl 9.0 ppg brine down tbg. SI well. Monitored well 10 psi. Attempted to bleed off. Well flowing. Pumped 225 bbl 9.0 ppg brine in tbg. SI well. Well dead. Installed BPV. ND tree. NU BOP. Tested BOP. 04/08/90 Pulled hgr to rig floor. Pulled BPV. LD hgr. Circ through choke. Monitored well. Lost 4 bbl/hr. POOH LD 4-1/2" tbg. CO rams. Tested BOP. RIH w/ burn shoe. Tagged fill 0 12,055'. Wash and reamed fill to 12,130'. Milled on pkr ~ 12,130'. 04/09/90 Milled on pkr 12,130'-12,133'. PU off bottom and could not get back down. Circ sweep and spotted Hi-vis pill on bottom. POOH. RIH w/ spear. Tagged fish ~ 12,126'. Speared fish. POOH. Recovered all of fish. LD production pkr. 04/10/90 RIH w/ squeeze pkr and tail pipe to 11,683'. Circ. Set pkr @ 11,578' Mixed pumped 170 sx cmt ~ 15.8 ppg. Had cmt squeeze out 13 bbl early. PullJd pkr and attempted to pump out cmt. POOH. Found cmt in last 7 stand of d.p. LD and washed out 21 jts of d.p. RIH w/ bit. .-- ', 5 ~.~ ,' ,~. ', ",-' ' ' Summary of Daily Oper, .ons Wel 1 D-42 Page 2 04/11/90 RIH w/ bit to 10,126'. Waited on cmt and circ. RIH and ta99ed 0 11,485'. Drld ratty cmt to 11,876'. Circ while waiting on cmt. Drld ratty cmt to 11,939'. Circ while waiting on cmt. 04/12/90 Drld cmt to 12,140'. Circ. Tested perfs to 2100 psi. Bled to 1450 psi. POOH. RIH w/ tailiPipe and pkr to 12,115'. Circ. Set pkr 0 11,353'. Tested annulus to 2100 ps Tested perfs to 3000 psi. Bled to 2000 psi. Released pkr. Pumped 58 sx 15.8 ppg cmt. POOH to 11,366'. Set pkr to 11,600'. Squeezed i bbl ~ 3000 psi. WOC. 04/13/90 WOC. Released pkr. POOH. RIH w/ bit to 10,127'. WOC. RIH. Tagged cmt @ 11,807'. Drld soft cmt to 11,876'. WOC. Drld cmt to 12,092'. 04/14/90 Fin drlg cmt 12,092'-12,140'. Circ sweep. Tested csg to 2,050 psi. Washed and reamed fill to 12,412' Circ. Washed and reamed fill to 12,742'. Circ. Started POOH. Rev circ. Tripped for 7" csg scrapers. 04/15/90 Fin RIH w/ 7" csg scrapers. Rev circ. Tripped for retrievable pkr. Displaced d.p. volume w/ 8.5 ppg FIW Set pkr (a 11,950'. Bled down d.p. to zero. POOH. Tested BOP. RIH w/ bi~ and scrapers to 12,726'. 04/16/90 Displaced hole w/ FIW. Circ. Round tripped 9-5/8" csg scraper to surface. Circ. Mixed and displaced hole w/ 34 KCl water. Circ and filtered 3~o KCl water. 04/17/90 Circ and filtered 34 KC1 water. POOH. RIH w/ pkr and set same ~ 11,869' DPM. POOH. RU and run 3-1/2" tbg and 4-1/2" tbg, externally testing to 5000 psi. 04/18/90 Fin running tbg. Stung into pkr. Tested tbg to 2000 psi. Tested pkr to 1500 psi. Spaced out. Displaced hole w/ inhibited KCl water. Landed tbg hgr. Tested annulus, SSSV and tbg hgr to 2000 psi. Made 2.5" gauge ring run. Set BPV. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugg~pg ~ Time extension ~ ~timulate __ Change approved program __ Pull tubing ~ Variance ~ Perforate z, Other 2. Name of Operator / 5. Type of Well: UNOCAL (Harathon Oil Co- Sub Operatlr) Devel°pment X-~- Exploratory m 3. Address Stratigraphic m P. 0. Box 190247 Anchorage, AK 995~9 Service__ 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 749' FSL, 1,135' FWL0 Sec. 6 - 8N - 13W - SM top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32 - 9N - 13W - SM effective depth At total dep_th 3,660' FWL, 2,661' FSL, Sec. 32 - 9N - 13W - SM 8. Well number D-42 9. Permit number 83-53 10. APl number 50- 733-20205-01 feet 12. Present well condition summary Total depth: meas'ured true vertical 12 830' , feet Plugs (measured) 9,870' feet Effective depth: measured true vertical 12,749 ' feet Junk (measured) feet Casing Length Size Structural Conductor Surface 3,000' 13-3/8" Intermediate 10,510' 9-5/8" Production Liner 2,652' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Cemented 1,000 sx 1,900 sx 750 sx 11. Field/Pool Hemlock Tagged fill La 12,548' WLM 7/86 Measured depth True vertical depth 3,000' 2,601' 10,510' 8,033' 12,828' 9,870' B-1 11,984' - 12,022' MD 9,202' - 9,233' TVD B-2 12,046' - 12,090' MD 9,253' - 9,289' TVD B-2 12.100' - 12,122' MD 9,297' - 9,315' TVD 4-1/2" 12.6# N-80 ASL Tbg to 10,206' MD Pa~kQrsancJ.~S..SV (type/.Qqdm~eas.~re.ddepth) 4-1/2" DC TBRV La 297' uaKer w~< w/ zz- ~eam Assy, 4.875" ID La 10,184'; Otis WD Pkr, 4.00" ID La 12,124' Detailed operations program 13. Attachments 1, 2, Description summary of proposal &3 15. Status of well classification as: BOP sketch 14. Estimated date for commencing operation April 6, 1990 16. If proposal was verbally approved Oil X Gas __ Suspended --APR - z~ 1990 Name of approver Date approved Service I,, l,...m.,, nil & Gas Cons, 13(1~ 17. I hereby ce/~ that the foregoing is true and correct to the best of my knowledge. AflC~iOrag¢ Signed UdL~-.~4 ~--), (~ ~ T,tle ~%, ~ '~..t\ Date .4~_ ._% ~ ~ FOR COMMISSION USE ONLY ' '~''~ JA~~' pproval - ~ 0 Conditions of aPl;Croval:lqbtify Commission so representative may witness No. ~;~p,/cC,Do Plug integrity __ BOP Test __ Location clearance __ ~,~,3 Z_f- , Mechanical Integrity Test __ Subsequent form required lO- ,..,,rovea CoPY -. ORIGINAL SIGNED BY ~V%elU~i~e6/ ~ D Approved by order of the Commission LONNIE C. SMITH ~ Form 10-403 Rev O6/15/88 SUBMIT IN TRIPLICATE Attachment //1 - : · Well D'4~ Procedure 1. Fill tubing annulus with FIW prior-to-moving rig over well. 2. Set BPV. ND tree. 'NU and test BOPE. Pull BPV. 3. POOH and LD 4-1/2" tubing string and GLV's. 0 Mill and retrieve Otis WD packer at 12,124'. RIH with RTTS pkr on work string. Test liner lap by pressuring up on backside. 6. Cement squeeze open perforations (HB-1, 2). POOH. WOC. 7. RIH with 6" bit on workstring. Drill out cement. Test squeeze. 8, Clean out fill to PBTD of 12,749'. POOH. 9. RIH with bit and casing scraper to PBTD. Circulate hole clean. POOH. 10. RIH with 7" pkr on 4-I/2" x 3-1/2" taPered tubing string with redesigned ~- ...... gas lift system. .. ~ ~ ~ ~' ~ ~ , m ~ ~ m' 11. ND BOPE. NU and test tree. Release rig. 12. RIH with 2,1/8" perf guns. Perforate Hemlock Bench 5 from 12,400' - 12,520'. POOH. 13. Turn well to test. 14. RIH with 2-1/8" perf guns. Perforate Hemlock Bench 3 & 4 from 12,160' - 12,370'. POOH. _ 15. Turn well to test. .~,116. =RIH with 2-1/8" perf guns.._. Perforate Hemlock Bench I from 11,984' - ....... i2.~-'02~, ~'~ -POOH. 17. Turn well to test. ::.-- - ...... . Note: Maximum anticipated SBHP is 3500 psi. . . _. : ' l \docs\dvp~d42.doc_ ~ . : ....~ :._ .- RECEIVED APR - ,q 1990 Alaska 0il & Gas Cons. 'AnchOrage Attachment #2 MARATHON OIL COMPAh_o~ DOLLY VARDEN PLATFORM ., BOP STACK Flowllna 13 5/8'x 5000 pal Annular Prevenler : [o° d'I .i,.. r'r'l A r-~-;~"~' Blind flame Choke Line 3' 5000 pal . Drill Deck Floor J _ Spool Pie~ea lo Ca,,Inghead CHOKE MANIFOLD ~) 3' Howco Lo Torque 5000 pal Valve All Flengla Ire 3' SOOO pal Remote AdJualeble Choke ' Preaaure Senior 3/4' Manual 1 1/2" Manual Choke Rig Floor RECEIVED -APR - h 1990 3- Vent Line aska 0il & {las Cons, Com~i~i.~l Il 'Slop Cock Valve ~ ..~ [~B~LeflOpen} . 6 Io Shaker Choke Une 3' 5000 pll Attachment #3 ~OLLY VARDEN P~)~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP , GREASE HEAD i ~ (Hydraulically Activated) ,. LUBRICATOR CHISTMAS TREE POSITIVE CHOKE A~R - h 1990 --- 2' 5000 psi 2' 3000 psi 13 3/8' CASING ·" STATE OF ALASKA ALA,.,KA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing -- Repair well __ Pull tubing __ 2. Name of Operator ~ 5. Type of Well: UNOCAL (Marathon Oil Co - Sub OperAtor) Devel.opm. ent.Qf_ · ! Exploratory __ 3. Address / Stratigraphic_ P. O. Box 190247 Anchorage, AK 99519 Service__ / 4. Location of well at surface Leg A-2 Cond. fl7, Dolly Varden Platform 749' FSL, 1,135' FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 3,311' FWL, 1,886' FSL, Sec. 32 - 9N - 13W- SM At effective depth At total depth 3,660' F~.rL, 2,661' FSL, Sec. 32 - 9N- 13W- SM Perforate x Other 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-42 9. Permit number/approval number 8-665 10. APl number 50-- 733-20205-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 12,830 ' feet Plugs (measured) 9,870 ' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,000' Intermediate 10,510 ' Production Liner 2,652 ' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 4-1/2" 12.6fl N-80 ASL Tbg Packers and SSSV (type and measured depth) Baker PBR w/ 21' 12,749 ' feet Junk(measured) feet Size Cemented Tagged 7/86 Measured depth 13-3/8" 1,000 sx 3,000' 9-5/8" 1,900 sx 10,510' 7" 750 sx 12,828' B-1 11,984' - 12,022' MD 9,202' B-2 12,046' - 12,090' MD 9,253' B-2 12,100' - 12,122' MD 9,297' to 10,206' MD 4-1/2" DC TBRV @ 297' ~ .00_. ~.ID Seal Assy, 4.875" ID @ 10,184'; Otis WD Pkr,:_ 4 " feet fill @ 12,548' WLM True vertical depth 2,601' 8,033' 9,870' - 9,233' TVD - 9,289' TVD - 9,315' TVD 13. Stimulation or cement squeeze summary 14. Intervals treated (measu red) @ 12,124' Treatment description including Volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9/88 2i3 70 1024 960 485 Subsequentto operation 11/88 96 109 3098 1240 140 16. Status of well classification as: Oil ~ Gas_ Suspended __ 15. Attachment~: ¢/1 Copies of Logs and Surveys run . Daily Report of Well Operations Service 17. I hereby certify that the foregoi ng is true and correct to the best of my knowledge. Title Enviro~tal ENqineer Date 11/21/88 SUBMIT IN DUPLICATE Signed ~ ,/~'~ ~~ Form 10-404 Rev 06/15188 Roy D. Roberts Attachment #1 TBU Well D-42 Daily Summary of Operations 10/4/88 RU E-line & PT lubricator to 2500 psi, OK. MU 3-3/8" hollow carrier guns, 6 SPF, 60° phasing. RIH and perforate Bench 2 from 12,102' - 12,122' DIL. POOH. lO/5/88 Made several attempts to RIH w/perforating guns but we were unsuccessful due to tight spots and obstructions in well. RD and prepare to run gauge rings. lO/6/88 RU wireline and PT lubricator to 2500 psi. RIH w/3.8" gauge ring and cut scale @ 9,609' WLM to tubing tail. Ran down and tagged isolation packer @ 12,126' WLM. POOH. RIH w/ 2.5" ring from isolation packer @ 12,126' WLM to fill @ 12,488' WLM. POOH, RD. RU E-line, PT to 2500 psi. RIH w/ 3-3/8" hollow carrier guns, 6 SPF, 60° phasing and perforate 12,080' to 12,090' and 12,100' - 12,102' DIL. POOH. Top 10' of guns did not fire. 1017188 RIH w/ 2-1/8" Enerjet guns, 4 SPF, 0° phasing, correlate and perforate Bench 2 from 12,068' - 12,090' DIL and 12,046' - 12,068' DIL. POOH. 10/8/88 Made two perforating runs using 2-1/8" Enerjet guns, 4 SPF, 0° phasing. RIH and perforated Bench 1 from 12,003' - 12,022' DIL and 11,984' - 12,003' DIL. POOH, RD. em/72/DVP2 STATE OF ALASKA · : ALASr,,A OIL AND GAS CONSERVATION COM~v,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , } Re-enter suspended well -- Alter casing T~me extension Change approved program Plugging "~. Stimulate ~ Pull tubing Amend order .r Perforate ~X Other 2 Name of Operator 5. Datum elevation(DF or KB) UNOCAL (Harathon 0il Company - Sub Operator) 106' KB above HSL feet 3 Address 6. Unit orProp~ty n~me_ P. O. Box 190247 Anchorage, AK 99519 Trading ~ay un~ 4. Location of well at surfaceLeg A-2 Cond. ~f7, Dolly Yarden Platfor] 749' FSL, 1,135' FWL, Sec. 6 - 8N - 13W- SM At top of productive ~nterval 3,311' FWL, 1,886' FSL, Sec. 32- 9N- 13W- SM At effective depth At total depth 3,660' FWL, 2,661' FSI'., Sec. 32- 9N- 13~- SH 7. Well number D-42 8. Permit number 83-53 9. APl number 50-- 733-20205-01 10. Pool 'Hemlock 11. Present well condition summary Total depth: measured true vertical 12,830 ' feet Plugs (measured) 9,870 ' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,000 ' I ntermed iate 10,510 ' Production Liner 2,652' Perforation depth: measured 12,749' feet feet Size Junk (measured) Tagged fill @ 12,548' WLM 7/86 Cemented Measured depth True Vertical depth 13-3/8" 1,000 sx 3,000' 2,601' 9-5/8" 1,900 sx 10,510' 8,033' 7" 750 sx 12,828' 9,870' B-1 11,984' - 12,022' MI) 9,202' -9,233' TVD true vertical B-2 12,046' - 12,080' MD 9,253' - 9,281' TVD Tubing (size, grade and measured depth) 4-1/2" 12.6¢f N-80 ASL Tbg to 10,206' ND Packers and SSSV (type and measured depth) 4-1/2" DC TBRV @ 297' Baker PBR w/ 21' Seal Assy~ 4.875" ID @ 10,184'; Otis W-D Pkr, 4.00" ID @ 12,124' 12.Attachments 1 & 2 Description summary of proposal _~; Detailed operations program _E-} BOP sketch ~ 13. Estimated date for commencing operation R ~ E . E~V~ September 1988 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . ,~-, . /"~L~..-~ ~ Title .... ~o~' D. Ro]~rts Commission Use Only Anon0rage Date 8/29/88 Conditions of approval Approved by Notify commission so representative may witness I Approval No. ~ Plug integrity I~. BOP Test © Location clearanceI Approved Copy 0Ri61NAL $1~NED BY Returne_(J. LONNIE C. SMITH ~-~' ~' - by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #1 TBU Well D-42 Procedure to Perforate 1. RU slickline and pressure test lubricator. 2. RIH w/ 3.50" gauge ring and tag fill. POH. RD. 3. RU electric line unit and pressure test lubricator. 4. RIH w/ collar locator and perf guns loaded 6 SPF and perforate as follows: Run Bench Interval DIL 1 B-2 12,100' - 12,122' 22 2 B-2 12,080' - 12,090' 10 Test Well for 12 to 24 hours. Feet 3 B-2 12,060' - 12,080' 20 4 B-2 12,046' - 12,060' 14 5 B-1 12,002' - 12,022' 20 6 B-1 11,984' - 12,002' 18 5. POH and RD electric line unit. 6. Put well back on production and obtain tests. GDM/em/72/D~rP 2 Note: Bottom hole pressure not exl~ected to exceed 3500 psi. Perforating will be ~.~ne under flc~ing conditions. Attachment #2 E-)LLY VARDEN p LA~-'~FO R M Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) BR - ICATOR 4~ ~t/~1'"6~-'5000 psi CHISTMAS TREE POSITIVE CHOKE 2' 5000 pal ]~ 2' 3000 psi 13 3/8' CASING Union Oil and G' ~ivision: Western Region Union Oil Company of California P.O. Box 6247. Anchorage, Alaska 99502 Telephone: (907) 276-7600 union July 8, 1985 Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99502 ~' Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS & SUBSEQUENTS Attached please find Sundry Notice Intentions for D-42 & D-7RD & Subsequents for D-29RD, & D-17RD, Trading Bay Unit, McArthur River Field. Please return the approved Sundry Notice of Intentions to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/ti Attachments J U L 0 919~5 Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2. Name of Operator Union Oil Company of California* 3. Address P. O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: Leg A-2, Cond. #7, Dolly Varden Platform 749' FSL, 1135' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18730 7. Permit No. 83-53 8. APl Number 5~33-20205-01 9, Unit or Lease Name Trading Bay Unit 10. Well Number D-42 11, Field and Pool McArthur River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estirr~a~te~date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ~'bC~/ VED ~laska 0il ~ Gas .. TBU WELL D-42 SUBSU~ACE SAFETY VALVE ~ c°/~s. C- , It ~s ~arathon's intention to install a pressure balanced 8to~m Choke in the well as a sub-surface safety valve on ~uno 28~ 1985. . . RU and test the lubricator to 2500 psi. SI the well. RIH and lock out the flapper of the tubing retrievable safety valve. RIH and set a Storm Choke in the profile of the tubing retrievable safety valve at 297'. Return the well to production and test the Storm Choke. Verbal approval to set the Storm Choke was received from Blair Wondzell of AOGCC on June 27, 1985, by W. J. Laverdure. *Marathon Oil Company - Sub Operator 14. I hereby certif~~,ing~~l~m~rect, to the best of my knowledge. Signed LAWRENCE 0. CUTTING Title ENVIRONMENTAL SPECIALIST The space below for Commission use Date 07 / 08/85 Conditions of Approval, if any: IIIIGINAL ,SIGlt[ll BY HARRY W. KUGLER Approved by. COMMISSIONER Approved Returned By Order of the Commission Date Form 10-403 ~,:~, 7-1 -Rd Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 484 ~£v. 3-83 · D'A;:i"E 0c't. 31, 1983 MARATHON OIL COMPANY FIELD HISTORY OF OIL OR GAS WELL -- bLoCK WELL NO. D-42 LEASE Trad±ng Bay Un±t SEC. PARISH STATE Alaska COUNTY Renal Peninsula Boroug~h 106 ' KB __ ELEV. 6 8N ,TWP MEASUREMENTS TAKEN FROM fToP OF OiL STRING ELEV ToP OF ROTARY TABLE ~ ELEV. ~ GRD. OR MAT ELEV._ McArthur River 13W /~ R. HISTORY PREPARED BY L. Y. Durham TITLE Secretary It is of the greatest importance-to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all-tests, ali completion operations and procedure, etc. DATE 1983 '05-08 05-09 _. __ 05-10 05-11 05-12 05-13 -- 05-14 05-15 05-16 05-17 16,606 'TD 16,606'TD 16,606 'TD 16,606'TD 16,606'TD 16,606'TD 16,606 'TD 16,606 'TD 16,606'TD 16,606'TD TBU Well D-42 (Marathon AFE f~4870) Moving equip & RU on Rig fi77, Well D-23. Plan to plug .& 'abandon Hemlock in D-23, cut & recover 9-5/8" & 13-3/8" csg to approx 600', & then drill new Hemlock producer D-42. PropOsed TD of.D-42 is 12,948'MD & 9984'TVD. Cont general RU of Rig ~77 on TBU D-23. Cont RU of Rig f~77 on D-23. RU WL. Pulled BV. RD WL. RU lines to'tbg & displ tbg w/ 132 bbl FIW. RU WL. RIH w/ 2-1/8" perf gun & perfd tbg @ 15,304'. POH w/ & RD WL. Displ well w/ FIW. Began mixing mud to 9.5 ppg. Fin mixing mud to 9.6 ppg. Displ FIW w/ mud. Circ & cond mud for 1 full circ. SD & checked for flow--had small flow on tbg side. Resumed circ thru perfs in tbg @ 15,304 o Circ & killed well. Set BPV. ND X-mas tree. NU & tstd BOPE--OK. MU landing j t in tbg hgr & attempted to pull hydraulic pkr @ 15,357'. Pkr would not.pull free. RIH ~w/ free point & CCL on WL--could not get below 3661' WLM. POH. Circ & cond 9.0 ppg gas cut mud to 9.6 ppg. RIH w/ CCL & jet tbg ctr--had to pump dwn f/ 11,700- 15,229' WLM. Attempt to cut 3~" tbg @ 15,229' --did not come free. Stuck WL tools--worked free & POH. Ctr fired OK. RIH & worked free point 'to ll,664'--tbg free here. Jet cut tbg @ ll,899'WLM. Tbg free. RD WL. LD tbg hgr & 2 jts. Circ mud. Fin circ. POH & LD 363 jts 4~" tbg, 9 jts 3~"~ tbg, & GL equip. Chng to 5''~rams in BOP & test. PU DP & RIH w/ OS. Fin RIH w/ overshot. Tagged top of tbg @ ll,919'DPM. PU kelly & worked over fish. Pulled tbg free w/ pull of 60,000~ over string wt. POH & LD fishing tools, 106 jts 3~" tbg & GL equip. Left pkr assy, circ slv& 125' 3~" tbg in hole. PU 6" bit & scrpr. Cont RIH w/ 6" bit & scrpr. Set dwn @ 14,946' & could not wash deeper. Circ & cond mud. POH. PU 7" cmt rtnr. RIH & set rtnr @ 14,910'DPM. RU cmtrs. Attempted to pump int Hemlock perfs--could not pump in w/ 4500 psi. Spotted 50 sx cmt on top of rtnr. Rev circ DP clean. POH to 11,700' Spotted 72 sx cmt 11,700-11;500'. POH to 11,239'. Well History - Dolly Varden No. D-42 Page 2 05-18 16,606'TD 05-19 16,606'TD 05-20 16,606'TD 05--~1- .... 16,606'TD 05-22 16,606'TD 05-23 16,060'TD 05-24 16,606'TD 05-25 16,606'TD 05-26 16,606'TD 05-27 16,606'TD 05-28 16,606'TD 05-29 16,606'TD Fin rev circ. POH & LD 3~" DP. RIH w/ 8½" bit & scrpr to 1500' CBU. POH. RIH w/ 9-5/8" cmt rtnr on DP. Set rtnr @ 1630' & dropped seal bar. POH & found seal bar stuck in setting tool. RIH 10 stds. C&C mud to 9.1 ppg. POH. RU WL. Ran gyro surv 600'-surf. Ran CCL 823'- surf. RD WL. f Fin LD 5" DP. Test BP @ 1030' & 9-5/8" csg to 1000 p~i as per AOGCC. RIH w/ 9-5/8" csg ctr & made initial cut @ 608'. POH~& redress ctr. Made second cut @ 49' RKB (5' under head). ND & PU BOP &.tbg spool. Prep to pull 9-5/8" csg slips @ 0700 hrs. Welded 9-5/8" slips to csg. NU BOP. Engaged 9-5/8" w/ spear & pulled 6.39' ~free. PU BOP & recd slips. NU BOP. Made cut #4 in 9-5/8" @ 63'--could not pull w/ spear. Made cUt #5 @ 56'. Jarred free w/ spear--rec 7.03'. RIH w/ spear & jarred & POH w/ 6.09' csg. CO w/ 1°~''~ bit to 63' RKB. Made cUt #6 @ 102' RKB--could not jar free. Made cut #7 @ 83' RKB. Presently jarring on 9-5/8" csg fish w/ top @ 63' RKB. Made cuts in 9-5/8" csg @ 76', 93', & 110'. Rec 47.1' csg last 24 hrs. Made cuts @ 140' & 125' RKB. Presently jarring on 9-5/8" csg fish w/ TOF @ 110' RKB. Made cuts in 9-5/8" csg @ 117~ 150', 165', 178' & 216'. Rec 105.4' csg last 24 hrs. esently top of 9-~/8" fish @ 216' RKB. Made cuts in 9-5/8" csg @ 235' ~55', 296' ~ 316'. Made cut @ 335'. TOF 316'. CO 9-5~8 stub w/ ~½ bit. Made cuts in 9-5/8" csg @ 324' 329' 355' 375' 395' TOF 375'. Made cuts in 9-5/8" csg @ 414', 434', & 452'. Made cut @ 490'--could not pull fish. Made cut @ 471'--could not pull fish. Chng out ctg tool w/ TOF @ 452'. RIH & made cut #36 @ 472' Made 2 attempts to jar csg fish free, but unscrewed ~ishing string on first try & 'parted bumper jars on second try. Fished & retrieved fishing tools. Made cut @ 462'. RIH w/ spear & rec 9.49' fish. CO trip w/ 12¼" bit to T0F @ 462'. RIH w/ spear--could not move fish. Made cut in 9-5/8" csg @ 467'. Jarred w/ spear--could not move fish. Recut @ 467'. RIH w/ spear & jarred fish free. POH & rec 4.9' csg. CO to TOF @ 467' w/ 12¼" bit. RIH w/ spear & jarred on fish--could not move fish. Recut @ - 472'. Jarred on fish--no move. Made cut @ 474' after removing knife stops. RIH w/ spear & jarred fish @ 467'. TOF 467' jarred w/ no movement. Rec spear & POH. Made csg cut ~ 477'. RIH w/ spear--jarred on fish--rec 6.6'. CO w/ 12~" bit. RIH w/ spear. POH & rec 2.3' csg. CO t~ T0F @ 477' w/ 12~" bit. CO inside 9-5/8" csg to 505' (bridge). Made cut @ 491~'--could not jar free. Made cuts 484' (partial) & 485'(complete). RIh w/ spear w/ @ 477'. Jarred on 9-5/8" csg fish w/ top @ 477' Rec 7.3'. Made 3 additional cuts & rec 26.5'. Top of ~-5/8" fish 510'. CO inside fish. Well History - Dolly Varden No. D-42 Page 3 05-30 16,606'TD 05-31 16,606'TD 06-0t 16,606'TD 06-02 16,606'TD 06-03 16,606'TD 06-04 16,606'TD 06-05 16,606'TD 06-06 16,606'TD 06-07 16,606'TD Fin CO trip. Made 5 cuts.~ Pulled & rec 51.5' 9-5/8" csg. TOF 561'. CO trip w/ 12~" bit & csg scrpr. Fin CO trip. Cond mud & reduce visc. POH LD 9-5/8" fishing tools. RU WL & ran Csg Clr Log on 13-3/8" csg to 561'. ND 13-3/8" BOP. NU 30" riser w/ flow nipple. RIH w/ ctr & cut 13-3/8" csg @ 55' RKB. RIH w/ spear. Pulled & rec 7.7'. RIH w/ ctr. ! Cut 13-3/8" csg @ 66'. Pulled & rec 11' csg. CO to TOF @ 66' w/ 26"bit. CO inside 13-3/8" w/ 12¼" bit. Cut 13-3/8" csg @ 77'--rec 11.2'. CO w/ 26" Bit to TOF @ 77' &~'inside fish'W/ 12¼" bit. Made cut @ 94' but could not pull. Made @ 85' but could not jar free icsg clr w/ centralizer @ 82'i. -RIH w/' 16" washpipe & WO fish 77-85'. Cmt very hard (made 8' in 24 hrs). RIH w/ spear. Engaged top of 13-3/8" fish @ 77'. Pulled & rec 7.7' csg. TOF @ 85'. CO inside 13-3/8" fish w/ 12~" bit. POH & releaSed Rig #77 from D-42 to Well D-1. Skid rig over D-] RU WL. Pull malfunctioning BV. Run new valve & test-- OK. RD WL. Skid over D-42. Install 30" riser. RIH w/ spear--jarred & moved fish up hole 2'--could not pull. Released spear. RIH w/ 16" WP & WO fish 85-92'. Rec. 9.6' csg. Made CO trips w/ 26" & 12~" bits. Cut 13-3/8" csg @ ll5'--could not jar free. WO 13-3/8" fish 95-117'. RIH w/ spear & rec 20' csg. CO w/ 26" & 12~" bits. Cut 13-3/8" csg @ 122' (clr & centralizer @ 119').~ RIH w/ spear & rec 7.2' csg--did not rec centralizer. CO inside 13-3/8" csg to 179'--did not tag centralizer. Cut 13-3/8" csg @ 148'. RIH w/ 16" WP. Ream 114-120' & attemp to free 13-3/8" cent. POH w/ no rec. RIH w/ 17-3/4" FB mill--reamed 114-121'. Milled on junk 121-122'. POH. RIH w/ 16" WP & WO 13-3/8" csg 122-134'. RIH & cut 13-3/8" csg @ 139'. Made 3 trips w/ spear--engaged 13-3/8" fish, but spear would pull free w/o pulling fish. Wait on ext to get deeper into fish. TOF @ 122'. RIH w/ 5' ext between grapple & stop ring of spear. Work~ spear into fish to 127'(TOF 122')--spear pulled spear. Recut csg @ 139', made 26" & 12~" bit trips to clean hole while waiting on another ext. RIH w/ 13' ext--latch fish & POH. Rec 16.2' 13-3/8" csg. Fish was cut in half w/ WO string total of 12.8' Made CO trip w/ 26" bit. CO inside fish w/ 12~". Puiled 9.8' csg w/ spear--TOF @ 148'. Cut csg @ 153.5'. Pul~ed 5' csg w/ spear--TOF @ 15~3.5'. Making CO trip w/ 26 bit. CO trip w/ 12¼" bit. Cut 13-3/8" csg @ 192'. Jar on fish. Parted pin on 7-3/4" DC. Fished tool string. RIH w/ spear, but could not pull fish. RIH w/ ctr--had difficulty getting into TOF--dressed w/ 12¼" string mill. RIH w/ ctr & cut 13-3/8" csg @ 164'. RIH w/ spear & jarred fish free--rec 12.3'. CO w/ 26" bit. CO inside fish w/ 8~" junk mill & 12¼" string mill. RIH w/ spear & rec 26.2' csg. CO conductor w/ 26" bit. CO inside 13-3/8" fish w/ TOF @ 192'. Cut 13-3/8" csg @ 228, 200'. Lost guide off ctr Fished & rec guide. RIH w/ spear--could not jar fish fre~ POH & MU guide w/ bullnose, stringmill, & ext to find fist & guide WO shoe over fish. RIH & work into fish w/ guide & reamed dwn to TOF. POH to check connection. RIH & WO fish. Welt History - Dolly Varden No. D-42 Page 4 06-08 16,606'TD 06-09 16,606'TD ~06-10 16,606'TD 06-11 16,606'TD 06-12 16,606'TD 06-13 16,606'TD 06-14 16,606'TD RIH w/ spear. Pulled & rec 4.8' csg. RIH w/ WP & WO 13-3/8" fish 212-252'--torque increased. POH. RIH w/ spear. Pulled & rec 27.4' csg. MU CO string to dress TOF & CO inside. RIH w/ 12~" string mill. Dressed TOF @ 224' & CO 13-3/8" csg to 257'. POH. RIH w/12¼" bit & CO 13-3/8" csg to 355'. POH. RIH & cut 13-3/8" csg @ 248'. POH. RIH w/ spear. POH LD 23.4' csg. RIH & CO conductor to 240' ~w7 26" bit. POH. RIH & washed over 13-3/.8" csg 252-257'. POH after torque increased. Marks on shoe indicated 13-3/8" csg is next to conductor wall. Chngd WO shoes. RIH & washed over 13-3/8" csg 257-262'. POH. RIH & cut 13-3/8"csg @ 260'. RIH w/ spear. Rec 12.3' csg. Marks indicated WO shoe has been shoving OD off 13-3/8" csg--max metal loss = ~". Cut 13-3/8" csg @ 265'. Could'not ~jar 5' fish free. RIH & recut 13-3/8" csg @ 265'. 'POH. RIH w/ spear & rec 5.1' csg--TOF @ 265' CO cond to 264' w/ 26" bit. CO 13-3/8" stub to 561''w/ 12~" bit. Cut 13-3/8" csg @ 400'. RIH w/spear & ' J-safety jr. Set spear in 13-3/8" stub. Unlatched J-jt (left spear in stub @ 13-3/8" csg). POH. RIH w/ 8~" bit to drill along the outside of 13-3/8" csg--could not get 3~" hole started. RIH w/ OS w/ 11-3/4" bowl--could not catch spear. RIH w/ J-retrieving tool--could not catch spear. RIH w/ OS w/ 8-1/8" bowl. Caught & released spear. CO cond to 265' w/ 26" bit. RIH w/ spear & J- safety jt--could not work into 13-3/8" stub. RU spear w/ ½" jet inside of bullnose. RIH w/ spear & jetted into fish--OK. Rec safety j t leaving spear & lower half safety jt in TOF @ 265'. RIH w/ 8~" bit & drld cmt along side 13-3/8" fish 265-384'. Circ hole clean. POH. RIH w/ OS & rec spear & safety j t. RIH w/ ctr & cut 13-3/8" csg @ 285' RIH w/ spear--jetted into TOF @ 265'. Jarred on fis~. Parted oil jars. POH. -RIH w/ OS & fished 0J & spear. POH. RIH w/ ctr & cut 13-3/8" csg @ 275'. RIH w/ spear. Fin RIH w/ spear & engage TOF @ 265'. Jarred. POH w/ 10.4' csg. RIH w/ 26" bit & CO to TOF. RIH w/ spear & jarred on 10' fish--no movement. Rec spear & POH. RIH & cut 13-3/8" csg @ 290'. RIH w/ spear. Jarred. POH w/ 15' csg--partial cut @ 285'. CO to TOF @ 290' w/ 26" bit. Cut 13-3/8" csg @ 306'. RIH w/ spear. Jarred. Jars failed. POH & chng OJ. RIH w/ spear--jarred & POH w/ 15~' csg. CO to TOF w/ 26" bit. RIH w/ ctr-- could not get below 316'. POH. RIH & CO fish w/ 12~" bit to 561'. ~ Cond mud @ 561'. POH. Cut 13-3/8" csg @ 343'. RIH w/ spear. Could not jar 37' fish free. POH. Cut 13-3/8~' csg @ 320' RIH w/ spear & jarred fish free. POH & LD 13.9' 13-3~8" csg. TOF @ 320' CO cond to 320' w/ 26" bit. RIH w/ spear & jarre~ fish free. POH & LD 23.9' 13-3/8" csg. CO cond to 344' w/ 26" bit. Cut 13-3/8" csg @ 357'. RIH w/ spear & jarred fish free. POH LD 13.2' 13-3/8" csg--TOF @ 357'. CO cond to 357' w/ 26" bit. RIH w/ ctr. Hit bridge in 13-3/8" csg @ 382'. POH. RIH w/ 12¼" bit & CO inside 13-3/8" fish. Hit bridge @ 382'. CO to 414'. Cut 13-3/8" csg @ 383'. RIH w/ spear. POH & rec 26.1' csg. CO w/ 26" bit to TOF. RIH w/ spear~ POH & rec 16.9' csg. CO w/ 26" bit to TOF @ 400'. RIH w/ 16" W0 shoe w/ 12' guide stinger. WO 13-3/8" csg 400-2'. PU off fish--unable to get back over fish. Circ & increased visc to 150. Circ out lots of cmt & metal. RIH w/ 8~" junk mill & 12~" string mill to 561'. RIH w/ 16" WO shoe--WO fish. WO 402-4'. PU above 13-3/8" fish. Could not work back over fish. Well History - Dolly Varden No. D-42 Page 5 06-15 16,606'TD .06-16 16,606'TD 06-1~7 16,606'TD 06-18 16,606'TD 06-19 16,606'TD 06- 20 16,606'TD 06-21 16,606'TD 06-22 16,606'TD 06-23 16,606'~TD 06-24 16,606'TD POH w/ WO shoe & stinger. Chngd WO shoe & RIH--could not work shoe over 13-3/8" csg stub. POH. RIH & cut 13-3/8" csg @ 404'. RIH w/ spear--could not engage fish. MU 5' ext on spear & RIH--could not engage fish. MU kick sub on spear & RIH--could not engage fish. MU DP stinger beneath spear & RIH. POH LD 4.1' 13-3/8" csg. TOF was split by WO shoe. Co cond to 404' w/ 26" bit. RIH w/ 17-1/8" WO shoe & guide assy. ~0 13-3/8" csg 404-6'. POH. RIH w/ 8~" junk mill to 561 . Cond mud while building ~ stabliizer for WO assy. Fin building.stabilizer for WO guide assy. MU guide assy, 5' WP & WO shoe. RIH & ~WO 13-3/8" csg 404-9' POH. MU new guide assy, 1 jt WP & WO shoe. RIH & WO {3-3/8" csg 409-26' (btm conductor @ 408'). WO 13-3/8" csg 426-39'. POH. MU WO shoe on 2 jts WP & RIH. WO 13-3/8" csg 439-47'. POH.' Left WO shoe & 1 jt WP in hole. Top of 16" WP fish @ 406'. Top of 13-3/8" csg stub @ 404' RIH & cut 13-3/8" csg @ 449'. RIH w/ spear. POH LD g5.6' 13-3/8" csg. MU spear for 16" WP & · RIH. Rec 45.6' 13-3/8" csg last 24 hrs. Total rec to dat 401.5'. Rec 16" WP fish on 2nd attempt--had to modify spear nose & stop ring. RIH w/ WP & guide stinger to 13-3/8" stub @ 449'. WO 449-83'. Ran spear & rec 27.2' csg to 477'-- -ulti-string cut made during 9-5/8" csg rec. Built-up stab blades on WP stinger & check all conn. RIH w/ 16" WP &3wO~l'3'-3/8''oz csg 483-512' Circ hole clean. POH. Cut 1 - 8 csg @ 508'. RIH ~/ spear & rec 31.2' csg. Made CO trip inside fish. RIH w/ WP & WO 512-34'. TOF 13-3/8" csg @ 508'. Top of 9-5/8" csg fish 561'. WO 13-3/8" csg 534-41'. Circ hole clean & POH. Cut 13-3/8" csg @ 535'. RIH w/ spear. POH LD 26.7' 13-3/8" csg. i,RIH w/ WO assy & washed to 541' WO 13-3/8" csg 541-6~- Circ hole clean & POH. PU ~ulti-string csg ctro Top of i3-3/8" stub 535'. Top of 9-5/8" stub 561'. RIH & cut 9-5/8" & 13-3/8" csg @ 567' RIH w/ spear. P0H LD 4.4' 9-5/8" csg cmtd inside 32.8' i3-3/8" csg. RIH w/ new WO shoe & WO 13-3/8" csg 569-601'. POH. RIH w/ 8~" bit-to 607'. Circ hole clean & POH. RIH w/ spear. POH LD 36~' 9-5/8" csg cmtd inside 36~' 13-3/8" csg. 9-5/8" csg against wall of 13-3/8" csg. LD all fishing tools. RIH w/ 8~" bit to 710'. Top of 13-3/8" & 9-5/8" stubs are 603'. POH w/ 8~" bit~. RIH to 650' w/ 0EDP. Spotted 202 sx kick off plug 650-480'. POH LD DP. ND 30" riser. NU~ 20" diverter. - Function tstd 20" diverter. RIH w/ 12¼" bit & tagged soft cmt @ 500' Cmt had been in place 24+ hrs. Washed & rotated th~u very soft cmt to 601'--hit hard cmt @ 601'. Circ hole clean & POH. RIH w/ OEDP to 601' Spotted 225 sx cmt plug 601-450' CIP 2145 hrs- 6-~2-83. POH to 415' & circ hole clean. 'POH. WOC. WOC until 1600 hrs, 6-23-83. RIH w/ 12¼" bit. Hit cmt stringer @ 520' & hard cmt @ 524'. Drld hard cmt to 526'. POH. RIH w/ 12-¼" bit, bent sub, & Dyna-Drill. Drld & surv 12-~" hole 526-839'. Well History - Dolly Varden No. D-42 Page 6 06-25 1706'TD 06-26 1930'TD 06-27 2332'TD 06-28 2359'TD 06-29 2400'TD 06-30 2600'TD 07-01 3005'TD 07-02 3005'TD 07-03 3005'TD 07-04 3005'TD 07-05 3005'TD Drld & surv 12~" hole 839-1106' POH w/ Dyna-Drill. RIH w/ 12~" bit on an angle building BHA. Drld & surv 12¼" hole 1106-1706'. Drld & surv 1706-1853'. POH. RIH w/ 12~" bit on Dyna- Drill #2. RIH w/ steering tool & oriented DD. Drld 1853-1920'--steering tool malfunctioned. POH w/ steering tool--steering tool OK. POH w/ DD--orientation equip OK. RIH w/ 12~" bit on DD #3. RIH w/ steering tool & oriented DD. Drld 1920-30'--steering tool malfunctioned. POH w/~ steering tool--steering tool OK. Attempted to check DE orientation w/ single shot gyro--gyro failed. POH w/ DD. Serv rig. RIH w/ DD #4. Checked tool face orienta- .tion w/ single shot gyro. RIH w/ steering tool & oriented DD. Drld 12¼" hole 1930-2332' w/ surv @ 2002' & 2190'. POH w/ DD. RIH w/ locked BHA--could not work BHA past 1883'. POH. RIH w/limber BHA. Reamed DD #4 run 1883-2266'. Surv taken shile reaming indicate hole may have been sidetracked. Fin surv @ 2206' (surv depth reported 6-27 was in error). Surv confirmed hole had been sidetracked @ +1850'. Drld 2266-359'--Hole #2. Circ & surv @ 2299'. POH. RIH w/ 12~" bit on locked-up BHA to 2359'--Hole #2. RIH w/ 12~" bit on DD #5 to 2332'. Reamed to 2341'. Surv confirmed DD was in Hole #1. Attempted 3 additional times to re-enter Hole #2 by orienting DD while RIH-- DD went into Hole #1 every time. POH w/ DD. RIH w/ 12¼" bit on locked up BHA. Fin RIH to 2359' w/ 12¼" bit on stiff BHA. Circ & surv-- surv confirmed bit was in Hole #2. Drld 2359-400'. Surv @ 2400' POH. PU 17~" hole opener & RIH to 526'. Opened i2¼" hole to 17½" 526-1730'. Opened 12¼" hole to 17½" 1730-2380'. CBU. P0H LD hole opener. RIH w/ 12~" bit on stiff BHA to 2400'--surv confirmed bit in Hole #2. POH. RIH w/ 12~" bit on DD #6 to 2400'--surv confirmed DD in Hole #2. Drld & surv 12~" hole 2400-600'. DD 2600-772'. POH w/ steering tool. SS surv @ 2723'. POH w/ DD.- RIH w/ locked 12¼" assy to 2400'. Reamed DD run 2400-772'. Dr~ to 3005'. Circ ~ surv. POH. RIH w/ 17~" HO to 238 & opened to 2570 . Opened hole to 17~" 2570-3003'. C&C. POH & cleaned HO & stab. RIH ! C&C for csg. POH. RIH w/ 13-3/8" K-55 68# csg. Fin running 13-3/8" K-55 68# butt csg w/ float shoe @ - 3000', float clr @ 2920'. C&C. RU & tstd cmt lines. Pumped 50 bbl fresh wtr ahead of 1200 sx C1 G blend cmt. Bulk cmt line plugged. Switched to neat C1 G tail slurry & pumped 100 sx. Press up & could not pump w/ 3000 psi. Checked surf lines--OK. CIP @ 1710 hrs. RD cmt lines. Hung off 20" stack. Fin bracing 13-3/8" csg to 33" cond. Cut off & belled 13-3/8" csg @ 41'. NU 20" stack/diverter. Drld cmt 42-1876' w/ FIW. Drld cmt out of 13-3/8" csg 1876-2917'. Circ & POH. w/ 13-3/8" csg scrpr. Circ clean. Displ FIW w/ mud. C&C. POH. RIH Well History - Dolly Varden No. D-42 Page 7 07-06 3005'TD 07-07 3010'TD 07-08 3010'TD 07-09 3010'TD 07-10 3045'TD 07-11 3710'TD 07-12 3957'TD 07-13 4166'TD 07-14 4586'TD 07-15 5100'TD 07-16 5888'TD POH w/ 13-3/8" csg scrpr. ND & PU 20" stack. RU WL & ran thru spear--RIH w/ spear & latched 13-3/8" csg--PU csg. Ran free point. Csg free @ 512' but no movement @ 550'. Reweld brakes to center 1~-3/8" csg in 33" cond. Release spear, POH, & RD WL. NU 20" stack. RIH w/ 12~" bit. Drld cmt 2917-21'. Drld fit clr 2921-23', & drld firm cmt 2923-73'. Fin drlg firm cmt out of shoe jt & drld float shoe. POH w/ 12¼" bit. RIH & set 13-3/8" cmt rtnr @ 2757' DPM. Tstd 13-3/8" csg shoe to 13.4 ppg E~ w/o leakoff. POH w/ stinger. RIH & perfd 13-3/8" csg @ 2480-81' w/ 4 SPF. RD WL. RIH & set 13-3/8" cmt rtnr @ 2341'DPM. Pump dwn DP & thru perfs @ 2480' & circ back to surf. C&C mud prior to cmtg 13-3/8" csg. Circ prior to cmtg. Mixed & pumped 1000 sx-C1 G w/ 6% gel followed w/ 296 sx C1 G neat. Cmtd thru rtnr @ 2341' &' csg perfs @ 2480-81'. Good cmt returns to surf'. CIP @ 1700 hrs, 7-7-83. Pulled out of rtnr w/ stinger & circ out. POH. ND 20" BOP, riser, & diverter lines. Cutoff 13-3/8" csg & weld on starting head. Begin tstg head @ 0700 hrs. Fin tstg wellhead. NU BOP. Tstd BOP--witnessed by AOGCC. RIH w/ 12¼" bit & suck BHA. Tag TOC @ 2302' (rtnr @ 2341'). Drld'cmt to 2317'. Fin drlg cmt 2317-41' (top of rtnr). Tstd csg to 1400 psi--OK. Drld rtnr @ 2341' Drld hard cmt below circ perfs @ 2480-81' & CO to 2n~ rtnr @ 2757'. Tstd csg to 700 psi--OK. Drld rtnr @ 2757'--pushed to btm & drld formation 3010-15'. CBU. POH. RIH w/ packed BHA. Drlg 3015-45'. ROP slow w/ lots of torque. Circ to clean hole Circ. POH--BHA OK. RIH w/ 11" globe basket. Cored 3045-47'. POH. No junk in basket. RIH w/12¼" bit-- dripped 3 stabs. Drld 3047-107' to bury BRA--no excessive drag or torque. Circ & surv. POH. MU packed BHA & RIH. Drld & surv 3107-710'. Drld & circ up samples 3710-803'. (Costs related to corin Grayling Gas Sands charged to AFE #4734.) Circ & surv. POH. RU WL & RIH w/ DIL/SP/GR--could not get below 3106'. Chngd logging tool configuration--RIH--could not get below 3160'. Logged from 3160-2000' & made tie-in w/ Well D-7. RIH & drld 3803-957' & circ up samples. POE RIH w/ core barrel. Plugged barrel. POH & unplug barrel. Unplugged core, bbl. RIH w/ 12¼" bit--tagged bridge @ 3890'. CO to 3947'. C&C mud. POH. RIH w/ core bbl. ' Cut Core #1 3957-77' (20'). Attempting core of Grayling Gas Sands A-6 interval. POH. Rec 14'. MU BHA. RIH & reamed 3957-77'. Drld & surv 3977-4166'. Drld 4166-412' Circ & surv. POH. RU WL. Ran DIL/GR/ SP 4114-3000' ~ csg shoe (could not work deeper). Correlated to Well D-7. RD WL. RIH & drld 4412-556'. Circ. POH. RIH & cut Core #2 in GGS B-5 interval 4556-86'. POH w/ core bbl. Fin POH w/ core bbl. LD Core #2 (B-5 sand). Rec 26.6', cut 30'. RIH w/ 12¼" bit & reamed core interval 4556 86'. Drld 4586-5070' Circ. POH. RIH w/ core bbl cut Core #3 (C-1 sandi 5070-100' POH & LD core. Cut 30' & rec 28.4'. MU & RIH w/ drig assy. Fin RIH w/ drlg assy. Reamed thru Core #3 5070-100'. Drld & surv 5100-678'. Circ & trip for Bit #15. RIH & drld 5678-888'. Circ & surv. POH for BHA chng to correct angle drop. Well History - Dolly Varden No. D-42 Page 8 07-17 6222'TD 07-18 6484'TD 07-19 6992'TD 07-20 7153'TD 07-21 7399'TD 07.,22 7768'TD 07-23 8040'TD 07-24 8066'TD 07-25 8110'TD 07-26 8226'TD 07-27 8384'TD 07-28 8689'TD 07-29 8937'TD 07-30 9284'TD 07-31 9490'TD 08-01 9687'TD 08-02 9776'TD Fin POH. Chngd BHA & RIH. Drld 5888-6214'. Circ & surv. POH. MU & RIH w/ core bbl. Cored 6214-222'. Core #4, D-2 sand. Cont cutting Core #4 6222-42' (GGS D-2 interval). POH w/ core bbl. Rec 23' (Cut 27'). Test BOP. RIH w/ Bit #16. Reamed thru cored interval 6214-41'. Drld 6241-484'. Drld 6484-859' w/ surv @ 6490' & 6804'. POH. Chngd out btm stabilizer & .RIH. Drld 6859-992'. Drld 6992-7153'. Circ &.surv @ 7098'. POH. MU DD #7~ & RIH. RIH w/ steering 'tool & oriented DD. DD would not operate. POH LD DD. PU DD #8 & RIH. Fin RIH w/ DD #8. RIH w/ steering tool & oriented DD. Drld 7153-7275'. POH w/ steering tool. POH LD DD. MU 19i,, , ~ bit & "locked' BHA. RIH to 7152'. Reamed DD #8 run 7152-275'. Drld 7275-399'. Circ. DP stuck while running surv on sand line. PU kelly & broke circ--DP came free. Circ & dropped surv. Fin POH. Chngd bits & RIH to 7360'. Washed & rotated to 2399'. Drld 7399-710'. DP stuck while drlg @ 7710' (high torque). Worked DP free w/ 390,000#. Drld to 7768'. Circ. Circ & surv: POH. RIH w/ Bit #21. Drld 7768-8040'. Drld 8040-45'. Circ. Cond trip to shoe--OK. Circ & surv. POH. RU WL & ran DIL/GR correlation log to tie in to GGS D-16 interval. RIH & drld 8045-66'. Circ & POH for core bbl. Fin POH. MU core bbl & RIH to 8066'. Cut Core #5 8066-75'. POH & LD core bbl--rec 4~' of core. Tstd BOPE.- RIH w/ Bit #21RR2. Reamed thru core interval. Drld 8075-110'. Drld 8110-96'. Circ & made cond trip. POH. RIH w/ core bbl & cut core #6 8196-226' in GGS D-17 interval. POH w/ core bbl. Fin POH w/~core bbl & LD Core #6 (D-17 sand). Rec 27.6' of 30' cut. RIH & reamed thru cored interval 8196-226'. Drld 8226-384' w/ trip for bit @ 8294'. Drlg 8384-689' w/ trip for Bit #23 @ 8527'. Drld 8689-8937~' w/ trip for Bit #24 @ 8761'. Drld 8937-9284' w/ trip for Bit #25 @ 9145'. Drld 9284-490' w/ trip for Bit #26 @ 9468'. Drld 9490-687'. Torque increased as penetrated F-1 sand. At 9687' broke rotary drive chain. Circ & surv. POH--several tight spots. Presently repairing rotary drix chain. Fin repairing rotary drive chain. RIH w/ Bit #27--hole OK. Drld 9687-776'. PU to make conn& kelly saver sub parted @ pin. WO OS. RIH w/ OS w/ 6¼" grapple & worked over TOF @ 57'. Circ. PU & fish free w/ 350,000#. POH LD 18 jts bent DP Hole tight btm 3200'. Test BOP. Chng BHA & RIH w/ Bit #28. Well History - Dolly Varden No. D-42 Page 9 08-03 9915'TD 08-04 10,128'TD 08-05 10,360'TD 08-06 10,485'TD 08-07 10,524'TD O8-08. 08-09 08-10 08-11 08-12 08-13 08-14 08-15 08-16 RIH w/ Bit #28. Reamed 40' to btm. Drld 9776-915'. Circ & surv. POH. Chngd BHA & RIH w/ Bit #29. Drld 9915-10,128'. Circ & surv. POH. Chngd BHA & RIH w/ Bit #27RR. Drld 10,128-360'. Fin cond trip (40 stds)--several tight spots. RIH. ~ Drld 10,360-468'. Made 40 std short trip--hole in better cond. RIH & drld 10,468-485'. Drld 10,485-524'. -Hole tight on conn. Circ. Made 45 std cond trip. Circ. Surv. POH--hole better. RU ~ WL & presently logging w/ CNL/FDC/DIFL/GR/Sonic/Caliper/S~ 10,524'TD. i :Cont Run #1 w/ CNL/FDC/DIFL/GR/Acoustic/Caliper/SP. Logged 10,490-3000'. Attempted to log w/ Spectralog, : but tool malfunctioned. BHA. RIH. Hole OK w/ 6' fill. Circ& cond for 9-5/8" csg. POI{. Hole OK. Chngd rams & pull wear bushing. Prep to run csg. 10,524'TD Fin running 9-5/8" csg to 10,510' (shoe) w/ stage clr @ 6984'. Circ. Cmtd 1st stage w/ 850 sx gel slurry followed w! 200 sx neat. Displ cmt. CIP @ 0700 hrs, 8-9-83. 10,524'TD Dropped bomb & opened stage clr @ 6984'. Circ & rec 90 bbl contaminated mud. Cmtd 2nd stage w/ 1050 sx gel slurry followed w/ 260 sx neat cmt. Dropped closing plug & displ cmt--unable to close stage clr. CIP @ 1300 hrs, 8-9-83. Held final displ press on csg 5½ hrs. Bled off press, PU BOP, & set slips. Cutoff csg. NU spool--tstd OK.. NU BOP. Presently tstg BOP. 10,527'TD MU BHA & RIH. Set wt on stage clr closing plug & press to 3000 psi--closed stage clr. Drld out stage clr & tstd to 3000 psi--OK. RIH & tagged cmt @ 10,416' (10' above float clr). Drld clr & tstd csg--OK. Drld cmt & shoe. Drld 3' formation to 10,527'. Tstd shoe to 11.9 ppg. EMW--OK. POH. Run gyro surv on 9-5/8" csg. 10,676 ' TD Fin running gyro surv on 9-5/8" csg. Gyro showed well to be +350' from single shot surf· Reran gyro. Second gyro showed well to be +150' from single shot surv. 8I~T MU = BHA & RIH w/ Bit #31. Drld 10,527-676'. 10,940'TD Drld 10,676-727'. Circ & dropped surv. Retr surv. POH. Chngd BHA & RIH. Drld 10,727-909'. Circ & dropped surv. Retr sgrv. Drld 10,090-940'. ll,064'TD Drld 10,940-11,064'. Circ & dropped surv. Retr surv & POH. Chngd BHA & RIH. Reamed 10,968-11,057'. Stuck pipe w! bit @ 11,057'. Worked stuck pipe, jars not working. RU & began FPI. ll,064'TD ll,064'TD Ran FPI. Free to btm of top steel DC. POH w/ ~VL. Circ & worked pipe while WO SFT. Mixed & spotted SFT pill. Soaked 5~ hrs, jarred 15 times Cont to soak 2 · · Jarred & worked stuck pipe to 470M. No movement. Ran FPI. Could not get any pull for reading below jars. Circ to move SFT. Jarred & worked pipe to 475M. Ran FPI. Three steel DCs free on top of monel stab @ 10,954'. Ran string shot & backed off @ 10,923'. Rec drill string to 10,923'. MU fishing tools & RIH. Well History - Dolly Varden No. D-42 Page 10 08-17 11,232'TD 08-18 11,232'TD 08-19 ll,413'TD 08-20 ll,706'TD 08-21 ll,912'TD 08-22 12,159'TD 08-23 12,396'TD 08-24 12,550'TD 08-25 12,830'TD 08-26 12,830'TD 08-27 12,830'TD 08-28 12,830'TD 08-29 12,830'TD 08-30 12,830'TD 08-31 12,830'TD 09-01 12,830'TD Fin RIH w/ fishing tools. Screwed into fish @ 10,923' & jarred fish free. POH. Rec entire BHA. MU BHA & RIH to 10,974'. Reamed 10,974-11,064'. Drld 11,064-11,232'. Circ. Short tripped to 9-5/8" csg shoe. Circ btms up. POH for logs. RU WL. Logged FDC/CNL/GR 10,500-3000'. Logged CBL/VDL/ GR/CCL 10,500-3000'. RD WL. Tstd BOPE. RIH w/ bit.~ RIH to 11,192'. Reamed 11,192-232'. Drld 11,232-413' · w/ 'surv @ 11,280'. Circ & dropped surv. POH. Chngd to locked BHA & ~RIH w/ Bit #33. Drld 11,413-706'. ~Circ & dropped surv. Trip to csg shoe to .retr surv. Hole OK. : Drld 11,706-91.2' w/ trip for Bit #34 @ 11,721'. Hole OK. Drld 11,912-12,007'. Short tripped to 9-5/8" csg shoe. Hole OK. Drld 12,007-159'. Circ & dropped surv. POH. PU Bit #35 & RIH. RIH to 11,099'. Reamed 11,099-12,159'. Drld 12,159- 356'. Circ & dropped surv. POH. PU Bit #36 & RIH to 12,296'. Reamed 12,296-356'. Drld 12,356-396'. Drld to 12,550'. Circ & dropped surv. POH. DP. Chngd out kelly & kelly bushing rollers. & RIH, PU S-135 DP. LD 87 its PU Bit #37 RIH to 12,470'. Reamed 12,470-550'. Drld 12,550-830'. Circ. Short tripped 10 stands. Circ for logs. Cond hole for logs. POH. CNL/SP/GR 12,828-10,508'. hole for lnr. RU ~. Ran DIFL/Sonic/FDC/ RD loggers. RIH to cond Fin RiH w/ 8½" bit. Circ & cond hole for 7" lnr. POH-- hole OK. RU & ran 68 jt$ 7" csg & lnr hgr. RIH on 5" DP to 12,828'. Circ lnr prior to cmtg. Cmtd lnr w/ 750 sx. CIP @ 0940 hrs, 8-27-83. Rel running tool f/ TOL @ 10,169'. POH w/ 8 stds. Circ out cmt contam mud. POH. Test BOP while WOC. MU BHA & RIH w/ 8½" bit. Circ @ 9746'. Tag T©C @ 9746'. Drld firm cmt 9746-9850' @ 0700 hrs. Drld cmt 9850'-TOL @ 10,169'. Circ hole clean. POH. PU 9-5/8" csg scrpr & RIH to TOL. Circ btms up. Press tstd 9-5/8" c~g & lnr lap to 2500 psi--OK. POH. RU Ran csg inspection log in 9-5/8" csg TOL-surf. RD WL. MU DST tools for dry test on lnr lap. _ RIHw/ DST tools w/ 4020' water cushion in DP. Set pkr & tstd 9-5/8" & 7" lnr lap (1 hr flow, 2 hr shut in). Unset pkr & POH w/ DST tools--press charts confirmed lnr lap tstd OK. PU 5-7/8" bit & RIH to TOL. Drld cmt 10,169-308'. RIH to 12,655'. Drld cmt 12,655-690'. Drld cmt 12,690'-fit clr @ 12,736'. Circ hole clean. POS RU WL. Ran GR/CBL/VDL & cmt evaluation tool 12,714- 10,163'WLM. Generally good to fair bond. RU & running inertial gyro. RD WL. RIH w/ bit & 7" csg scrpr to 12,728'. Displ well w/ FIW & spotted pill of 3% KC1 across Hemlock. Press tstd 9-5/8" csg & 7" lnr to 2500 psi--OK. POH w/ bit & scrpr. RU WL. Ran GR & JB to 12,500'WLM. POH w/ WL. Well History - Dolly Varden No. D-42 Page 11 09-02 12,830'TD 09-03 12,830'TD 09-04 12,830'TD 09-05 12,830'TD 09-06 12,830'TD 09-07 12,830'TD 09-08 12,830'TD 09-09 12,830'TD 09-10 '12,830 ' TD MU isolation pkr & RIH on WL. Set pkr @ 12,124'DIL. POH & RD WL. Dropped handle from 1" ball valve in hole while RD WL; MU short seal assy on DP & RIH to TOL. Stabbed seal assy into PBR. Tstd seal assy & PBR to 2500 psi--OK. RU WL. Ran a 2" broach thru isolation pkr @ 12,124'. RD WL. POH LD DP. RU & ran 306 jts 4½" prod tbg w/ pkr bore receptacle seal assy (20'), 8 GLMs, & TR BV. Tstd tbg to 4000 psi. Sting into PBR @ 10,184' & tstd seals to 2500 psi--OK. Space out & install tbg hgr. Landed tbg. RU ~VL & run 3-3/8" drift, thru tbg, PBR~ & isolation pkr @ 12,124'. Fin running 3-3/8" drift thru string ~ isol pkr @ 12,124'. POH RD WL. "ND BOP--NU & test tree. RU flow & GL lines. Attempted to open SSSV--control line would not hold press. ND tree--found hgr too low in tbg spool. PU tbg string & found support wedges in tbg spool damaged. Wait on spider & bowl, & new DCB spool & tbg hgr. PU tbg string. ND damaged tbg spool & PU. Set tbg in spider & bowl w/ 4½" slips on csg spool. Remove old tbg hgr & spool & replace. Strip new spool over tbg--PU string & remove spider. NU & tst new spool. Land tbg hgr in spool & tst ¼" control line. Tst PBR seals--OK. NU & tst tree. Open SSSV & begin unloading well for drawdown to perf Hemlock. 275 bbls. Unloaded. Compl unloading for 500 psi drawdown. RU WL & tst lub. RIH & perfd Hemlock Bench #1 w/ 8 HPF w/ 3-3/8" gun 12,002-022' DIL. Prod well to tst separator. Unloaded approx 43 bbl/hr & 10% oil cut. Still rec load water. Prod tstd Bench #1 conglomerate interval 12,002-022'DIL. Well unloaded & died. RU & pumped 45 bbl FIW dwn tbg for load water. RU & perf Bench #1 ll,984-12,002'DIL w/ 3-3/8" carrier guns, 90° phasing, 8 HPF. Flowed well to test separator. Cont tstg HB #1 perfs (ll,984-12,022'DIL). RU ~ & RIH w/ HP press gauge. Return well to prod to stab rate. Prod rate 636 B/D w/ 0% WC. SI well @ 2400 hrs, 9-7-83 . to begin press BU. Fin HB #1 ~ress BU. Returned well to prod & stabilized @ 1008 B/D w/ .1% WC. Made press/temp pass across HB #1 perfs. Majority of prod f/ perfs 12,004-022'DIL. SI well. POH w/ HP gauge. Chngd 7/32" to 3/8" WL--retest lub. RIH & perfd HB #2 12,055-080'DIL. Compl perfg H~mlock. Total perfd interval is Bench #1 ll,984-12,022'DIL & Bench #2 12,046-080'DIL. RD WL & returned well to test. Rate @ 0700 hrs = 3578 BFPD w~ .7% WC (3503 BOPD) w/ 207 GOR. Cont tstg well. FINAL REPORT. STATE OF ALASKA '-~' ALASKA ,.,iL AND GAS CONSERVATION CC,¢iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California * 83-53 3. Address 8. APl Number P.O. Box 6247 AnchOrage, Alaska 99502 50-733-20205-01 .4. Location of Well 749' FSL, 1135' FWL, Section 6, T8N, R13W, SM Leg A-2, Cond 7, Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) KB 106' MSL I 6 . Lease Designation and Serial No. ADL 18729 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-42 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ' [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on FOrm 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations. (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The interval of 3045'-3047' listed in the Drilling History of 7-11-83, on page 7 and on the Monthly Report of July,1983 was improperly described as being cored. This interval should be deleted. * Marathon Oil Company - Sub-operator MAR 0 1 1984 0[I & Gas Cons. C0mmissJ~ A.qch0r~go 14. I here~v ce'~tify tha~ ,l:h~ f~oin~ is true and correct to the best of my knowledge. S~g?ed;j~~c~al,.~e~~C~/l.[.~k.~-~.-y'f~t'l./~ T~t,eDistrict Drilling Superintenden~ate T~h~e,space below for Commission use 02/28/84 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate Union Oil and Gas /ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union DOCUMENT TRANSMITTAL February 15, 1984 HAND DELIVERED TO: William Van Alen FROM: LOCATION: 3001 Porcupine Drive LOCATION: Anchorage, Alaska 99504 ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: Reference: Trading Bay Unit - D-42 well One (1) set of core chips PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. DATED: D~TE Oct. 31, 1983 WELL NO., D- 42 STATE Alaska MEASUREMENTS TAKEN FROM MARATHON OI!.. COMPANY HISTORY OF OIL OR GAS WELL BLOCK LEASE Trading Bay Unit SEC. PARISH COUNTY Kenai PeninsUla Borough .106 ' ~'u~:v. KB FIELD "TOP OF OIL STRING. ELEV __ ,.TOP OF ROTARY TABLE ELEV.~ 6 TWP. 8N McArthu~~ River HISTORY PREPARED BY L. Y. Durham TITLE Secretary GMD. OR MAT_ ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1983 05-08 05-09 05-10 05-11 05-12 05-13 05-14 05-15 05-16 05-17 16,606'TD 16,606'TD 16,606 'TD 16,606 'TD 16,606 'TD 16,606'TD 16,606 'TD 16,606 'TD 16,606 'TD 1'6,606'TD TBU Well D-42 (Marathon AFE #4870) Moving equip & RU on Rig #77, Well D-23. Plan to plug & abandon Hemlock in D-23, cut & recover 9-5/8" & 13-3/8" csg to approx 600', & then drill new Hemlock producer D-42. Proposed TD of D-42 is 12,948'MD & 9984'TVD. Cont general RU of Rig #77 on TBU D-23. Cont RU of Rig #77 on D-23. RU WL. Pulled BV. RD WL. RU lines to tbg & displ tbg w/ 132 bbl FIW. RU WL. RIH w/ 2-1/8" perf gun & perfd tbg @ 15,304'. POH w/ & RD WL. Displ well w/ FIW. Began mixing mud to 9.5 ppg. Fin mixing mud to 9.6 ppg. Displ FIW w/ mud. Circ & cond mud for 1 full circ. SD & checked for flow--had small flow on tbg side. Resumed circ thru perfs in tbg @ 15,304' Circ & killed well. Set BPV. ND X-mas tree. NU & tstd BOPE--OK. MU landing j t in tbg hgr & attempted to pull hydraulic pkr @ 15,357'. Pkr would not pull free. RIH w/ free point & CCL on WL--could not get below 3661' WLM. POH. Circ & cond 9.0 ppg gas cut 'mud to 9.6 ppg. RIH w/ CCL & jet tbg ctr--had to pump dwn f/ 11,700- 15,229' WLM. Attempt to cut 3~" tbg @ 15,229' --did not come free. Stuck WL tools--worked free & POH. Ctr fired OK. RIH & worked free point'to ll,664'--tbg free here. Jet cut tbg @ ll,899'WLM. Tbg free. RD WL. LD tbg hgr & 2 j ts. Circ mud. Fin circ. POH & LD 363 jts 4~" tbg, 9 jts 3~"2 tbg, & GL equip. Chng to 5" rams in BOP & test. PU DP & RIH w/ OS. Fin RIH w/ overshot. Tagged top of tbg @ ll,919'DPM. PU kelly & worked over fish. Pulled tbg free w/ pull of 60,000# over string wt. POH & LD fishing tools, 106 jts 3~" tbg & GL equip. Left pkr assy, circ slv& 125' 3~" tbg in hole. PU 6" bit & scrpr. Cont RIH w/ 6" bit & scrpr. Set dwn @ 14,946' & could not wash deeper. Circ & cond mud. POH. PU 7" cmt rtnr. RIH & set rtnr @ 14,910'DPM. RU cmtrs. Attempted to pump intc Hemlock perfs--could not pump in w/ 4500 psi. Spotted 50 sx cmt on top of rtnr. Rev circ_nP ~.]ean. POH ,to 11,700'. Spotted 72 sx cmt 11,700~ pO~ to 11,239 . ' Well History - DollY Varden NO D-42 Page 2 05-18 16,606'TD -- _ . Fin rev circ. P0H & LD 3~" DP RIH w/ 8~" bit & scrpr to 1500' ~ ~ CBU. POH. -RIH w/ 9-5/8" cmt rtnr on DP. Set rtnr @. 1030' & dropped seal bar. POH & found seal bar stuck in setting tool. RIH 10 stds. C&C mud to 9.1 ppg. POH. RU WL. Ran gyro surv 600'-surf. Ran CCL 823'- surf. RD WL. 05 .... -16,606'.TD ....... Fin LD 5" DP. 05-20 16,606'TD 05-21 16,606'TD 05-22 16,606'TD 05-23 16,060'TD 05-24 16,606'TD Test BP @ 1030' & 9~5/8" csg to 1.000 psi as per AOGCC. RIH w/ 9-5/8" csg ctr & made initial cut @ ~08'. POH & redress ctr. Made second cut @ 49' RKB (5 under head). ND & PU BOP & tbg spool. Prep to pul~ 9-5/8" csg slips @ 0700 hrs. Welded 9-5/8" slips to csg. NU BOP. Engaged 9-5/8" w/ spear & pulled 6.39' free. PU BOP & recd slips. NU BOP. Made cut #4 in 9-5/8" @ 63'--could not pull w/ spear. "Made cut #5 @ 56'. Jarred free w/ spear--rec 7.03'. RIH w/ spear & jarred & POH w/ 6.09' csg. CO w/ 12¼" bit to 63' RKB. Made cut #6 @ 102' RKB--could not jar free. Made cut #7 @ 83' RKB. Presently jarring on 9-5/8" csg fish w/ top @ 63' RKB. Made cuts in 9-5/8" csg @ 76', 93', & 110' Rec 47.1' csg last 24 hrs. Made cuts @ 140' & 125' ~KB. Presently jarring on 9-5/8" csg fish w/ TOF @ 110' RKB. Made cuts in 9-5/8" csg @ 117', 150', 165', 178' & 216'. Rec 105.4' csg last 24 hrs. Presently top of 9-~/8" fish @ 216' RKB. Made cuts in 9-5/8" csg @ 235', 255', 296' ~ 316'. Made cu~@ 335'. TOF 316'. CO 9-5/8" stub w/ ~ bit. Made cuts in 9-5/8" csg @ 324', 329', 355', 375', 395'. T0F 375'. 05-25 16,606'TD 05-26 16,606'TD 05-27 16,606'TD 05-28 16,606'TD 05-29 16,606'TD Made cuts in 9-5/8" csg @ 414', 434', & 452'. Made cut @ 490'--could not pull fish. Made cut @ 471 '--could not pull fish. Chng out ctg tool w/ TOF @ 452'. RIH & made cut #36 @ 472' Made 2 attempts to jar csg fish free, but unscrewed ~ishing string on first try & parted bumper jars on second try. Fished & retrieved fishing tools. Made cut @ 462'. RIH w/ spear & rec 9.49' fish. CO trip w/ 12¼" bit to TOF @ 462'. RIH w/ spear--could not move fish. Made cut in 9-5/8" csg @ 467' Jarred w/ spear--could not move fish. Recut @ 46~~'. RIH w/ spear & jarred fish free. POH & rec 4.9' csg. CO to TOF @ 467' w/ 12¼" bit· RIH w/ spear & jarred on fish--could not move fish. Recut @ 472'. Jarred on fish--no move. Made cut @ 474' after removing knife stops. RIH w/ spear & jarred fish @ 467'. TOF 467', jarred w/ no movement. Rec spear & POH. Made csg cut @,477'. RIH w/ spear--jarred on fish--rec 6.6'. CO w/ 12¼' bit RIH w/ spear. POH & rec 2.3' csg. CO to TOF @ 477' w/ 12¼" bit. CO inside 9-5/8" csg to 505' (bridge). Made cut @ 491~'--could not jar free. Made cuts 484'~ (partial) & 485'(complete). RIh w/ spear w/ @ 477'. Jarred on 9-5/8" csg fish w/ top @ 477' Rec 7.3'. Made 3 additional cuts & rec 26.5'. Top of ~-5/8" fish 510'. CO inside fish. Well History - Dolly Varden No. D-42 Page 3 05-30 16,606'TD 05-31 16,606'TD 06-01~ 06-02 06-03 06-04 06-05 06-06 06-07 Fin CO-trip. r' Made 5 cuts. Pulled & rec 51.5' 9-5/8" csg. TOF 561'. CO trip w/ 12¼" bit & csg scrpr. Fin CO trip. Cond mud & reduce visc. POH LD 9-5/8" fishing tools. RU WL & ran 'Csg Clr Log on 13-3/8" csg to 561'. ND 13-3/8" BOP. NU 30" riser w/ flow nipple. RIH w/ ctr & cut 13-3/8" csg @ 55' RKB. RIH w/ spear. Pulled & rec 7.7'. RIH w/ ctr. 16,606'TD· -~ Cut 13~/8" csg @ 66'o ·Pulled & rec 11' c~g ?0 to TOF @ 66' 26"bit.--'CO inside 13-3j8" w/ 12¼ git Cut 13-3/8" csg @ 77'--rec 11.2' CO w/ 26" bit to TOF @ 77' & inside fish w/ 12¼" bit. ~ade cut @ 94', but could not pull. Made @ 85', but could not jar free (csg clr w/ centralizer @ 82'). RIH w/ 16" washpipe & WO fish 77-85'. Cmt very hard (made 8' in 24 hrs). RIH w/ spear. 16,606 'TD Engaged top of 13-3/8" fish @ 77'. Pulled & rec 7.7' csg. TOF @ 85'. CO inside 13-3/8" fish w/ 12¼" bit. POH & released Rig #77 from D-42 to Well D-1. Skid rig over D-1. RU WL. Pull malfunctioning BV. Run new valve & test-- OK. RD WL. Skid over D-42. Install 30" riser. RIH w/ spear--jarred & moved fish up hole 2'--could not pull. Released spear. RIH w/ 16" WP & WO fish 85-92'. 16,606'TD Rec. 9.6' csg. Made CO trips w/ 26" & 12k" bits. Cut 13-3/8" csg @ ll5'--could not jar free. WO 13-3/8" fish 95-117'. RIH w/ spear & rec 20' csg. CO w/ 26" & 12~" bits. Cut 13-3/8" csg @ 122' (clr & centralizer @ 119'). RIH w/ spear & rec 7.2' csg--did not rec centralizer. CO inside 13-3/8" csg to 179'--did not tag centralizer. Cut 13-3/8" csg @ 148'. RIH w/ 16" WP. 16,606 'TD Ream 114-120' & attemp to free 13-3/8" cent. POH w/ no rec. RIH w/ 17-3/4" FB mill--reamed 114-121'. Milled on junk 121-122'. POH. RIH w/ 16" WP & WO 13-3/8" csg 122-134'. RIH & cut 13-3/8" csg @ 139'. Made 3 trips w/ spear--engaged 13-3/8" fish, but spear would pull free w/o pulling fish. Wait on ext to get deeper into fish. TOF @ 122'. 16,606 'TD 16,606'TD RIH w/ 5' ext between grapple & stop ring of spear. Worked spear into fish to 127'(TOF 122')--spear pulled spear. Recut csg @ 139', made 26" & 12~" bit trips to clean hole while waiting on another ext. RIH w/ 13' ext--latch fish & POH. Rec 16.2' 13-3/8" csg. Fish was cut in half w/ WO string total of 12.8' Made CO trip w/ 26" bit. CO inside fish w/ 12k". Pulled 9.8' csg w/ spear--TOF @ 148'. Cut csg @ 153.5'. Pulled 5' csg w/ spear--TOF @ 153.5'. ~aking CO trip w/ 26" bit. CO trip w/ 12¼" bit. Cut 13-3/8" csg @ 192'. Jar on fish. Parted pin on 7-3/4" DC. Fished tool string. RIH w/ spear, but could not pull fish. RIH w/ ctr--had difficulty getting into TOF--dressed w/ 12¼" string mill. RIH w/ ctr & cut 13-3/8" csg @ 164'. RIH w/ spear & jarred fish free--rec 12 3'. CO w/ 26" bit. CO inside fish w/ 8~" junk mill & i2¼" string mill. RIH w/ spear & rec 26.2' csg. 16,606'TD CO .conductor w/ 26" bit. CO inside 13-3/8" fish w/ TOF @ 192'. Cut 13-3/8" csg @ 228, 200' Lost guide off ctr. Fished & rec guide. RIH w/ spear--cguld not jar fish free. POH & MU guide w/ bullnose, stringmill, & ext to find fish & guide WO shoe over fish. RIH & work into fish w/ guide & reamed dwn to TOF. POH to check connection. RIH & WO fish. Well History ~ Dolly Vardem No. D-42 Page 4 06-09 16',606'TD 06-10 16,606'TD 06-11 16,606'TD 06-12 16,606'TD 06-13 16,606'TD 06-14 16,606'TD RIll ~ ~p*~mr. ~.P~tied~:-&~ ~.~ec ~'~'.8 ~_,~::~sg. '?;c. RIH. ~'w~ 'W-M~/~0' c.~ ~. 13-3/8" fish 212-252' --torque increased. POH. RIH w/ spear. Pulled & rec 27.4' csg. MU CO string to dress TOF & CO inside. RIH w/ 12~" string mill. Dressed T0F @ 224' & CO 13-3/8" csg to 257'. POH. RIH w/12¼" bit & CO 13-3/8" csg to 355'. POH. RIH & cut 13-3/8" csg @ 248'. POH. RIH w/ spear. POH LD 23.4' csg. RIH & CO conductor to 240' w/ 26" bit.~POH. .RIH~& washed over~13-3/8" csg 252-257'. POH after torque increased. Marks on shoe indicated 13-3/8" csg is next to conductor wall. Chngd WO shoes. RIH & washed over 13-3/8" csg 257-262'. POH. RIH & cut 13-3/8"csg @ 260'. RIH w/ spear. Rec 12.3' csg. Marks indicated WO shoe has been shoving OD off 13-3/8" csg--max metal loss = ¼". Cut 13-3/8" csg @ 265' Could not jar 5' fish free. RIH & recut 13-3/8" csg ~ 265'. POH. RIH w/ spear & rec 5.1' csg--TOF @~- 265'. CO cond to 264' w/ 26" bit. CO 13-3/8" stub to 561' w/ 12~" bit. Cut 13-3/8" csg @ 400'. RIH w/spear & J-safety jt. Set spear in 13-3/8" stub. Unlatched J-jt (left spear in stub @ 13-3/8" csg). POH. RIH w/ 8~" bit to drill along the outside of 13-3/8" csg--could not get 3~" hole started. RIH w/ OS w/ 11-3/4" bowl--could not catch spear. RIH w/ J-retrieving tool--could not catch spear. RIH w/ OS w/ 8-1/8" bowl. Caught & released spear. CO cond to 265' w/ 26" bit. RIH w/ spear & J- safety jt--could not work into 13-3/8" stub. RU spear w/ ~" jet inside of bullnose. RIH w/ spear & jetted into fish--OK. Rec safety jt leaving spear & lower half safety jt in TOF @ 265' RIH w/ 8~" bit & drld cmt along side_13-3/8" fish 295-384' Circ hole clean. POH. RIH w/ OS & rec spear & safgty jt. RIH w/ ctr & cut 13-3/8" csg @ 285' RIH w/ spear--jetted into TOF @ 265'. Jarred on fis~. Parted oil jars. POH. RIH w/ OS & fished OJ & spear. POH. RIH w/ ctr & cut 13-3/8" csg @ 275'. RIH w/ spear. Fin RIH w/ spear & engage TOF @ 265'. Jarred. POH w/ 10.4' csg. RIH w/ 26" bit & CO to TOF. RIH w/ spear & jarred on 10' fish--no movement. Rec spear & POH. RIH & cut 13-3/8" csg @ 290'. RIH w/ spear. Jarred. POH w/ 15' csg--partial cut @ 285' CO to TOF @ 290' w/ 26" bit. Cut 13-3/8" csg @ 30g'. RIH w/ spear. Jarred. Jars failed. POH & chng OJ. RIH w/ spear--jarred & POH w/ 15~' csg. CO to TOF w/ 26" bit. RIH w/ ctr-- could not get below 316'. POH. RIH & CO fish w/ 12¼" bit to 561'~ Cond mud @ 561'. POH. Cut 13-3/8" csg @ 343'. RIH w/ spear. Could not jar 37' fish free. POH. Cut 13-3/8" csg @ 320' RIH w/ spear & jarred fish free. P0H & LD 13.9' 13-3~8" csg. TOF @ 320' CO cond to 320' w/ 26" bit. RIH w/ spear & jarre~ fish free. POH & LD 23.9' 13-3/8" csg. CO cond to 344' w/ 26" bit. Cut 13-3/8" csg @ 357'. RIH w/ spear & jarred fish free. POH LD 13.2' 13-3/8" csg--TOF @ 357'. CO cond to 357' w/ 26" bit. RIH w/ ctr. Hit bridge in 13-3/8" csg @ 382'. POH. RIH w/ 12~" bit.& CO inside 13-3/8" fish. Hit bridge @ 382'. CO to 414'. Cut 13-3/8" csg @ 383'. RIH w/ spear, POH & rec 26.1' csg. CO w/ 26" bit to TOF. RIH w/ spear, POH & rec 16.9' csg. CO w/ 26" bit to TOF @ 400'. RIH w/ 16" WO shoe w/ 12' guide stinger. WO 13-3/8" csg 400-2'. PU off fish--unable to get back over fish. Circ & increased visc to 150. Circ out lots of cmt & metal. RIH w/ 8~" junk mill & 12~" string mill to 561'. RIH w/ 16" WO shoe--WO fish. WO 402-4'. PU above 13-3/8" fish. Could not work back over fish. Well History - Dolly Varden No. D-42 Page 5 06-16 16,606'TD 06-17 16,606'TD 06-18 16,606'TD 06-19 16,606'TD 06-20 16,606'TD 06-21 16,606'TD 06- 22 16,606'TD 06-23 16,606'TD 06-24 16,606'TD .~OH w/ WO~_~.shoe Rz:Bki~g~r~.~.:ecChngd WO,_: sho~T'R-,RtH~.~cou'"l,~ not work shoe over 13-3/8" csg stub. POH. RIH & cut 13-3/8" csg @ 404'. RIH w/ spear--could not engage fish. MU 5' ext on spear & RIH--could not engage fish. MU kick sub on spear & RIH--could not engage fish. MU DP stinger beneath spear & RIH. POH LD 4.1' 13-3/8" csg. TOF was split by WO shoe. Co cond to 404' w/ 26" bit. RIH w/ 17-1/8" WO shoe & guide assy. WO 13-3/8" csg 404-6'· POH. RIH w/ 8~" junk mill to 561'. Cond mud while building s-tabliizer 'for- !,70 assy. Fin building stabilizer for WO guide assy. MU guide assy, 5' WP & WO shoe. RIH & WO 13-3/8" csg 404-9' POH MU new guide assy, 1 jt WP & WO shoe RIH & WO i3 3/8;' · - csg 409-26' (btm conductor @ 408'). WO 13-3/8" csg 426-39'. POH. MU WO shoe on 2 jts WP & RIH. WO 13-3/8" csg 439-47'. POH. Left WO shoe & 1 ,it WP in hole. Top of 16" WP fish @ 406'. Top of 13-3/8' csg stub @ 404' RIH & cut 13-3/8" csg @ 449'. R,I,H w/ spear. POH LD ~5.6' 13-3/8" csg. MU spear for 16' WP &' RIH. Rec 45.6' 13-3/8" csg last 24 hrs. Total rec to dat 401.5'. Rec 16" WP fish on 2nd attempt--had to modify spear nose & stop ring. RIH w/ WP & guide stinger to 13-3/8" stub @ 449'. WO 449-83'. Ran spear & rec 27.2' csg to 477'-- -ulti-string cut made during 9-5/8" csg rec. Built-up stab blades on WP stinger & check all conn. RIH w/ 16" WP & WO 13-3/8" csg 483-512'. Circ hole clean. POH. Cut 13-3/8" csg @ 508'. RIH w/ spear & rec 31.2' csg. Made CO trip inside fish. RIH w/ WP & WO 512-34'. TOF 13-3/8" csg @ 508'. Top of 9-5/8" csg fish 561'. WO 13-3/8" csg 534-41'. Circ hole clean & POH. Cut 13-3/8" csg @ 535'. RIH w/ spear. P0H LD 26.7' 13-3/8" csg. RIH w/ WO assy & washed to 541' WO 13-3/8" csg 541-69' Circ hole clean & POH. PU ~ulti-string csg ctr. Top of {3-3/8" stub 535'. Top of 9-5/8" stub 561'. RIH & cut 9-5/8" & 13-3/8" csg @ 567' RIH w/ spear. P0H LD 4.4' 9-5/8" csg cmtd inside 32.8' i3-3/8" csg. RIH w/ new WO shoe & WO 13-3/8" csg 569-601'. POH. RIH w/ 8~" bit to 607'. Circ hole clean & POH. RIH w/ spear. POH LD 36~' 9-5/8" csg cmtd inside 36~' 13-3/8" csg 9-5/8" csg against wall of 13-3/8" csg. LD all fishing tools. .RIH w/ 8~" bit to 710'. Top of 13-3/8" & 9-5/8" stubs are 603'. POH w/ 8~" 5it. RIH to 650' w/ OEDP. kick off plug 650-480'. POH. LD DP. 20" diverter. Spotted 202 sx ND 30" riser. NU Function tstd 20" diverter. RIH w/ 12¼" bit & tagged soft cmt @ 500'. Cmt had been in place 24+ hrs. Washed & rotated thru very soft cmt to 601'--hit hard cmt @ 601'. Circ hole clean & POH. RIH w/ OEDP to 601' Spotted 225 sx cmt plug 601-450'. CIP 2145 hrs, 6-~2-83. POH to 415' & circ hole clean. POH. WOC. WOC until 1600 hfs, 6-23-83. RIH w/ 12¼" bit. Hit cmt stringer_@ 520' & hard cmt @ 524'. Drld hard cmt to 526'. POH. RIH w/ 12-~" bit, bent sub, & Dyna-Drill. Drld & surv 12-~" hole 526-839'. Well. History - Dolly Varden No. D-42 Page 6 06-26 06-27 06-28 06-29 06-30 07-01 07-02 07-03 07-04 07-05 D~ld.*~& !§h~R~7-~!l..'~°~8,39-}il'06:,,~.i ~'q(POH~f ~yhva~--Di<i:lLll-;~- not R.IH w/ 12~" bit on an angle building BHA. Drld & surv 12~"'hole 1106-1706'. 1930'TD Drld & surv 1706-1853'. POH. RIH w/ 12~" bit'on Dyna- Drill #2. RIH w/ steering tool & oriented DD. Drld 1853-1920'--steering tool malfunctioned. POH w/ steering tool--steering tool OK. POH w/ DD--orientation equip OK. RIH w/ 12~" bit on DD #3. RIH w/ steering tool & oriented ~ .~". ~ ~. DD~ ~Drld-1920-30'~steering tool malfuncticn~d. POH w/ steering tool--steering tool OK. Attempted to check DD orientation w/ single shot gyro--gyro failed. POH w/ DD. Serv rig. RIH w/ DD #4. Checked tool face orienta- tion w/ single shot gyro. RIH w/ steering tool & oriented DD. 2332 'TD Drld 12¼" hole 1930-2332' w/ surv @ 2002' & 2190'. POH w/ DD. RIH w/ locked BHA--could not work BHA past 1883'. POH. RIH w/limber BHA. Reamed DD #4 run 1883-2266' .-- Surv taken shile reaming indicate hole may have been sidetracked. 2359'TD Fin surv @ 2206' (surv depth reported 6-27 was in error). Surv confirmed hole had been sidetracked @ +1850'. Drld 2266-359'--Hole #2. Circ & surv @ 2299' P--OH. RIH w/ 12~" bit on locked-up BHA to 2359'--Hole ~2. RIH w/ 12¼" bit on DD #5 to 2332'. Reamed to 2341'. Surv confirmed DD was in Hole #1. Attempted 3 additional times to re-enter Hole #2 by orienting DD while RIH-- DD went into Hole #1 every time. POH w/ DD.-.RIH w/ 12~" bit on locked up BHA. 2400'TD Fin RIH to 2359' w/ 12¼" bit on stiff BHA. Circ & surv-- surv confirmed bit was in Hole #2. Drld 2359-400'. Surv @ 2400' POH. PU 17~" hole opener & RIH to 526'. Opened ~2¼" hole to 1~" 526-1730' ~ · 2600'TD Opened 12¼" hole to 17~" 1730-2380' CBU. POH LD hole opener. RIH w/.12¼" bit on stiff B~A to 2400'--surv confirmed bit in Hole #2. POH. RIH w/ 12~" bit on DD #6 to 2400'--surv confirmed DD in Hole #2. Drld & surv 12¼" hole 2400-600'. 3005'TD DD 2600-772'. POH w/ steering tool. SS surv @ 2723'. POH w/ DD. RIH w/ locked 12¼" assy to 2400'. Reamed DD run 2400-772'. Drld to 3005'. Circ & surv. POH. RIH w/ 17~" HO to 2380' & opened to 2570'. 3005'TD Opened hole to 17~" 257.0-3003' 2 · & stab. RIH.. & C&C for csg. POH. 68# csg. C&C. POH & cleaned HO RIH w/ 13-3/8" K-55 3005'TD Fin running 13-3/8" K-55 68# butt csg w/ float shoe @ 3000', float clr @ 2920' C&C. RU & tstd cmt lines. Pumped 50 bbl fresh wtr ~head of 1200 sx C1 G blend cmt. Bulk cmt line plugged. Switched to neat C1 G tail slurry & pumped 100 sx. Press up & could not pump w/ 3000 psi. Checked surf lines--OK. CIP @ 1710 hrs. RD cmt lines. Hung off 20" stack. 3005 'TD Fin bracing 13-3/8" csg to 33" cond. Cut off & belled 13-3/8" csg @ 41'. NU 20" stack/diverter. Drld cmt 42-1876' w/ FIW. 3005 'TD Drld cmt out of 13-3/8" csg 1876-2917' Circ & POH. RIH w/ 13-3/8" csg scrpr. Circ clean. Di~pl FIW w/ mud. C&C. POH. Well History - Dolly Varden No. D-42 Page 7 07-07 3010'TD , 07-08 3010'TD 07-09 3010'TD 07-10 3045'TD 07-11 3710'TD 07-12 3957'TD 07-13 4166'TD 07-14 4586'TD 07-15 5100'TD 07-16 5888'TD ROH ~-%~/'- l<3-~378'.'--:>~§gc:~-¢:rpr:."--:~Di':&: :PU :2'0" .s'tack.. ~'Rlti .WL :&~'ran thru spear--RIH w/ spear & latched 13-3/8" csg--PU csg. Ran free point. Csg free @ 512', but no movement @ 550' Reweld brakes to center 13-3/8" csg in 33" cond. Relegse spear, POH, & RD WL-. NU 20" stack. RIH w/ 12¼" bit. Drld cmt 2917-21'. Drld fit clr 2921-23', & drld firm cmt 2923-73'. Fin drlg firm cmt out of shoe j t & drld float shoe. POH ...... w/ t2~" bit~- RIH & set 13-3/8" cmt~-rtnr @ 2757' DPM. Tstd 13-3/8" csg shoe to 13.4 ppg EMW w/o leakoff. POH w/ stinger. RIH & perfd 13-3/8" csg @ 2480-81' w/ 4 SPF. RD WL. RIH & set 13-3/8" cmt rtnr @ 2341'DPM. Pump dwn DP & thru perfs @ 2480' & circ back to surf. C&C mud prior to cmtg 13-3/8" csg. Circ prior to cmtg. Mixed & pumped 1000 sx C1 G w/ 6% gel followed w/ 296 sx C1 G neat. Cmtd thru rtnr @ 2341' & csg perfs @ 2480-81'. Good cmt returns to surf. -. CIP @ 1700 hrs, 7-7-83 Pulled out of rtnr w/ stinger & circ out. POH. ND 20" BOP, riser, & diverter lines. Cutoff 13-3/8" csg & weld on starting head. Begin tstg head @ 0700 hrs. Fin tstg wellhead. NU BOP. RIH w/ 12¼" bit & suck BHA. 2341'). Drld cmt to 2317'. Tstd BOP--witnessed by AOGCC. Tag TOC @ 2302' (rtnr @ Fin drlg cmt 2317-41' (top of rtnr). Tstd csg to 1400 psi--OK. Drld rtnr @ 2341' Drld hard cmt below circ perfs @ 2480-81' & CO to 2n~ rtnr @ 2757'. Tstd csg to 700 psi--OK. Drld rtnr @ 2757'--pushed to btm & drld formation 3010-15'. CBU. POH. RIH w/ packed BHA. Drlg 3015-45'. ROP slow w/ lots of torque. Circ to clean hole. Circ. POH--BHA~ globe ~asket~. Cored 3045-47'. POH.~_No j~n-k--ln -~as~etq~KTH--~~" bit-- dripped 3 stabs.----D~-~d 30~7~i0~; to bury BHA--no excessive drag or torque.. Circ & surv. POH. MU packed BRA & RIH. Drld & surv 3107-710'. Drld & circ up samples 3710-803'. (Costs related to coring Grayling Gas Sands charged to AFE #4734.) Circ & surv. POH. RU WL & RIH w/ DIL/SP/GR--could not get below 3106' Chngd logging tool configuration--RIH--could not get bglow 3160'. Logged from 3160-2000' & made tie-in w/ Well D-7. RIH & drld 3803-957' & circ up samples. POHo RIH w/ core barrel. Plugged barrel. POH & unplug barrel. Unplugged core bbl. RIH w/ 12¼" bit--tagged bridge @ 3890'. CO ~o 3947'. C&C mud. POH. RIH w/ core bbl. Cut Core #1 3957-77' (20'). Attempting core of Grayling Gas Sands A-6 interval. POH. Rec 14' MU BHA. RIH & reamed 3957- 77'. Drld & surv 3977-416g'. Drld 4166-412'. Circ & surv. POH. RU WL. Ran DIL/GR/ SP 4114-3000' @ csg shoe (could not work deeper). Correlated to Well D-7. RD WL. RIH & drld 4412-556'. Circ. POH. RIH & cut Core #2 in GGS B-5 interval 4556-86'. POH w/ core bbl. Fin PoH'W/ core bbl. LD Core #2 (B-5 sand). Rec 26.6', cut 30'. RIH w/ 12¼" bit & reamed core interval 4556- 86'. Drld 4586-5070' Circ. POH. RIH w/ core bbl & cut Core #3 (C-1 sandi 5070-100' POH & LD core. Cut 30' & rec 28.4'. MU & RIH w/ drig assy. Fin RIH w/ drlg assy. Reamed thru Core #3 5070-100'. Drld & sur.v 5100-678'. Circ & trip for Bit #15. RIH & drld 5678-888'. Circ & surv. P0H for BHA chng to correct angle drOp. Well History - Dolly Varden No. D-42 Page 8 07-18 6484'TD 07-19 6992'TD 07-20 7153'TD 07-21 7399'TD 07-22 7768'TD 07-23 8040'TD 07-24 8066'TD 07-25 8110'TD 07-26 8226'TD 07-27 8384'TD 07-28 8689'TD 07-29 8937'TD 07-30 9284'TD 07-31 9490'TD 08-01 9687'TD 08-02 9776'TD POH. MU & RIH w/ core bbl. Cored 6214-222'. Core #4, D- 2 sand. Cont cutting Core #4 6222-42' (GGS D-2 interval). POH w/ core bbl. Rec 23' (Cut 27'). Test BOP. RIH w/ Bit #16. Reamed thru cored interval 6214-41'. Drld 6241-484'. Drld 6484~859· w/ surv @-.6490' & 6804'. POH. Chngd out btm stabilizer & RIH. Drld 6859-992'. Drld 6992-7153'. Circ & surv @ 7098'. POH. MU DD #7 & RIH. RIH w/ steering tool & oriented DD. DD would not operate. POH LD DD. PU DD #8 & RIH. Fin RIH w/ DD #8. RIH w/ steering tool & oriented DD. Drld 7153-7275'. POH w/ steering tool. POH LD DD. MU 12k" bit & "locked" BHA. RIH to 7152'. Reamed DD #8 run 7152-275'. Drld 7275-399'. Circ. DP stuck while running surv on sand line. PU kelly & broke circ--DP came free. Circ & dropped surv. Fin POH. Chngd bits & RIH to 7360'. Washed & rotated to 2399'. Drld 7399-710'. DP stuck while drlg @ 7710' (high torque). Worked DP free w/ 390,000#. Drld to 7768' . Circ. Circ & surv. POH. RIH w/ Bit #21. Drld 7768-8040'. Drld 8040-45'. Circ. Cond trip to shoe--OK. Circ & surv. POH. RU WL & ran DIL/GR correlation log to tie in to. GGS D-16 interval. RIH & drld 8045-66'. Circ & POH for core bbl. Fin POH. MU core bbl & RIH to 8066'. Cut Core #5 8066-75' POH & LD core bbl--rec 4~' of core Tstd BOPE. RIH w/ Bit #21RR2. Reamed thru core interval. Drld 8075-110'. Drld 8110-96'. Circ & made cond trip. POH. RIH w/ core bbl & cut core #6 8196-226' in GGS D-17 interval. POH w/ core bbl. Fin POH w/ core bbl & LD Core #6 (D-17 sand). Rec 27.6' of 30' cut. RIH & reamed thru cored interval 8196-226'. Drld 8226-384' w/ trip for bit @ 8294'. Drlg 8384-689' w/ trip for Bit #23 @ 8527'. Drld 8689-8~37' w/ trip for Bit #24 @ 8761'. Drld 8937-9284' w/ trip for Bit #25 @ 9145'. Drld 9284-490' w/ trip for Bit #26 @ 9468'. Drld 9490-687'. Torque increased as penetrated F-1 sand. At 9687' broke rotary drive chain. Circ & surv. POH--several tight spots. Presently repairing rotary driw chain. Fin repairing rotary drive chain. RIH w/ Bit #27--hole OK. Drld 9687-776'. PU to make conn& kelly saver sub parted @ pin. WO OS. RIH w/ OS w/ 6k" grapple & worked over TOF @ 57' Circ. PU & fish free w/ 350,000#. POH LD 18 jts gent DP. Hole tight btm 3200'. Test BOP. Chng BHA & RIH w/ Bit #28. Well History - Dolly Varden No. D-42 Page 9 08-04 10,128'TD 08-05 t0,360'TD 08-06 10,485'TD 08-07 10,524'TD 08-08 10,524'TD 08-09 10,524'TD 08-10 10,524'TD 08-11 10,527'TD 08-12 10,676 ' TD 08-13 10,940'TD 08-14 ll,064'TD 08-15 ll,064'TD 08-16 ll,064'TD RIH W~BitC~.~8~-~Reamed?.4.0' t.-o btmg?~qDrld~9776~9~'.~':..~ Circ & surv. POH. Chngd BHA & RIH w/ Bit #29. Drld 9915-10,128'. Circ & surv. POH. Chngd BHA & RIH w/ Bit #27RR. Drld 10,128-360'. Fin cond trip (40 stds)--several tight spots. RIH. Drld 10,3~0-.468'~. .Made 40 std short trip-,hol.~ in better cond. RIH & drld 10,468-485'. Drld 10,485-524'. Hole tight on conn. Circ. Made 45 std cond trip. Circ. Surv. POH--hole better. RU WL & presently logging w/ CNL/FDC/DIFL/GR/Sonic/Caliper/SP. Cont Run #1 w/ CNL/FDC/DIFL/GR/Acoustic/Caliper/SP. Logged 10,490-3000'. Attempted to log w/ Spectralog, but tool malfunctioned. BHA. RIH. Hole OK w/ 6' fill. Circ & cond for 9-5/8" csg. POH. Hole OK. Chngd rams & pull wear bushing. Prep to run csg. Fin running 9-5/8" csg to 10,510' (shoe) w/ stage clr @ 6984'. Circ. Cmtd 1st stage w/ 850 sx gel slurry followed w/ 200 sx neat. Displ cmt. CIP @ 0700 hrs, 8-9-83. Dropped bomb & opened stage clr @ 6984'. Circ & rec 90 bbl contaminated mud. Cmtd 2nd stage w/ 1050 sx gel slurry followed w/ 260 sx neat cmt. Dropped closing plug & displ cmt--unable to close stage clr. CIP @ 1300 hrs, 8-9-83. Held final displ press on csg 5½ hrs. Bled off press, PU BOP, & set slips. Cutoff csg. NU spool--tstd OK. NU BOP. Presently tstg BOP. MU BHA & RIH. Set wt on stage clr closing plug & press to 3000 psi--closed stage clr. Drld out stage clr& tstd to 3000 psi--OK. RIH & tagged cmt @ 10,416' (10' above float clr). Drld clr & tstd csg--OK. Drld cmt & shoe. Drld 3' formation to 10,527'. .Tstd shoe to 11.9 ppg. EMW--OK. POH. Run gyro surv on 9-5/8" csg. Fin running gyro surv on 9-5/8" csg. Gyro showed well to be +350' from single shot surf. Reran gyro. Second gYro showed well to be +150' from single shot surv. MU 8½" BHA & RIH w/ Bit--#31. Drld 10,527-676'. Drld 10,676-727'. Circ & dropped surv. Retr surv. Chngd BHA & RIH. Drld 10,727-909'. Circ & dropped surv. Retr surv. Drld 10,090-940'. POH. Drld 10,940-11,064'. Circ & dropped surv. Retr surv & POH. Chngd BHA & RIH. Reamed 10,968-11,057'. Stuck pipe w! bit @ 11,057'. Worked stuck pipe, jars not working. RU & began FPI. Ran FPI. Free to btm of top steel DC. POH w/ WL. Circ & worked pipe while WO SFT. Mixed'& spotted SFT pill. Soaked 5½ hrs, jarred 15 times. Cont to soak. Jarred & worked stuck pipe to 470M. No movement. Ran FPI. Could not get any pull fOr reading below jars. Circ to move SFT. Jarred & worked pipe to 475M. Ran FPI. Three steel DCs free on top of monel stab @ 10,954'. Ran string shot & backed off @ 10,923'. Rec drill string to 10,923'. MU fishing tools & RIH. Wel~l History - Dolly Varden No. D-42 Page 10 11; 232¥TD 08-18 11,232'TD 08-19 11,413' TD 08-20 11,706 ' TD 08-21 ll,912'TD 08-22 12,159'TD 08-23 12,396'TD 08-24 12,550'TD 08-25 12,830'TD 08-26 12,830'TD 08-27 12,830'TD 08-28 12,830'TD 08-29 12,830'TD 08-30 12,830'TD 08-31 12,830'TD 09-01 12,830'TD & jarred fish free. POH. Bec entire BHA. MU BHA & RIH to 10,974'. Reamed 10,974-11,064'. Drld 11,064-11,232'. Circ. Short tripped to 9-5/8" csg shoe. Circ btms up. POH for logs. RU WL. Logged FDC/CNL/GR 10,500-3000'. Logged CBL/VDL/ GR/CCL 10,500-3000'. RD WL. Tstd BOPE. RIH w/ bit. RiH to 11,192'. Reamed 11,i92-23'2'. Drld 11,232-413' w/ surv @ 11,280'. Circ & dropped surv. POH. Chngd to locked BHA & RIH w/ Bit #33. Drld 11,413-706'. Circ & dropped surv. Trip to csg shoe to retr surv. Hole OK. Drld 11,706-912' w/ trip for Bit #34 @ 11,721'. Hole OK. Drld 11,912-12,007'. Short tripped to 9-5/8" csg shoe. Hole OK. Drld 12,007-159'. Circ & dropped surv. POH. PU Bit #35 & RIH. RIH to 11,099'. Reamed 11,099-12,159'. Drld 12,159- 356'. Circ & dropped surv. POH. PU Bit #36 & RIH to 12,296'. Reamed 12,296-356'. Drld 12,356-396'. Drld to 12,550'. Circ & dropped surv. POH. LD 87 jts DP. Chngd out kelly & kelly bushing rollers. PU Bit #37 & RIH, PU S-135 DP. RIH to 12,470'. Reamed 12,470-550'. Drld 12,550-830'. Circ. Short tripped 10 stands. Circ for logs. Cond hole for logs. POH. CNL/SP/GR 12,828-10,508'. hole for lnr. RU WL. Ran DIFL/Sonic/FDC/ RD loggers. RIH to cond Fin RIH w/ 8½" bit. Circ & cond hole for 7" lnr. POH-- hole OK. RU & ran 68 jts 7" csg & lnr hgr. RIH on 5" DP to 12,828'. Circ lnr prior to cmtg. Cmtd lnr w/ 750 sx. CIP @ 0940 hrs, 8-27-83. Rel running tool f/ TOL @ 10,169'. POH w/ 8 stds. Circ out cmt contam mud. POH. Test BOP while WOC. MU BHA & RIH w/ 8½" bit. Circ @ 9746'. Tag TOC @ 9746'. Drld firm cmt 9746-9850' @ 0700 hrs. Drld cmt 9850'-TOL @ 10,169'. Circ hole clean. POH. PU 9-5/8" csg scrpr & RIH to TOL. Circ btms up. Press tstd 9-5/8"---csg & lnr lap to 2500 psi--OK. POH. RU WL. Ran csg inspection log in 9-5/8" csg TOL-surf. RD WL. MU DST tools for dry test on lnr lap. RIHw/ DST tools w/ 4020' water cushion in DP. Set pkr & tstd 9-5/8" & 7" lnr lap (1 hr flow, 2 hr shut in). Unset pkr & POH w/ DST tools--press charts confirmed lnr lap tstd OK. PU 5-7/8" bit & RIH to TOL. Drld cmt 10,169-308'. RIH to 12,655'. Drld cmt 12,655-690'. Drld cmt 12,690'-fit clr@ 12,736'. Circ hole clean. POH~ RU WL. Ran GR/CBL/VDL & cmt evaluation tool 12,714- 10,163'WLM. Generally good to fair bond. RU & running inertial gyro~ RD WL. RIH w/ bit & 7" csg scrpr to 12,728'. Displ well W/ FIW & spotted pill of 3~ KC1 across Hemlock. Press tstd 9-5/8" csg & 7" lnr to 2500 psi--OK. POH w/ bit & scrpr. RU WL. Ran GR & JB to 12,500'WLM. POH w/ WL. Well History - Dolly. Varden No. D-42 Page 11 .09-02 '12,830 ' TD 09-03 12'830'TD 09-04 12,830'TD 09-05 12,830'TD 09-06 12,830'TD 09-07 12,830'TD 09-08 12,830'TD 09-09 12,830'TD 09-10 12,830'TD MU~isolation. pkr-& RIH on WL. Set pkr @_12,124',DIL~.~. POH & RD WL. Dropped handle from 1" ball valve in hole while RD WL. MU short seal assy on DP & RIH to TOL. Stabbed seal assy into PBR. Tstd seal assy & PBR to 2500 psi--OK. RU WL. Ran a 2" broach thru isolation pkr @ 12,124'. RD WL. POH LD DP. RU & ran 306 jts 4½" prod. tbg w/ pkr bore receptacle seal assy (20'), 8 GLMs, & TR BV. Tstd tbg to 4000 psi. Sting into PBR.@ 10,184! & t~td seals to 2500~psi--OK. Space out & install tbg hgr. Landed tbg. 'RU WL & run 3-3/8" drift thru tbg, PBR, & isolation pkr @ 12,124'. Fin running 3-3/8" drift thru string & isol pkr @ 12,124'. POH RD ~YL. ND BOP--NU & test tree. RU flow & GL lines. Attempted to open SSSV--control line would not hold press. ND tree--found hgr too low in tbg spool. PU tbg string & found support wedges in tbg spool damaged. Wait on spider & bowl, & new DCB spool & tbg hgr. PU tbg string. ND damaged tbg spool & PU. Set tbg in spider & bowl w/ 4½" slips on csg spool. Remove old tbg hgr & spool & replace. Strip new spool over tbg--PU string & remove spider. NU & tst new spool. Land tbg hgr in spool & tst ¼" control line. Tst PBR seals--OK. NU & tst tree. Open SSSV & begin unloading well for drawdown to perf Hemlock. 275 bbls. Unloaded. Compl unloading for 500 psi drawdown. RU WL & tst lub. RIH & perfd Hemlock Bench #1 w/ 8 HPF w/ 3-3/8" gun 12,002-022' DIL. .Prod well to tst separator. Unloaded approx 4.3 bbl/hr & 10% oil cut. Still rec load water. Prod tstd Bench #1 conglomerate interval 12,002-022'DIL. Well unloaded & died. RU & pumped 45 bbl FIW dwn tbg for load water. RU & perf Bench #1 ll,984-12,002'DIL w/ 3-3/8" carrier guns, 90° phasing, 8 HPF. Flowed well to test separator. Cont tstg HB #1 perfs (ll,984-12,022'DIL). RU WL & RIH w/ HP press gauge. Return well to prod to stab rate. Prod rate 636 B/D w! 0% WC. SI well @ 2400 hrs, 9-7-83 to begin press BU. Fin HB #1.press BU. Returned well to prod & stabilized @ 1008 B/D w/ .1% WC. Made press/temp pass across HB #1 perfs. Majority of prod f! perfs 12,004-022'DIL. SI well. POH w/ HP gauge. Chngd 7/32" to 3/8" WL--retest lub. RIH & perfd HB #2 12,055-080'DIL. Compl perfg'rHemlock. Total perfd interval is Bench #1 ll,984-12,022'DIL & Bench #2 12,046-080'DIL. RD WL & returned well to test. Rate @ 0700 hrs = 3578 BFPD w/ .7% WC (3503 BOPD) w/ 207 GOR. Cont tstg well. FINAL REPORT. Union Oil and Ga,,-,..C~sion: Western Region Union Oil Company or California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL October 21, 1983 Hand Carried TO: William Van Alen FROM: R.C. Warthen LOCATION: 3001 Porcupine Drive LOCATION: Alaska District Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Re: Marathon Oil Company TBU D-42, as follows: One (1) each blueline and sepia as follows: (1) BHC Acoustilog Gamma Ray/Neutron 2" (2) BHC Acoustilog Gamma Ray/Neutron 5" (3) Densilog Gamma Ray 5" (4) Dual Induction Focused Log 2" (Logarithmic) (5) Dual Induction Focused Log 2" (Linear) (6) Dual Induction Focused Log 5" (Logarithmic) (7) Densilog Neutron Gamma Ray 5" (8) FDC/CNL Porosity (9) CNL Count Rates (lC) CBL/VDL 2" (ll) CBL/VDL 5" (12) Cased Hole Normalized FDC/CNL Porosity (13) Cement Evaluation Log (CET) (14) Directional Survey Guidance Continuous Tool (GCT) One (1) magnetic tape with verification listings LEASE A~KNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: Alaska Oil & Gas Cons. [;ommission Anchoraga STATE OF ALASKA '~ ~ ~ ~~r~ . .-_-- ALASK~,~.:)IL AND GAS CONSERVATION !.~./1MISSION! ~ ~ I~ WELL COMPLET,ON OR RECOMPLETION 'REPORT AND LOG 0IL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] : -_ 2. Name of Operator ' ' Union Oil Company of California * 3. Address P. 0, Box 6247 Anchorage, Alaska 99502 4. Location of we, at surface Leg A-2, cond. #7, Dolly Varden Platform 749' FSL, 1135' FWL, sec. 6-8N-13W-SM At Top Producing Interval , 3311' FWL, 1886' FSL, Sec. 32-9N-13W-SM At Total Depth 7. Permit Number 83-53 8. APl Number 5o-733-20205-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-42 11. Field and Pool 3660' ~L, 2261' FSL, sec. 32-9N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB Above MSL I ADL-18730 McArthur River Field _una ._J. !iS_, , Au~. ,-.,. I~83 , o~p~. ~_o, ~_~8.~ I =u '~"'~'°~ I ~_] One 17. TotalDepth'(MD+TVD) 118. Plug~ackDel~th(MD+TVD)119. Dir~ctionalSurvey I 20. DepthwhereSSSVse, I 21.ThicknessofPermafrost 12830'MD 9875"TVDI 12736'MD 9801'TVDI YES [] NO Fl 297' feet MD 22. Type Electric or Other Logs Run GR/ SP/ DIFLL Sonic/ FDC/ CNL, GR/ CCL/ CBL/ VDL, GR/ CRT, Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 13 3/8" 9 5/8" 7I! WT. PER FT. GRADE 68# K-55 47# -80 P-11~ 29# Stage co] N-80 SETTING DEPTH MD TOP I BOTTOM Surfac~ 3000' I Surfac~ 10510' Llar@ 69184' 10,169 112828' 24. Perforations open to Production (MD+TVD of Top and Bottom and ' - interval, size and number) Bench 1 Top Bottom 11,984'MD (9,202'TVD) 12,022'MD (9233' TVD) ' r'': ;': ' ' Bench 2 ..... ' Top Bot~Gm 12046'MD (9253' TVD) 12080'MD (9281' TVD) ~. .. '.. . .:- ' ~,1 ...- .. : : 7--0' Open 8 HPF " HOLE SIZE 17 1/2" CEMENTING RECORD 1000 sx C1 G AMOUNT PULLED Cmt to surface 12 1/4" 850 sx Cl G 1st st _ 1050 sx Cl G 2nd st 750 sx Cl G 25. TUBING RECORD SIZE_ i-DEPTH SET (MD) I PACKER SET (MD) & ~/?"I 10_206' I 10,184'(PBR) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '- DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED -_ . · 27. PRODUCTION TEST Date First Production .: :' .. Sept. 6; 1983 Date of Test [ Hours Tested 9/10783 ,- [ 24 Flow. T~bing Casing Pressure Press. '250 1140 28. Gas lift :- IPRODUCTION FOR IOIL-BBL GAS-MCF ITESTPERIOD~ 13359 730 ' .ICALCULATED , IOIL-BBL-..GAS-MCF [24-UOUR R~TE'I~]3359-- .730 CORE DATA Method of Operation (Flowing, gas lift, etc.) . .. . - ~. . ' - WATER-BBL , 27 _ . WATER-B B L . 27 " CHOKE SIZE IGAS-OILRATIO [ 217 OIL GRAVITY-APl (corr) ' 35 ..... ':"' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ .. - . . .. - ;:.: _ - ~. . _ . . ' ~ ;' . . . . * Marathon Oil Company --- Sub-operator. Form 10~07 R~¢. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate - · -. . ..'. ... .:' · .. , -, . , GEOLOGIC MARKERS ' ' FOflMATIO'NTESTS ....... o-. .... i~IL~N4~'~F ~' ~J ~ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase~ · . . · · .. 31. LIST OF ATTACHMENTS . · , 32. . I her that the forego correct to the best of my knowledge -- DIST DRLG SUPT 9/27/85 . : . sig Title Date -- - 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 di~nn~a~ water ¢,,"n~,' for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. - - ..... . Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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". S UB-$ URFA CE DIRECTIONAL SURVEY [-~ UIDANCE ~]ONTINUOUS r'-~ oo I Company MARATHON OIL COMPANY Well Name Field/Location TRADING BAY UNIT D-42 MCARTHUR RIVER. KFNAT. A)AKR~ Job Reference No. 68619 Lo~ed By: Pawl ows ki Date (Re-Computed) 31-$EP-84 Computed By: COLSON J.L., TRAD'Y,] B-"? '_":'_T Z '2 K3~,~TXSR 2:'-,'£-. TVi,,.! P_]T F~.-,? -_-_-T F_.,,a,T- dOB REFERENCE SOUTH WELL: TPADING BAY UNIT.~_.. 2 SURFACE LOCATION- (S6, -i8N, R13W) -8000 VERTICAL PROJECTION -6000 -4000 -2000 0 O 2000 "'~"""" 5'-)`.`)'.`' ....... 8000 ! ~ ~ L ~ ~ ~ -' ~.---~-~...- .................... ~ ...... ~- .......... e ........................... ~ ....................................... · ~ - ~ ...... .__: ............................................. ~--~.~- ................................................................................... PI~OJECTION ON VERTICAL PLANE OF AZIMUTH 0 SCALED IN VERTICAL DEPTHS HOF~IZ SCALE : 1/2000 IN/FT WELL: TRAD1N~ BAY UNIT [' '9 SURFACE LOCAIION: (S6, 'N, Ri3W) HO RI ZONTAL PROJ ECT I ON NORTH 8000 R£F 686!9 SCRLE = 1/2000 !N/FT 6000 4000 2000 -~000 -4O00 -8000 OUTH-8000 -IZO00 WEST : : : : - : ~ ~ : , ~ ~ ~ ~ ~ .-' : ~ . , : : : i ! . : - · : ~ : : "~'",~'"~"": .;- :' 'F-'~'"! .... ?'"~"'?'"?-"?"-:'"'"~? ..... -,' '!'-?-?"r'-~'"??' .-'"' ~ ~ :.-: ~- : , ] . i : i ' ' ' : ' : ; ' ; ' :-+.+-+-~.-'.'.-.:=-.?~+'.: H.-i-~-~+H+!----:.-+-~.-~---!..-~---t-.-~---?--~ ...... '~---~,--!---~ ................. ~..~,.-~.-+-.~..-T ........... +.--~.-+.~.--!..~-..~-.-i ................ :~:~:F'-~'-!---~ +!~-~!--~'-!-:.i---!~'-t-.~--~--i-:H--?-~-! i 1-T'"":"!"--'"'i"~-'-"::"T'":":'''~''i ...... i'""~:":l ......... -'":'"~'"F'~'"'.'"":'"t .............. ~ ........ i ..... :' ~ · ~ ' I' ................................. : ....... " - 10000 -8000 -S000 -4000 -2000 0 ~00C;) 4000E~S7 t, F:bA I., I,t t!:T tt I l I);.; {,t,' 'I ul.~l, I,[~(.:A'I'II'~N: 'I'AI',GI'.:t'J'I' I Al.,- [ I,J T b'l~II'ill,h 'l' I f}!i: VEi~'I I('hl, ,'Sk,(:'l lllh: ri[Jill2'., i)15'i , dverdcled devia[lon and azimutl~ P~UdE:CTEL1 Un'l'(,) A 'I'Ai~(;E'I' AZI!,tUTtt (,IF NL)I~T H () DEG M J t~ i R t.~ t< D l.; I:'T I! !) E PT ~i 20()().0() 11319,1 i 21()O.OU lqS.g,2b 22()0.00 20_'15,53 2300.00 2107,32 2400,()() 21'/5,19 2500.00 2244,69 260(),00 2317.1() () () 2459,7 (.) l.,li'l<t'tJl,;\TL[, VALut'.;J I-tJl~ k,~/Eh ¢. . b ~i t-S - S 1. A ('l ii. 14., I'. YKR'rI(iAI~ I~u, VlA'I']LIt,I AZLt ,l'l'tl I)h.i"l'fl I'b;G rlLN I;I':G qIfi 249,1. I 2 2566.'77 41 2639,57 42 48 N 2712,~ 42 59 2 It~6,34 4~ 29 2859.93 42 4h ri 23 2gJJ,7o 42 25 N 3o0'1.27 -I2 38 .~O~l,Oa 42 15 N 23 40 ~154,72 42 53 N 23 ~ K V ~.K r I('AI, SI'iCI I[)N [.'bET () ,00 0.35 1.J7 2.05 2,84 1,9g 2,24 8.48 1~,4! 33,RO 54.66 BO,OB 108,60 140.~t2 177,51 220,13 26~,o5 J22,f19 382,52 441.61 599.40 024,01 693,56 766.94 838,67 906,45 972,g0 t038.2'1 11(12.96 11h7.3~ 1229,85 1292.24 1354.26 1416.17 1417.99 153b,30 1o01.59 1603.28 1725.]4 ?7-bh~' r-84 L)~'I'K ()l-' bUkVE¥: 31'"Atit;-U3 KEbI,Y BU$ttIi,,(.; P.t, EVA'[ItJr,: ]()t3 .. l(~ [''EEl' OF t'iEASLJt{EI) I)EP'll: DL]GI.LG SEVERITY t)EG/iU0 R kC'I'AI~GI.IbAR COtJi, I, N(.JR'I'tI/SUU?H EASI/ F'E E T F F. E 'I k I.]ST I)I~T. 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J'l I~ 2~ t~ k. 1916.29 ~'3 68 l~ 22 :)b F, 1981.90 45 .th t~ 22 bO ~. 204~,21 4f~ .~q N 22 41 k 2114,75 4', 30 I; 22 JU E 21B1,49 45 43 I~ 22 b g 22.17.64 .%5 11 N 21 57 E: 2313.55 44 6 I~ 21 55 k 2J;8.63 (,,,t:t9 1758.11 ;l 385, lb ~:. 1d29.24 0,63 1851,92 ii 413,15 E 1891,45 1,59 1916,29 N 440.b9 ~, 19bo,29 0,59 1981,90 N 4t. 8,55 ~: 2056,54 I 17 2048,2A N 496,52 k, 210'1,b3 1:08 2114,75 N 524,54 F. 2178.03 1,37 21B1,49 N 552.24 e. 2250.30 1.31 22~7.64 N 5't9.41 k. 2321.12 1 03 2313,55 N 606,03 K 2391,60 0:~9 237a,6J N f. 32,2] ~. 2461,22 I, !0 24,13,6,9 Fl t:58.,:t'1 t- 2.5'Jo.~.5 1,08 250U,32 ,, 01;4,02 g 2599,91 O,Bb 25'12,24 N 709,13 ~: 2558,2() (),'12 2635,0~ N 733,~6 t:: 2736,8~ 0.04 27U(),lb N 758.1~ F', 2804,58 1,21 2763.~4 N '182.3~ ~, 2~72.~ 0,58 282~,8U N 805.99 ~, 2939,4b U.I] 28~g.2~ N 829.27 ~, 3005,9q 0,71 2q51 71 h R52,~7 F; 3072.35 1,16 3013',50 N H75,24 ~: 3138,U9 (1,99 .jt)/5,99 i'~ 8~.~,19 f; 32(.).A.45 1,50 31.:i8,72 I',i 921,99 ~., 3271,33 0,34 3202 4b N 946,71 E 3:J39,4~ 0,73 J21~6:03 N 971,49 ~; 3407,45 0,7'1 3330,0U I~ 990,40 E 34'15,d~ 0,41 34bt,),40 N 104b,16 E 3615,1~ 1,15 3526,13 N 1071,29 E 168b,2~ 0,43 3592,5~ N 10~5,~'1 ~i 3766,22 1,46 3659,1b N 1122,36 ~; 3827,41 1,15 372h,69 la 11~t8,21 ~, 3899,57 l,U5 3'194,7U N 1174,43 L. 3972,2u 6,94 3862,59 N 1202 34 ~: 4045 40 1.78 3925,80 N 1237:6H ~, 4110:2B 1,()1 3986,67 N 12'16,2~ g 4185'97 0,38 4047,06 N 1314,91 k; 4255, 33 0,82 4107,06 Il 1353,35 E 4324,29 () 41 4lOb,b9 N 1391,79 L: 4192,99 0:97 4225,05 N J430,17 g 446J,49 0,77 42B5,04 N J46U,45 E 4529,67 AZI ;,Itl I It L)EC, ~ I I~ '['l~l~,l) llJ(; ~,A¥ II~i l'f I~-,lz HJ'A[~ I tllib, Iq I Vi..14 { tJ,~t'l, I - t I ~1;: I)A ri::: 2 i-,bJ';l~' l'-'dq l,,'ll.l,t ~1,,~'11'.1, vat,t,~'::, }'tlr< l<qLd IOU kEt:il t' l'~ L., I" l~Alr, iii' ~i. 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Et:.T I"Ei'.T t' u,L'r DL¢, I'.tl ri 100o, ()0 84.(~H. 2 t ,t 1~}1 ,b'l 1100,00 {J492,05 1200,oo ~5'15, lb }~'168,45 l]O0,()O ~655,61 85.t~,97 1400 (10 A7]6.62 8029.92 15(;0~00 8815,55 1600 O0 8894.53 170(),(}0 ~9'13,15 1800,00 9U53,11 H945,41 1900,00 9133.bt .12 'lb tJ 3'i 'i'1 t'., 5491·Ul O,U5 4i 22 N 11 JZ E 5543.95 0,64 .t0 34 N 31 3'9 E 5595·86 1,39 ]g 0 N 3't 41J ~.: 5646.53 ()ebb 3'1 32 N 3~ 1 F; 5695051 1.54 3,. 1 N 38 39 k 5742.47 1.51 ..~4 bl N 39 I E b';87,]7 0,75 34 22 N .~8 11 E 5831.81 {1 47 i~ 37 22 ~, 5816,11 0,59 31 45 N to 54 ~'. 5912.36 0.89 .ti h N Jd 2.t E. o00'1,15 1,lb ]4 ~2 ~ ]}] lO E 605[),80 1o35 t6 16 N 3~ b E, 009b,3~ 1 ~I 29 N ~H 21 E 6143.55 l,lb .t'l 53 IW .]ll 29 E 62]9,96 37 45 ~ 3~* 8 E 52~8,t9 2,40 36 ]3 N 40 45 E 0129,04 0,38 ~5 5H N 'tl 28 E bJT~,g4 1,45 tt3,14,1.4 a lbOo.b(~ h 459'/.ut ~ 19 '1 I', 4402,50 N 1544,02 f; 4565,6U ,~ 19 2U b, 4460,20 N 1592.95 ~. 4732,7'1 :, 1~ J2 k. q512,0~ N 1617.50 k; 479].2~ ~ 19 43 ~: q574.10 N 1659,40 L 4865.UO i~ 19 5c, ~. 46]1,21 N 1698,25 t 4932,77 k 20 s e 46~7,9~ N 1736,~ k 4999,~4 k 2u 19 t ~745,59 N l'l'16,]2 ~. 5067,14 ,~ 2~ ]1 ~. 4802 $o h 1810,12 ~; 5134.29 ,~ 20 42 E 4859:33 N 185o.25 ~: 5201.~0 ~ 20 54 F, 4!116,74 1,{ 1696,'!9 t'. 5269,93 4914,2:/ kl 19]1:i,00 I:, 5J]8,42 bOJ2.21 I~ 1979.81 ~: 5407.06 50'30,3~ N 2021,93 h 54'1'1,2J r,~ 21 39 b148,7~ N 2064,79 E 5541.3~ 520'1,21 N 2108,08 ~: 5b17 75 5255,6~ N 21bi,b] ~ 5688:24 N 22 13 E 532J,6~ N 2194,72 E 5758,30 ~ 22 24 g 5~80,81 N 22~7,70 E 5827.55 54]507~ h 22~0.15 ~ 5895.54 5491 O]. I~ 2321,93 t 59ol.7o 5543~95 Iq 2362,88 E 5026,49 b595 85 h 2402,89 E 6089,95 bO4b:5~ I~ 2441,~5 ~.: 6151,90 a 2J 2~ ~': b595,51 N 24'19,~5 t 6211,97 5742,4/ N 2516,96 ~. 62~9,~5 5787,3/ N 2553,34 ~ 6325,6u 58JI,81 N 2588.~2 E b3}10.59 58'/6,11 N 262].05 E 6q]4,99 ~'~ 24 3 E 5912,]6 N 2650,79 E 6479,40 5954.3q N 26t19,94 i~, 6542,tt'I ,',,24 It> bOO7,1:::) I'~ 2723,B1 E 5595,dJ ,~ 24 23 E: bUbO.SO t~1 2'158,2t~ E 6649.83 l~ 24 30 E; t, Ogb,3U N 2793,99 ~. 67Ub,14 N 24 37 ~: 6143,55 N 2831.20 E. 6754.53 i'~ 24 q't b191,7~ N 2~69,23 E 0824,2q ~ 24 bl ~2J9,90 N 2907,16 ~; 6883,94 I~ 24 5~ E ~2~8,1~ N 2945,77 f 6943,9~ ~ 25 0 K 6329,0~ N 29~0,08 E 6995,54 N 25 12 ~: 51'/8,94 N ~023,q2 [; 7059,17 N 25 21 E .4CAI~ I ltllt' L : Ii I I-'Lil ,~'1 I',1.' j' L)E P l;h 2 0 0 U. (~¢ 92 1 2200,00 937 2 30 o, ()ti ti45 25()0.()0 961 2600. (~) 9~9 , ( , (10 q7 I , , (I i) 9 H () V!'t', I'ICAI, 5EC'I'Ii]N IIA'I'I.; I I- ;,~it.,gt',¥: 31 --hUt,-:i t K 1-.: 1., L ~ t~o L. ih I r,(, glll.jl:.lJ<J: h; t{ F: (~ 'l ..q N (j d l, A I4 fJLidi-I,l.~,~lt'.L) rll,,.,lA, t.:l'.l-,,,~t~t.,t'. r,~ t I l( '1. tt / $ U tl 1' tt b. A S'J / ~, Ig,% t t., l b'l'. ,~ZI ~-.tJ I Il ['ELI' t' i~:E 1' ['ELl I: i-'(., rll,~ rRAI.)ItlG t~A¥ I.IN.[T D-42 ~cAhrHI.II~ RIVER Ki,:ilA! , AI,ASKA F A t., !:: b l't,: ! I I.. ,StJ LAI;I. IRi-.i) VkRTICAI, VE D {-' P T I-, !) E [-: T ! t I;AJ'E t)l" 5URVLYl KE[,I,¥ BU,SHING LI,LYA'JIONI IOv,TU i-r EN(;II,,I<E:H; PAwl,,lk, SFl RTICAI., l~t'.V lA'FlUb AY',liltJ'l~l l)l:.:P'l'tl I~)EG r.., I I'~ L)EG ,~ 1 ~1 VGA]'] CAI, SEC3 ION Fl:, E'[' Dg(;/lO0 (~,00 0,00 ~4,66 2,31 499,65 2,12 1167,38 4,32 17~8,11 0,89 2443,69 1,10 3075,99 0,99 3726,69 1,15 4344,13 0,97 4916,74 0,94 5491,01 0,85 5964,34 1,39 6422,07 0,09 u750,29 0,00 O.o0 O,UO 10o0,00 99b,22 2000,00 1879,11 1772o41 3000,00 2600,d2 2494,12 4000,00 33]4,48 3227.78 5000,00 403B.5¢) 39Jl ,80 6000.00 4174.9(~ 4668.2b ~' '0.00 5491,o0 5J84,9() u..inO\ 6910o38 0000,o0 7609,09 75t~2,99 1000,00 8408i2'1 u~t)l,b7 2000,00 9215 Oo 9108,36 2739.0o 9803 43 9696, 13 42 46 N .]7 47 !~.. ] ] 0 N 37 45 g 35 5 N 42 4 E 36 N 44 2'1 g R{<C.']ANGULAI,t CUt,JRDi>iA'I'E5 hUr<lZ, bKPAIr~'i'bt~l", ~ EEl' FEET !. EEl' DEG ~1N O,OO N O,OO E O,OO ~, O I~ g b4,6~ N 21,20 E bU,03 ~ 21 12 E 499,6b N 3,77 W 499,00 l~ 0 25 ~ 1167,]8 N 109.43 E 1172,49 ~] 5 21 E 1~80,11 N ]~5,7~ E 1829,24 ,'~~2 1o E 2443,69 N 658,37 E 25~0,~3 *~ lb 4 E 30'15,99 N 898,19 g 3204,45 t~ 16 1~ E ]72~,69 N 1148,21 g 3899,57 N 17 ? E 4344,1, N 1506,b0 E 4597.97 N 19 7 E 49~6.74 N 1896,79 E 5259,93 N 21 5 El bq91,O1N 2321,93 E 59bl,Tb ,~ 22 b5 ~, 5964,34 N 26B9,94 E 6542,~7 N 24 lU ~.: 6422,07 N 3062,12 g 7114.75 i~ 25 29 E 0750,29 N 3365.]2 E 7542,67 N 26 29 E ~I!liil Directional Surve~ Table JUNE 21, 1994 10:26 Survey datum Survey elevation Survey company Survey method Survey date Surface location projection township 106.00 208384.0 STATE ALK4 TRADING BAY UNzT D-42 UNOCAL/ALASKA . EPARJJD API~ 507332020501 OPERATOR MARATHON 2490829.00 · D42 Measured Vertical SubSea Drift Coordinates Depth Depth Depth Angle Azimuth X Y 0.00 0.00 100.00 100.00 200.00 199.99 300.00 299.98 400.00 399.98 500.00 499.93 600.00 599.53 700.00 699.05 800.00 798.23 900.00 896.54 1000.00 993.79 1100.00 1090.00 1200.00 1185.43 1300.00 1279.36 1400.00 1371.03 1500.00 1460.10 1600.00 1545.81 1700.00 1627.82 1800.00 1707.24 1900.00 1788.46 2000.00 1869.88 2100.00 1948.25 2200.00 2022.28 2300.00 2091.81 2400.00 2159.45 2500.00 2230.83 2600.00 2303.52 2700.00 2374.97 2800.00 2445.36 2900.00 2515.93 Calculation method Reference 106.00 0.00 0.00 6.00 0.39 359.12 -93.99 0.53 358.36 -193.98 0.75 315.21 -293.98 0.33 175.66 208384 2490829 208384 2490829 208384 2490830 208383 2490831 208383 2490830 -393.93 1.86 109.76 -493.53 5.13 70.01 -593.05 5.64 32.12 -692.23 7.30 11.67 -790.54 10.57 7.97 208386 2490829 208395 2490832 208400 2490840 208403 2490853 208406 2490871 -887.79 13.45 357.31 -984.00 15.83 358.03 -1079~43 17.39 357.51 -1173.36 20.06 357.73 -1265.03 23.56 357.49 208405 2490894 208405 2490921 208405 2490951 208404 2490986 208403 2491025 -1354.10 27.04 357.57 -1439.81 31.01 357.43 -1521.82 34.90 357.30 -1601.24 37.42 356.28 -1682.46 35.69 353.76 208403 2491071 208402 2491122 208400 2491180 208398 2491240 208393 2491299 -1763.88 35.49 357.34 -1842.25 38.40 358.47 -1916.28 42.24 358.33 -1985.81 45.95 357.80 -2053.45 47.44 359.33 208392 2491357 208392 2491419 208391 2491486 208390 2491558 208391 2491631 -2124.83 44.45 6.80 -2197.52 43.38 13.84 -2268.97 44.39 19.96 -2339.36 45.26 23.85 -2409.93 45.12 24.39 208401 2491701 208419 2491767 208445 2491832 208475 2491896 208506 2491960 : Tangential (default from database) : Map projection STATE ALK4 Measured Verticax Subsea Depth Depth Depth 3000.00 2587.57 -2481.57 3100.00 2659.98 -2553.98 3200.00 2733.36 -2627.36 3300.00 2806.50 -2700.50 3400.00 2880.24 -2774.24. Drift Angle Azimuth 44.24 24.53 43.60 24.50 42.80 24.42 42.99 24.08 42.49 24.12 Coordinates X Y 208537 2492023 208567 2492085 208597 2492146 208626 2492208 208655 2492268 3500.00 2953.66 -2847.66 42.76 23.89 3600.00 3027.49 -2921.49 42.42 23.91 3700.00 3101.05 -2995.05 42.64 23.90 3800.00 3175.07 -3069.07 42.25 23.78 3900.00 3248.34 -3142.34 42.89 23.13 208684 2492330 208713 2492391 208742 2492452 208771 2492513 208799 2492575 4000.00 3321.10 -3215.10 43.31 23.19 4100.00 3392.65 -3286~65 44.32 23.10 4200.00 3463.81 -3357.81 44.63 23.14 4300.00 3533.32 -3427.32 45.97 22.92 4400.00 3603.07 -3497.07 45.77 22.83 208827 2492637 208856 2492701 208886 2492765 208915 2492830 208945 2492895 4500.00 3671.50 -3565.50 46.82 22.68 4600.00 3741.59 -3635.59 45.50 22.50 4700.00 3811.42 -3705.42 45.71 22.09 4800.00 3881.91 -3775.91 45.18 21.95 4900.00 3953.71 -3847.71 44.11 21.92 208975 2492962 209003 2493027 209032 2493093 209060 2493158 209088 2493222 5000.00 4024.81 -3918.81 44.68 21.67 5100.00 4097.27 -3991.27 43.56 21.62 5200.00 4169.68 -4063.68 43.61 21.26 5300.00 4242.38 -4136.38 43.36 20.94 5400.00 4315.91 -4209.91 42.66 20.88 209115 2493286 209142 2493350 209169 2493414 209195 2493477 209221 2493540 5500.00 4389.25 -4283.25 42.83 20.70 5600.00 4463.73 -4357.73 41.86 20.45 5700.00 4538.27 -4432.27 41.80 20.43 5800.00 4612.96 -4506.96 41.68 20.26 5900.00 4688.28 -4582.28 41.13 20.17 209246 2493603 209271 2493665 209296 2493726 209321 2493788 209345 2493849 6000.00 4762.79 -4656.79 41.83 20.30 6100.00 4836.25 -4730.25 42.72 21.18 6200.00 4909.22 -4803.22 43.14 21.29 6300.00 4982.52 -4876.52 42.86 21.30 6400.00 5054.36 -4948.36 44.08 21.07 209370 2493911 209396 2493974 209422 2494037 209448 2494100 209475 2494164 6500.00 5126.04 -5020.04 44.20 20.88 6600.00 5197.13 -5091.13 44.69 20.83 6700.00 5268.13 -5162.13 44.77 21.02 6800.00 5338.05 -5232.05 45.63 20.87 6900.00 5407.73 -5301.73 45.83 21.22 209502 2494229 209528 2494294 209555 2494359 209582 2494425 209610 2494491 7000.00 5476.43 -5370.43 46.60 20.89 7100.00 5544.77 -5438.77 46.89 21.29 7200.00 5613.20 -5507.20 46.82 25.18 O 7300.00 5682.05 -5576.05 46.49 31.89 209637 2494558 209666 2494626 209698 2494691 209738 2494751 Calculation method : Tangential (default from database) Reference : Map projection STATE ALK4 Measured Vertica~ Subsea Drift Depth Depth Depth Angle Az imuth Coordinates X Y 7400.00 5751.77 -5645.77 45.79 32.56 7500.00 5821.84 -5715.84 45.52 32.58 7600.00 5892.07 -5786.07 45.38 32.69 7700.00 5962.81 -5856.81 44.98 32.95 7800.00 6033.66 -5927.66 44.88 32.78 209778 2494811 209818 2494870 209858 2494929 209898 2494987 209938 2495046 7900.00 6105.01 -5999.01 44.48 33.00 8000.00 6175.94 -6069.94 44.82 32.76 8100.00 6247.98 -6141.98 43.91 33.45 8200.00 6320.05 -6214.05 43.89 33.73 8300.00 6393.24 -6287.24 42.95 33.90 209977 2495103 210017 2495162 210057 2495219 210096 2495275 210136 2495331 8400.00 6465.63 -6359.63 43.62 34.14 8500.00 6537.70 -6431.70 43.89 34.17 8600.00 6610.10 -6504.10 43.61 34.30 8700.00 6682.58 -6576.58 43.55 34.76 8800.00 6754.57 -6648.57 43.95 35.17 210176 2495387 210216 2495443 210257 2495499 210297 2495555 210339 2495611 8900.00 6826.09 -6720.09 44.34 35.10 9000.00 6897.07 -6791.07 44.78 35.40 9100.00 6967.16 -6861.16 45.50 35.52 9200.00 7036.95 -6930.95 45.74 35.91 9300.00 7106.46 -7000.46 45.96 36.17 210380 2495667 210423 2495723 210465 2495780 210509 2495837 210553 2495894 9400.00 7174.99 -7068.99 46.74 36.24 9500.00 7243.33 -7137.33 46.89 36.67 9600.00 7312.00 -7206.00 46.63 36.67 9700.00 7381.50 -7275.50 45.97 36.82 9800.00 7451.86 -7345.86 45.28 37.08 210597 2495952 210642 2496009 210687 2496066 210732 2496123 210776 2496178 9900.00 7524.12 -7418.12 43.73 37.44 10000.00 7597.53 -7491.53 42.77 37.79 10100.00 7672.57 -7566.57 41.37 37.53 10200.00 7748.53 -7642.53 40.57 37.66 10300.00 7826.23 -7720.23 39.01 37.66 210819 2496232 210862 2496285 210904 2496336 210945 2496387 210984 2496435 10400.00 7905.52 -7799.52 37.54 38.01 10500.00 7986.39 -7880.39 36.03 38.66 10600.00 8068.45 -7962.45 34.85 39.03 10700.00 8150.99 -8044.~9 34.37 38.19 10800.00 8234.10 -8128.10 33.79 37.38 211023 2496483 211061 2496528 211098 2496571 211134 2496614 211169 2496658 10900.00 8317.23 -8211.23 33.76 36.90 11000.00 8401.10 -8295.10 33.00 37.75 11100.00 8484.86 -8378.86 33.11 38.41 11200.00 8567.24 -8461.24 34.53 38.17 11300.00 8647.86 -8541.86 36.27 38.08 211203 2496701 211238 2496744 211273 2496786 211309 2496829 211347 2496875 11400.00 8727.21 -8621.21 37.49 38.36 11500.00 8806.07 -8700.07 37.94 38.05 11600.00 8885.00 -8779.00 37.88 38.49 11700.00 8964.07 -8858.07 37.75 39.14 211386 2496922 211425 2496969 211464 2497016 211504 2497063 Calculation method : Tangential (default from database) Reference : Map projection STATE ALK4 Measured Vertica~ Subsea Drift Depth Depth Depth Angle Azimuth 11800.00 9044.41 -8938.41 36.54 40.75 11900.00 9125.33 -9019.33 35.98 41.47 12000.00 9207.16 -9101.16 35.08 42.06 12100.00 9288.61 -9182.61 35.47 42.16 12200.00 9369.40 -9263.40 36.10 41.98 Coordinates X Y 211544 2497107 211584 2497150 211623 2497192 211663 2497234 211704 2497276 12300.00 9449.11 -9343.11 37.15 42.07 12400.00 9528.11 -9422.11 37.81 42.34 12500.00 9606.67 -9500.67 38.22 42.92 12600.00 9685.02 -9579.02 38.42 43.80 12700.00 9763.25 -9657.25 38.52 44.31 211746 2497320 211788 2497364 211831 2497409 211875 2497452 211920 2497496 12739.00 9793.73 -9687.73 38.60 44.45 12830.00 9864.85 -9758.85 38.60 44.45 211937 2497513 211978 2497552 Calculation method : Tangential (default from database) Reference : Map projection STATE ALK4 Suggested. lorm to be inserted in each "Active" well folder to check for timely compliance with our regulations. - ~ 0pera[or, 'WeI]' ' and Reports and Materials to be received by: /~-/_~ Date Required Date Received Remarks , Cc~pletion Report Yes q _Samples /~6/j~-~ ]9 Mud Ix:xJ .d, ~ ' ~ .... ~ Core ~scriPtioh ~,., ~ ~ ~ : ~'-- 0 ~- '~ '?; ' / Registered ~ey Plat ~/id Inclina~on Su~ey ~ ._ ..~ - .: ~ : Drill St~ Test Re~s '~-~:'4/~' ~- , :- Digitiz~ ~ta ..... / ~ /~/~ ~ ? -' .. / ~ STATE OF ALASKA ~' ALASK.~,.OI L AND GAS CONSERVATION ~q- MMISSION MONTHLY REPOR. OF DRILLING AND W(i,, KOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator , 7. Permit No. 83-53 Union Oil Company of California* 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99502 50- 733-20205-01 4. Location of Well atsurface 749'FSL, l135'FWL, Sec. 6-T8N-R13W-SM Leg A-2, Cond. #7, Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-42 11. Field and Pool McArthur River Field For the Month of September 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at EOM - 12,830' Total footage drilled - 0' Completed operations @ 1200 hrs, 9-10-83. 13. Casing or liner run and quantities of cement, results of pressure tests N/A 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data Perfd Hemlock Bench #1 11,984-12,022' DIL Perfd Hemlock Bench #2 1'2,046-1'2,080' DIL *Marathon Oil Company Sub-Operator /'~ .,.,i . 17.I he~~ t~t the foregoing is true and correct to the best of my knowledge. ~~eport on this form is required for each calendar month, regardless of the status of operations, and must bo filod in duplicate ~ith tho ~la~ka O~nd Gas Conservation Commission bg the 1 [th of the succeedin~ month unless otherwise directed Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ~. ALASKt ILAND GAS CONSERVATION C 'AMISSION - MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . !1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California 83-'53 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 9950'2 50-733-20205-01 4. Location of Well atsurface 749'FSL, l135'FWL, Sec. 6-T8N-R13W-SM Leg A-2, Cond. #7, Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-42 11. Field and Pool McArthur River Field For the Month of August , 19 8.3 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at EOM - 12,830' Total footage drilled '3340' 13. Casing or liner run and quantities of cement, results of pressure tests Cemented 9-5/8" csg to 10,510' - First stage: Second stage: 850 sx gel slurry followed by 200 sx neat. CIP 0700 hrs, 8-9-83. 1050 sx gel slurry followed by 260 sx neat. CIP 1300 hrs, 8-9-83. Cemented 7" liner 10,169-12,828' w/ 750 sx cmt. CIP 0940 hrs, 8/27/83. 14. Coring resume and brief description N/A 15. Logs run and depth where run CNL/FDC/DIFL/GR/Acoustic/Caliper/SP - i0,490-3000' FDC/CNL/GR - 10,500-3000' CBL/VDL/GR/CCL - 10,500-3000' DIFL/Sonic/FDC/CNL/SP/GR - 12,828-10,508' GR/CBL/VDL - 12,714-10,163' I 6. DST data, perforating data, shows of H2S, miscellaneous data /" ~;-i"i¥.,, ~?;! , .,. *Mara~O_il Company Sub-Operator 17. I hereby/~erti~ythat the foregoing is true and correct to the best of my knowledge. (/ SIGNED//"b/-.~/ff/ /~ f (~-¢_,~Y-~--~-/(_,,YITLE__~ __ DATE NO eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oiled Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA ALASKA iLAND GAS CONSERVATION Ct iMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Union 0il Company of California* 83-53 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99502 50-733-20205-01 4. Location of Well atsurface 749'FSL, l135'FWL, Sec. 6-T8N-R13W-SM Leg A-2, Cond. #7, Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-42 11. Field and Pool McArthur River Field For the Month of July ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at EOM - 9490' Total footage drilled - 8964' 13. Casing or liner run and quantities of cement, results of pressure tests 13-3/8" K-55 68# casing to 3000' w/ 1200 sx Cl C cmt. CIP @ 1710 hrs on 7-3-83. Cemented thru retainer and perforations w/ 296 sx C1 G cmt. CIP @ 1700 hrs on 7-7-83. Cement returns to surface. 14. Coring resume an~ief~e~r~'~'"~ Cut cores ah~45-30~ 3~57--3P%7' 4556-4586' 5070-5100' 6214-6241' 8066-8075' 8196-8226' 15. Logs run and depth where run DIL/SP/GR 3160-2000' DIL/SP/GR 4114-3000' DIL/SP/GR 8045-3000' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfd 13-3/8" csg @ 2480-2481' w/ 4 spf. / '~F :' :" ' ' "': *Marathon 0il Company 'Sub-Operator J~7- - 'L)~,,~ 17. ~ herebyce~y that the foregoing is true and correct to the best of my knowledge. SIGNED . z~~_/~__ _ _ TLE______ DISTRIC~T DRL__G S__U_PTDATE 8/10/83 NOTE//ort on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil' an~Gas Conservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10-404 Submit in duplicate .. ...-., STATE OF ALASKA ,. ALASK/~:'.;iL AND GAS CONSERVATION C~. AMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California 83-53 3. Address 8. APl Number PO Box 6247, Anchorage AK 99502 50- 733-20205-01 4. Location of Well atsurface 749tFSL, l1351FWL, Leg A-2, Cond. #7, Sec. 6-TSN-R13W-SM Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB above MSL ADL-18729 9. Unit or Lease Name Trading Bay Un it 10. Well No. D- 23/~)~.42, 11. Field and Pool McArthur River Field For the Month of. June ,19 83 -12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Recovered total of 5.55.9' of 13-3/8" casing and 559.9' of 9-5/8" casing from surface. Well D-23 is a shut-in Hemlock producer and the southern-most well in the reservoir. This well is now being redrilled toward the crest of the structure to the northeast and has been redesignated Well D-42. Spud date of D-42, 6-23-83. Depth at EOM, 2600'. Total footage drilled, 2074'. 13. Casing or liner run and quantities of c~ment, results of pressure tests N/A 14. Coring resume and brief description : N/A 15. Logs run and depth where run ~/^ 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A *Marathon Oil Company Sub-Operator 17. I hereby certify that the fo~regoing is'true and correct to the best of my knowledge. ' ......" NOTE-/e/laTort on this form is required for eac ca endar ont , ega d ess us o operations, and must be filed in duplicate with the Alaska Oil a~//G~s Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Forr¢~10-404 c,,~;, in ~l.nli~t~_ MEMORANDUM State of Alaska ALAS~IL .AND GAS CONSEI~V~TION COMMISSION ~ ~ . FILE NO: TH~:~ie C S~~ ~ * ~ - ~. ~ TELEPHONE NO: c~issioner FROM: Edgar W. Sipple, J petroleum Inspector SUBJECT: . Witness BOPE Test On Marathon' s Dolly 9~r~n Platform Friday, July 8, 1983: I '¢le~ft Anchorage via AAI fOr Kenai to ~itnes-s a BOPE test on Mar&thO;n"'~' ~-l~'Varde~ P1atfOrm~ ' The BOPE test commenced a~t*-'4:30 p.m. and was concluded at 8:50 p.m. There were two fail,la.'' One m~nuai"~&lVe On'the choke line and one manual %~ve'-on the kill line. =' 'The"~AOGCC office will :be nOtified w~h~n'' the' valves. _arel' repaired ~ and"teStea ~' to 3000 psi. '-:~ -~ ' " I filled out the AOGCC BO~P~ inspection .report which, is. attached. In summary, I witnessed t~ BOPE test on Marathon' s,.Dolly Varden platform. Attachment: /i4r. TOny Swift'called 'and reported the two /valves that failed were repaired and. tested ~ -~- to 3000 psi %~ 3:30 a.m.,'JulY 9, 1983. O&G. ~"4 ~.." ~ 4.C-8 0 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMblISSION B.O.P.E. Inspection Report Inspector Operator /~};i~ ~f-/O~. ~ ~.0 i~y V/~Z)em~.. Location:. Sec ~ T~ RS~I Drilling Contractor ~K~ ~,~;/~ Rig ~ ~ Representative ~._~7 Permit # ~-~-' /~Casing Set @ . .. Representativa-7~'~ .,~0.0 5 f t. Location, General Well Sign General HOusekeeping Reserve pit Rig BOPE Stack Annular Preventer P i~p e Rams Blind R~s H.C.R. Valve . , ~ .' ~ ~ C,,~~I~ Kil~ ~$ne Valves ~ valve Test Results: Failures Oll Test Pres sure ;~oo 5o0o ~ooo ACCUMULATOR S'YSTEN Full Charge Pressure: ~'~,.'Pf3 ps.ig Pressure After Closure / ~/OcQ _psig 200 psig Above Precharge Attained: O min ~se% ~ rain Full Charge Pressure Attained: N~~ ~70 '~ ? ~' ~ ~' ~ ~:~-'~'~ '~ -~ ~ iq Cqntrols: Master ~ Remote ¢[< Blinds switch cover ._ Kelly and Floor Safety Valves Upper Kelly. ~)/(~est Pressure Lower Kelly. O/~ Test Pressure Ball Type ~< ~"~Test Pressure Inside BOP Test Pressure Choke Manifold ~ Test Pressure No. Valves // ~00o .~0 C~ NO. 'flanges 9~ Adjustable Chokes / ~lydrauically operated choke Test Time ~ hrs. Repair or Replacement. of failed equipment to be made within' /~./%4~days and:" ~-~ Inspector/Commission office notified. . ' ' !i. ': ,, Distribution orig.' - AO&GCC cc - Operator cc - Supervisor. STATE OF ALASKA i ALASI~"DI k AND GAS CONSERVATION ("i;MMISSION MONTHLY REPORT OF DRILLIHG AND WORKOVER OPERATIONS !1. Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California* 83-53 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99502 50- 733-20205-01 4. Location of Well atsurface 749'FSL, l1351FWL, Sec. 6-TgN-R13W-SM Leg A-2, Cond #7, Dolly Varden Platform 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. · 106' KB above MSL ADL-18729 For the Month of May , 19 83 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-23 1 1. Field and Pool McArthur River Field 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations on 05-09-83. Plugged back Well D-23 to 1030'. Recovered total of 519' of 9-5/8" csg from surface. Recovered total of 7.7' of 13-3/8" csg from surface. After recovering 13-3/8" casing, a new well, D-42, will be drilled from this conductor. i13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 1 6. DST data, perf.orating data, shows of H2S, miscellaneous data Perfd circulating holes with 2-1/8" perf guns @ 15,304' in tubing. *Marathon Oil Company Sub-Operator RECEIVED JUN t ? 1983 Alaska Oil & ~:;,.-,, ........ ,', 17. I hereby/~tify that the foregoing is true and correct to the best of my knowledge. _SIGNE..~._~..//_ LE__ DISTRICT DRLG SUPT DATE O~.el"[d Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union Oil Compamy of California * 69-106 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50_733-20205 4. Location of Well Surface:' Leg A-2, 749' FSL, cond #7, Dolly Varden Platform 1135' FWL, Sec. 6-8'N-13W-SM 5. Elevation in feet (indicate KB; DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL- 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-23 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [--J Stimulate [] Abandon E~ Stimulation r-J Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions, on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). D-23 Abandonment Procedure · 5. 6. 7. 8. 9. Kill D-23 with drilling mud. Install BPV. ND X-mas tree. NU and test BOPE. Pull POH and LD 4-1/2" and 3-1/2" tbg. Abandon the Hemlock with 145 sx cement from 15485-16055'. Spot a 200' cement plug across the liner lap at 11,755 Set a bridge plug at 800'. Cut and pull 9-5/8" casing to + 800' in 40' segments. Cut and pull 13-3/8" casing.to + 800' in 40' segments. Spot a 200' cement plug from top of 13-3/8" stub '(290 · BPV. (55 sx cement). sx cement). * Marathon Oil Company - Sub-operator Alaska Oil & Gas Cu,15. Co~n~r]JssJon Anchoiage 14. i hereby certify, that the foregoing is true and correct to the best of my knowledge. The space belo~for Commission use [ '~ Conditions of Approval, if any: DISTRICT DRLG SUPT Oa,e 414183 Form 10-403 COMMISSIONER By Order of the Commission Dale Suhml! "lnlprlt,r)n,;" ,n T~,ol,r-ale April 8, 1983 Mr. Robert T. Anderson District Laud Manager Union Oil Company of California ?. O. Box 6247 Anchorage, Alaska 99502 Trading Bay Unit tie. D-42 Union Oil Company of California Permit ~io. 83-53 Sur. Loc. 749~FSL, I135'FWL, Sec. 6, TEN, P..13W, SM. gtmhoie Lee. 2134'FSL, 4151'F~L, Sec. 32, TWN, R13W, S~. Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, ~ one cubic inch chip from each foot of recovered core is required, samples of well cuttings and a mud log are not required. A continuous directional survey i~ required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log infor~ation shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~{any. rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by tbs Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulation~ promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) a~ld by the Federal Water Pollution Control Act, as amended.. Prior to cotamencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us im scheduling field work, please notify this office ~ h:our~ prior to comme~cing i~.~tallation of the blowout Mro Robert T, Anaerson .Trading Bay Unit No. D-42 -2- April 8, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drillin§ below the shoe of the conductor pipe, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, BY ORDER OF THE CO3.'IP~,ISSION C, V. ~hattertou Chairman of Alaska Oil and Gas Conservation Commission EnclOsure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be March 2.9, 1983 ADMINISTRATIVE APPROVAL ... NO. 80.45 Re= Application of Union Oil Company of California, operator of the' Trading Bay Unit, to drill, complete and produce the .~Trading'Ba~:Uni ~~wel!_. as part of the pressure main- -:~ project approved:bY COnservation Order No. 80. -. - f . ~- .. ? -. .. .- }~"~ Robert:'T. Anderson'S? District Land ~nager Union Oil Company of Californ~ P. Ol~ ~x 6247 Anchorage, Alaska 99502 ~e referenced application was received on March 22, 1983 and stated that the drilling, completion and production'of the Trading Bay Unit D-42 well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kugler, Commissioner . .. _ . . : BY ORDER OF THE. COMMISSION . Anchor. _,e Division Production Operations, United States Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 Mr. Lonnie Smith State Of Alaska Oil and Gas Conservation Comission 3001 Porcupine Dr. Anchorage, AK 99504 Dear Mr. Smith, Attached are three plots of our proposed well path for TBU D-42. Although only a plot with a 1" = 100' scale was requested, I also included a 1" = 20' plot and a 1" = 500' plot. The additional plots should clarify our plans on TBU D-42. I have also attached a revised schematic of the diverter system we will use on D-42. The changes reflect our intention to comply with current state regulations for diverters. Sincerely, T. B. Arnold Dril ling Engineer TBA'sl -7-:---:-1 1 ': i i - i . 1 '' ' + .............~--: ....... = .... ~ ............ :.:-:-~4--- ~095- -'-~ ~ - ] ' ~ ...... , .. ~ . . ~ .... - I ~-~L ........... ~ ..... ~ ' ~ _: _ ~ . [ : ~ ~ , ~ ',- 1596 ~ i , ' ~-- ' :--7:551 ......~ - - ' ' ' :' '/:7:':::' ............. I ......... ~ .... i ...... :-4 __ ~1399--~ - , ..... :.__. .... ~ _ ~ .... :_, ]_. :_.~--:.2::.2::-.:]. i ..... ~ .... ~ .........~-~ -.. _ i , . i 1186 .. _ 1282 . . ' - i :!654 I ;395 - - . .- I ;!4-1_ ........ : "" ....... 289 , '''' } : i-:-,..-:-:: I'.':;::-: ':':. J-: J ............... t ~ ...... ~"- -~i98 ....: .............i .... .................,_:._ ........ ....... I T : ........... { .. ...... ~ ...... ~s~ Xi.X ~' ~ "7:.X '~g,O ' ~rs': I ................ ~ . .... ~ ...... '--:'~_i. ' ......... ~ ......... 7515 '099 9932 ....... 8480' : 5164 .. 5996 15322 45837 8165 .... /6783 !'6608 6306 5 _ 4829 4485 / 4,119 3975 342:3 6681 ~4095 8645 ~6667 . 5541 % - 3774 _ 3653 5764 . 4910 ................... 19 12 111 44 4620 3292 4118 979 2687 3966 311 5 -3393 3968 7987 . . 8883 61 2694 .. --321 6 4.1 05 5008 5929 6872 - ; ' 836 .. Union Oil and Gas Di on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager March 16, 1983 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Rorcupine Drive Anchorage, Alaska 99504 WEST FORELAND AREA State of Alaska HcArthur River Field Trading Bay Unit D-42 ADL-18729, (8-86-71-5575-601351) Dear Mr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill D-42. Also enclosed is our Check No. 19231 in the amount of $100.00 to cover the required filing fees. Upon approval of same, we would appreciate a copy so that we may complete our files. Very truly yours, Landman sk Enclosures · . cc: O. R. Callender A. Lannin-O & G RaSadena ALASKA STATE OF ALASKA L AND. GAS CONSERVATION C ,1MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. N~me of operator DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT Oil E~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] Union Oil Company of California * 3. Address P.O. Box 6247 Anchoraqe AK 99502 4. Location of well at surface 749' FSL, 1135' FWL, Sec 6-8N-13W-SM · Leg A-2 Cond #7, Dolly Varden Platform At top of proposed producing interval 1800' FSL, 3500' FWL, SeC. 32-9N-13W-SM At total depth 2134' FSL, 4151' FWL, Sec. 32-9N-13W-SM 5. Elevation in feet (indicate KB, DF etC.) I 6. Lease designation and serial no. 106' KB above MSL I ADL-18729 12. Bond information (see 20 AAC 25.025) Type Blanket Drilling Surety and/or number B-2-165-724-1 9. Unit or lease name Trading Bay Unit 10. Well number D-42 11. Field and pool McArthur River Field Amount $200,000.00 15. Distance to nearest drilling or completed wel~ D-28 1200 ' feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 21 mil'es NW of Kenaimiles 5400' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 13275' MD 9957 ! 'TVD feet ' 3085 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 44 O l (see 20 AAC 25.035 (c) (2) 21 18. Approximate spud date March 31, 1983 ~RqR psig@ Surface 341 ~ psig@.9~ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole 17 1/; 12 8 1/: Casing !13 3/( : 9 5/( 9 5/~ Weight 68 47 47 7 29 22. Describe proposed program: CASING AND LINER Grade I Couplingl K-55 IButt J N-80 IButt I P-110 IButt I N-80 IButt I Length 3000' 9890 ' 2110! 1775' SETTING DEPTH MD TOP TVD Surfac~ 0 Surfac~ 0 9890 ,7523' 11500,~ ~8681' MD BOTTOM TVD 3000' ~ 2567' 9890' 7523' 12000'1 9042' 13275'1 9957' I I QUANTITY OF CEMENT (include stage data) 2500 sx cl G 3000 Sx cl G Stages 400 sx cl G Well D-42 Drilling Program 1. Kill, plug and abandon D-23 as reported in S_~nd~b_tice_._ ~tQ__ _Abandon./: 2. Drill 17 1/2" hole to + 3000'. Run and cmt 13 3/8" csg. 3. Drill 12 1/4" hole to T 12,000'. Run open hole logs. Run and cmt 9 5/8" csg. 4. Df. ill 8 1/2" hole to + 13,275'. Run open hole logs. Run and ~t 7" liner. 5. Complete the well as a Hemlock producer, i~ ~'~-~' , · * ~rathon Oil CompanY - Sub-operator / 23. I hereby certify that the foregoing is true and correct to the be~ of m~ kDC/wledge SIGNED~ %- ~ , ~ TITLE The space belb"v~-f~r Comm,ss~on use, R..~ Artder s orr .! CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required ~YES ¢~NO E]YES ,~NO ~'-,Y ES []NO Permit number Form 10-401 . Approval date number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE April 8, 1983 by order of the Commission Submit in triplicate S--J I I2,EO0 VD I0,177 io i, io TC . , \ D-4 D-25 TD 11.510 vo 9906 TI) 12,100 VO 10.014 S-J ~ MARATHON OIL COMPANY TRADING BAY UNIT N'cARTHUR Rr,,'ER FIELD STRUCTURE CC:4TCLJ~ *,tAP TOP HEMLOCK,.,_,,.,,nc.~'r" I' CONTOUR ,,'4T£RvAL · i~' -C _) -~ ....... , .... MARATHON C COMPANY " ............... ~:' :; '-Z _-_-.'~c_-;;' :. ' :_-_'-:", DOLLY VARDEN PLATFORM ............ .......... ~ ................... .............. ' ............... -'' ........... '" ........ :.TBU _WELL_'_ED.--_4?' '-~:~ ........... ~ ................ ~ ....... ........ ":- ...... i .......................... ~ ................ : ............................ - --I ........... ! ......... ~ ................. !-: ........ : -: .................... - . ? ......... ~. ......... ; ........... ; ......... . ........ ........ ~. .................. ~ ........... ,., ............. ...... ;- ................... t ................ ,~ ................. ................. - ....... ! ...................... i ................... t---: .................. ............... ~- ............................. ' ............ -.- 3500" - '-'; '-'~ARGET ...................... i--'---: ....... '- ...... r ................. ~' ............................ ~ .............. ! .......... : ........ 4 ........................ t ................................ $1 ~ .... T 9 N ............. ii: i;::;:'-~ ..... ' t ................... t .............. ~ ......................... - ...................... ...... , t~ ........... t ............. f ............................................... .......... .t- ................. t ................... f ................... ; ........................... · . . ...... ~. ................. j. ................ ~_; .............. ~ ................................ ................. ~ ............. ~ .............................. -~ ............... · ........ " "" ~: ~: ..... r'J ......... · . SURFACE .................... : .................... ',:1' to ..... ......... KOP ........... ,_ ................ n,- n:: : . ........... 0 TVD: 500 ............. ;. ............................................... .................. TMD = 500 .................. f .............. ? ...................................... ...... OEP:O .............. i .................................. ....... \ --:-: ; ................. ? .......................... ..__, .... , ............... ............. ,~, .... I_~ ........... +-_,~ ....... i. ............ : I1,~,~ ............................. " '. :. ,.,-.'~',~o ~.,oo': !:::-:::::----.::;..:-::-:-4--:-::::: '.:-'.. -,,,s?-~--"Af~..-:..:;; :.:.-:.;:-':'--:-:.. · ~ooo. .~. :L:__';L;;:;i_'.ET:;:-::::i:-_:-;.;'::-::_:','_':LJ_;-:::: , ,'" ~ ':i .......... ::"' .... \ ...... '; ................ : ...................... i-- ..... - ..... .... :_:_:_-': :-::':._.: .... :_..-..-.:::-: _. -.-: _.-- ~- -_ _~_ ~ -~- ............ ~N.~. ................................... i ....................... ~ ............. t ........... ..~_~___:__:_~-'_..~' :_:_~;_.:~ ...... :~ i__::.::-~:.:_i ~': ;'_ :._:; ..... :... :..:. :..-.: .... ;'....---.'~::_:_:.;_~_.-~::~:.~. :-= ~oo. ' ;-:;_'-_:;-;::';L~_E_-_L:.? ';.':.~:::';:;-"?:_'_L;'::':'~:_ :j.~:-':._-.-:..:; ;:':::.' :: :.':::~: :.;;":.-.'--:-: · ~ :'_ !.--; .-_:-_;_--__-_----_--;:- ~__:.. ' ';::7.:.;_:...i.:;_-_-_.:_.: ':"::'-: :_-.: ~,.' ';-.;:;: :.; ':..~. :.:..: .';.:':::: :.:_'.-_.-7-:: C) .................... ; .............................. ~ ................... + ............... ~ 6~. L ........... i ...... . i ' 'i;'';. ;.'~"-~,L_".'i.'..L--~'~'_;: ~ ; .....~-~ ............. \ ............................................. ; ............... ~ ......... --4-' ' ' - ' ~-i- ........................ : ................. ~ ........ i ............. 4- ....... . .L ,--;-_,---;--- ......... i ......................... ; ....................................................... -.'----~----~- . ,_ ..................... .............. ........... ~ ................................................. ;. -~. - -- ...... t .......... \ . - ! .................. i ......... i ......................... _,. _~ ........ ! ..... ~...\ ._ + ................ ~ ..................... ~ ..................... , : ~~ ......... \ ' --: ......... ~ .............. t .................... :_~:L: '_:: :.::_: :_ i~:.:: :._:~::_:_.:_.:_-i.:~'::.:-_::_-~.:;::.:-.'N~ :-:~_:_.:_.::: _: :-:-J;:::~-:--::-::::;::~:;--:'I:-:-:-'-:-::'-:-;:--:--: :-'-::--:-:-::-.:--: :--: · -~'"~'-~ ............... \ ......... ' ...................... t .................... :' .............. : : :--:-: : :i . i_.~ ......... · :.;."~ '*TARGET TVD=9200 · ! .......................... · ; ~~---~ ---~ .... : DEP='7621-;--I ............ ' ............. ...... ~ ~~,, ,~ ~ !~ ....... \. , .... ! .................. IO, Ooo ; i ~ '..~. i i i i_~ ...... ; . ."rD. TVD= g57 i i . ' . i. ', .................... ............ i ............ TMD= 1:~,275 .............. : ......... ? ' ' DEP~ 8353 "-T- ..... ~--I .... T-', ......... i ................ :'i ..... :_ "- DEPARTURE ' I 8000 -MARATHON " OIL GO.. -- DOLLY VARDEN! PLATFORM - · . U // - Flowline Drillin9 Ilippl¢ -- Diogr~m ~ _Riser ttacd Before Preventer (20" ~ 2,o00~ I-i.y. dril ,) 'x C. Io~p-oh Hub £ocZ) MARATH O'[L GO.- - DOLLY VARDEN PLATFORM -- ON Mucl D~n b Drillinq~ Mippl~ U Pr~v~nf~r ~ i5~/~'' Doubl~-Gatc- CIW ]5"~ 5,000~- Kill Lin~ D~ill Deck Floor . I ~ / C°nneat°rs Clamp -- Di~rn~ 2_- 15s/8"x 5,000~ Riser ¢_ BOP £fack For Drillin~~ From Uhd~r 15~/6'~ 5ur~ae O~sin9 To ~D.-- o 2. Ff. Spool ~.. ,~ ;:-*i,,,-,~,,-.~.- .7~ -- Well Room Floor [oo C. oilar' 13 z/6" Surface O~sin8 33" C~onduator o o Ci~mp C_o ~nec-}ae o o ...... _ . . .......... · · , -MARATHON OIL GO.. U / / Flowline Drill/n@ N" X 2~000'~ V~v~- Hippie Preventer (20" ,, 2,ooo'* H.ydril ) _Riser ~scd B~fo~e Set- 4ih~ !~ ~/a'' Surf~cc Ca~ing--~ _1 · . Wt..it Roo~ Floor- N N Ola~np- o~ Hub ~3" Oonducfor CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No ....... t)> ~'"i~ ..... ITEM APPROVE DATE .//(2 ,~hru 8) , lo me 3, 4. 5. 6. 7. 8. (3) Admin ~-'~ %"~ ~"~.'] 9. ,~/::) thru 11) 10. · 11. (4) Casg ~,,,.~ ~-~-$~ 12. (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. (5) (21 thru 24) 21. 22. 23. 24. (6) Add,,:~ff ,Y'~-Z~: 25. YES NO REMARKS Is the permit fee attached · f,"l~$~ ®o®®®®®eo®®®®oo®oe®eoee®o®®eeeeoo®oooooo®®.. "~" Is well to be located in a defined pool ............................. Is well located proper distance from property line ................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ................ Is operator the only affected party Can permit be approved before ten-day wait ............. .............. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ...... .................................. Is enough cement used to cirCulate on conductor and 'surface ......... Will cement tie in sUrface and intermediate or 'produCtion strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating- Test to .~OOo Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. ~ Geology: Engin,e_er ing: 'er: 12/06/82 INITIAL GEO. UNIT J 0N,/O~ POOL ,., CLASS STATUS AREA NO. ,-,! SHORE .,~i / "' t 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 APPENDIXl .. No Special'effort has been made to chronologically organize this category of information. C~pany CU:VL _c?£ZiTICATZ ~'~ MARATHON OIL COMPANY I£11 TBU D-42 Composite Mcz:2RTHUR RIVER ?/11/~S, State KENAI, ALASKA Date 8/25/83 (Akkrev.). ~.Ctan~--~,.,~... Curve Name Le:s Used Scale RFOC j Resistivity Focused iDIFL , RI~,I ! Resistivity Medium DIFL RILD [ Resisti~zity Deep iDIFL j Gamma Ray, IDIFL .2 ? 2000 Spontaneous Potential (2990'-10490')iDIFL-BHC/AC · .2 - 2000 .2 - 2000 GR2 (10490'-12830') 0-100, 100-200 SP1 j Spontaneous ,- , Potential (10490 -12830')iDIFL 0-100 SP2 -100 - 1.00 GR! Gamma Ray 0-100, !00-200 Spontaneous Potential Gamma Ray . . Acoustic ' (1990'_10490')IDIFL-BHC/AC CD/CN-CDL SP (10490'-12830')IBHC/AC GR .(10490'-12830') AC BHC/AC-CDL-CD/CN IBHC/AC Density I cDL Correction i' CDL DEN CORR CN Compensated Neutron ICD/CN jCD/CN Density Porosity Caliper tCDL-CD/CN iCDL-CD/CN DENP CAL CALl Caliper 0-100 0-100, 100-200 150 - 5O 2 - 3 60 - 0 60 - 0 10-20, 20-30 6-16, 16-26 · .. ..':~'-~ -_, ~"'~' . ~--.~~ ........................................ ..... ~: .... ~ :.~:~.,; · _ .-.~..~:~:.:_:__.. ~.~ ::. -_ : .... ~'~..;d -~ '" - ..................................... ~~ ---x ~~,_ ....... .: - .. ;::'x..:-z ..::."~';'::.;. :"". · '. :.:'".': :-..":'../..C ~ ~'. . - . _ ~~~.. _ _ ._ ---__.....-- _ ._.._ .~-. ~ -~ ~'~ . - -. :. :....~ ..... ..: _:.:-: .. '-- -- ~~-~ :- ~.. _ .;:~.': _:.: :-.... ~ _ - '~'~~ :. . - .~- ...~: ~.~'-.. % - _.. "- .: ....... - _ . . ~. . -~ ~~_ - - . ~.. -. :.~_....~'._ ...~}..~_-......_;.......-. '. '..:.- -: - -- __ __ . .... . _~~- ~-. --__:: :..': .~ ... - .. 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