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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from casey.morse@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Cc:Brooks, Phoebe L (OGC) Subject:FW: Dolly D-41 (PTD #1790830) AIO 5.021 Compliance Temp Survey February 2024 Date:Tuesday, February 27, 2024 10:05:27 AM Attachments:D-41 AA - AIO 5-21 - 2016-02-02.pdf D-41 - 2024-02-25 - Temp Survey Plot.pdf From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, February 26, 2024 4:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Dolly D-41 (PTD #1790830) AIO 5.021 Compliance Temp Survey February 2024 Mr. Wallace, Well D-41 (PTD 1790830) was granted a return to injection under Administrative Approval (AIO 5.021) on February 2, 2016. As required under the approval (Rule 3), a biennial temperature survey was run on 2/25/2024. The survey (see attached) is consistent with the last survey run on 1/21/2022. As this new temperature survey is consistent with the previous surveys, it confirms that all the injected fluids are being contained in the approved strata. Please contact me if you have any questions or require additional information. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: Field:02/25/2024Hilcorp D-41 Dolly Varden 40 60 80 100 120 140 160 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Temperature (Deg. F) De p t h - M D , ( f e e t ) Pressure (psia) Pressure 24 Perfs 13-3/8"9-5/8" 7"TBG PKR Press 22 Press 20 Temperature 24 Temp 22 Temp 20 Pressure-Temperature Profile 1. RIH 2020 - 2022 - 2024 2. Static Report date: 2/26/2024 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored); Brooks, Phoebe L (OGC) Subject:FW: Dolly D-41 (PTD #1790830) AIO 5.021 Compliance Temp Survey January-2022 Date:Monday, January 31, 2022 10:33:43 AM Attachments:D-41 AA - AIO 5-21 - 2016-02-02.pdf D-41 - 2022-01-21 - Temp Survey Plot.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Thursday, January 27, 2022 12:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Dolly D-41 (PTD #1790830) AIO 5.021 Compliance Temp Survey January-2022 Mr Wallace, Well D-41 (PTD 1790830) was granted a return to injection under Administrative Approval (AIO 5.021) on February 2, 2016 (AA anniversary date is 1/25/2016). As required under the approval (Rule 3), a biennial temperature survey was run on 1/21/2022. The survey (see attached) is consistent with the last survey run on 3/27/2020. As this new temperature survey is consistent with the previous surveys, it confirms that all the injected fluids are being contained in the approved strata.. Let me know if you have any questions or require additional information. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: Field:01/21/2022Hilcorp D-41 Dolly Varden 40 60 80 100 120 140 160 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Temperature (Deg. F)Depth-MD, (feet)Pressure (psia) Pressure 22 Perfs 13-3/8"9-5/8" 7"TBG PKR 1-18Press 3-20 Press Temperature 22 1-18 Temp 3-20 Temp Pressure-Temperature Profile 1. 1/19/18 - 03/27/2020 - 01/21/2022 2. Static Report date: 1/27/2022 _____________________________________________________________________________________ Updated By: JLL 01/07/16 SCHEMATIC McArthur River Field Well: D-41 Last Completed: 12/02/1990 PTD: 179-083 API: 50-733-20331-00 Top (MD) Btm (MD) Top (TVD) Btm (TVD) 10,932’ 10,992’ HOWCO Steel liner casing patch (Nov 1990) 11,024’ 11,994’ HOWCO Steel liner casing patch (Nov 1990) CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 68# K-55 Butt Surf 2,994’ 9-5/8” 43.5# N-80 Butt Surf 6193’ 9-5/8” 47# N-80 Butt 6,193’ 8,616’ 9-5/8” 47# P-110 Butt 8,616’ 10,734’ 7” 29# N-80 Butt 10,536’ 11,728’ TUBING DETAIL 3-1/2” 9.3# N-80 DSS-HTC (TK-69) Surf 10,795’ JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 41’ 41’ CIW DCB-FBB Tubing Hanger. 410 stainless steel treated to NACE MR-01-75, 3.5” 8RD EUE x 3.5” DSS-HTC bottom 305’ 305’ 2.88” Otis Flow Coupling 310’ 310’ 2.813” Otis X Nipple – Baker XJ Injection Safety Valve w/ 53/64” Port and equalizing sub installed in X-Nipple 311’ 311’ 2.88” Otis Flow Coupling 10,729’ 9,147’ Otis HCM Packer, IPC, w/’SAP’ Seal Anchor Assembly 10,735’ 9,152’ Mill Out Extension 10,742’ 9,157’ X-Over 4” VAM Box x 2-1/2” DSS-HTX, IPC 10,751’ 9,165’ 2.813” Otis X-Nipple 10,787’ 9,194’ 2.75” Otis XN-Nipple 10,794’ 9,200’ Otis Ball Catcher Sub w/ WLEG Notes 11,475’ 08/28/15 - 2.25” DD Bailer tagged up 11,490’ 08/22/07 - 2.50” GR tagged up 11,603’ Old isolation packer PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status HK 1 10,882' 10,914' 9,271' 9,296' 32' Open HK 2 10,938' 10,988' 9,316' 9,356' 50' Nov-90 Cmt Szq'd HK 2 11,000' 11,020' 9,366' 9,382' 20' Nov-90 Cmt Szq'd HK 3 11,066' 11,111' 9,419' 9,456' 45' Nov-90 Open HK 4 11,138' 11,296' 9,478' 9,606' 158' Nov-90 Open HK 5 11,314' 11,430' 9,620' 9,715' 116' Nov-90 Open Wallace, Chris D (CED) From: Julie Wellman - (C) <Julie.Wellman@hilcorp.com> Sent: Friday, November 27, 2020 4:34 PM To: Wallace, Chris D (CED) Subject: Dolly D-41 (PTD #179083) AlO 5.021 Compliance Temp Survey March 2020 Attachments: D-41 Temp survey 3-27-2020 vs 1-19-18.xls Hello Chris, Well D-41 (PTD 1790830) was granted a return to injection under Administrative Approval (AlO 5.021) on February 2, 2016. As required under the approval, a biennial temperature survey was run on 3-27-2020, slightly delayed for weather. Due to recent personnel changes and COVID office shut downs, the reporting of this compliance temp survey was overlooked. The survey (see attached) is consistent with the last survey run on 1-19-18. As this new temp survey compares very favorably with the temp survey from two years ago, it confirms that all the injected fluids are being contained in the approved strata. We are requesting that this satisfies Rule 3 of AlO 5.021. Thank you, Julie Wellman Regulatory Tech — Hilcorp Alaska, LLC o: 777-8505 1 c: 360-265-4397 Julie.WellmanAhilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PT1> 1-710930 Hilcorp Well: D-41 Field: Dolly Varden 03/27/2020 1000 2000 3000 4000 5000 6000 CL fl. 0 7000 8000 9000 10000 11000 12000 40 50 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) —Pressure — Perfs 13-3/8" 9-5/8" 7" -�-- • TBG PKR --- Temperature 1-18 Ter Report date: 11/30/2020 • • P'l) I/90 B30 Hilcorp Alaska,LLC I Well: D-41 Field:IDolly Varden 101/25/2016 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 0 1000 Pressure-Temperature Profile RIH 01/15 vs 01/25 Overlay 2. Static 2000 3000 - 4000 — • 5000 r • a, = - l0 6000 2 t CD 7000 CI 8000 F 9000 10000 a 116x 11000 12000 I I I I I 50 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) i 1 6‘i- 1-25-16 Pressure — Perfs 13-3/8" 9-5/8" 7" —TBG PKR 1-25-16 Temp 1-15-16 Temp Report date:9/20/2016 • • -5-7-;t1X6-4 PP ►7' 0630 Regg, James B (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, December 30, 2015 12:56 PM To: Regg, James B (DOA); Larry Greenstein ���� f Z�30i,s Cc: Wallace, Chris D (DOA);Juanita Lovett Subject: RE: Possible Dolly Varden D-41 tubing/casing integrity loss (PTD#179083) Attachments: D-41 Weekly Operations Summary - 12-23-15 to 12-29-15.xlsx Jim, See attached weekly update for D-41 diagnostics Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com OE scik Hilcorp A Company Built on Energy From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: December 28, 2015 10:37 AM To: Larry Greenstein Cc: Wallace, Chris D (DOA) Subject: RE: Possible Dolly Varden D-41 tubing/ casing integrity loss (PTD #1790 Hilcorp is granted the requested 30 day window to complete diagnostics. ".GCC requests weekly updates of Hilcorp's diagnostics.This approval expires January 28, 2016. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message ncluding any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is •r the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosu .. of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or orwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. 1 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-41 N/A 50-733-20331-00 179-083 12/29/15 Future Daily Operations: 12/23/2015 -Wednesday 12/24/2015 -Thursday 12/25/2015 - Friday 12/26/2015 -Saturday 12/27/2015 -Sunday 12/28/2015 - Monday 12/29/2015 -Tuesday All is okay on the wellhead, no internal seal leaks going on for the wellhead to cause the increase in the 9 5/8 casing pressure. Tubing hanger void (3 Y2 x 9 5/8): Bled void off, good oil in void, no water. Pressure test tubing hanger to 250/5000psi for 15 min each. Test good. Casing hanger void ( 9 5/8 x 13 3/8): Bled void off, good oil in void, no water. f Pressure test void to 250/2500psi for 15 min each. Test good. • . t le--t�. PT1N v7q0v3c Regg, James B (DOA) From: Regg, James B (DOA) `1 z fr9l is Sent: Monday, December 28, 2015 10:37 AM To: 'Larry Greenstein' Cc: Wallace, Chris D (DOA) Subject: RE: Possible Dolly Varden D-41 tubing/casing integrity loss (PTD#179083) Hilcorp is granted the requested 30 day window to complete diagnostics. AOGCC requests weekly updates of Hilcorp's diagnostics. This approval expires January 28, 2016. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 sci0 01 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Thursday, December 24, 2015 12:34 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: Possible Dolly Varden D-41 tubing / casing integrity loss (PTD #179083) You got it Jim A lot depends on what we find out as we proceed through the different testing. First, we'd probably try a standard pressure test type MIT to verify the existence and the `size/speed' of the communication. This will be done initially with the well still shut-in, but depending on what we find, we may want to bring the well on to get the thermal effects stabilized before doing that again. Next we'd look for bleed down responses again to verify the size/speed of the communication and to determine if it's a one way leak or two way (ie past the packer one way, but holds pressure the other way, for instance). Depending on the results of those tests, we'd be looking at temperature surveys to see where the water is exiting the tubing/casing. That step would require a baseline survey as well as a stable downhole_thermal profile. This would require a week or two of injection to make sure thermal stability is achieved. Hopefully we already have a baseline, but if not, that requires some downtime to get a good survey. The intent of all this diagnostics is to first verify whether we have communication or not and then to determine if the well still has a proven single barrier(which may include a low pressure MIT of the OA) as the basis for requesting an Admin Approval for continued injection. In the meantime, we'll be seeing what next year's budget looks like and, if the well has an integrity failure, whether it can be feathered into the work scope for next year. So depending on weather and vendor availability over this holiday season, it might not take very long to confirm all this, or it may take a little while. Hence the request for a one month window to accomplish all the testing required. 1 • • Does this help explain the possibilities our plan better?? Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, December 24, 2015 11:10 AM To: Larry Greenstein Cc: Wallace, Chris D (DOA) Subject: RE: Possible Dolly Varden D-41 tubing / casing integrity loss (PTD #179083) Need more definitive diagnostics plan than "could include..." before addressing the temp injection request: - What pressure tests and when - Timing for temp survey Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] Sent: Thursday, December 24, 2015 9:45 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Subject: Possible Dolly Varden D-41 tubing / casing integrity loss (PTD #179083) Hi Chris &Jim, Please be aware we shut-in the Dolly Varden 0-41 waterflood well last night due to a possible tbg/IA integrity loss. Attached is the well schematic and a 90 day TIO plot showing no previous indications of an integrity problem with this well. Hilcorp is requesting temporary approval to restart water injection in this well for up to one month to perform diagnostic tests which could include pressure tests, bleed downs, temp surveys, etc. As we learn more about the possible integrity problem, we will report back to AOGCC with our findings and propose a plan forward for this well. Thank you Larry 2 • PrL I , Regg, James B (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday, December 24, 2015 9:45 AM 1Z'7-4(1S To: Wallace, Chris D (DOA); Regg, James B (DOA) Subject: Possible Dolly Varden D-41 tubing /casing integrity loss (PTD #179083) Attachments: D-41 Schematic.xlsx; D-41 90 day TIO plot.xlsx Hi Chris &Jim, Please be aware we shut-in the Dolly Varden D-41 waterflood well last night due to a possible tbg/IA integrity loss. Attached is the well schematic and a 90 day TIO plot showing no previous indications of an integrity problem with this well. Hilcorp is requesting temporary approval to restart water injection in this well for up to one month to perform diagnostic tests which could include pressure tests, bleed downs,temp surveys, etc. As we learn more about the possible integrity problem, we will report back to AOGCC with our findings and propose a plan forward for this well. Thank you Larry �Ea EP 2 Q 216 • 0 r O O O O O O 'L 1 O O O O O O ; O O O O O 0 O 'Cf M N I 0 i:;:b' N .0i Ilr---------------- n -401 N 0_ 111L Lan 4.114.1......m. C L Y al O Q WI O u •.4 soo I • G CO 01 C .L] N LA O N O )S'111'. i il i i f VI i N CP O O O O O it O O O to O to O LA M N N .--I ^1 -LIStdd S • McArthur River Field,TBU SCHEMATIC Well: D-41 iiiic„„Alaska,1.1f. As Completed: 12/2/90 CASING DETAIL All measurements are RKB to top of Size Wt Grade Conn ID Top Btm Cmnt equipment. 13-3/8" 68 N-80 Butt Surf 2994' p 9-5/8" 43.5&47 N-80,P-110 Butt Surf 10734' T . 1 7" 29 N-80 Butt 10536' 11728' 2 Iiii 3 Tubing Detail 3-1/2" 9.3 N-80 DSS-HTC Surf 10794' JEWELRY DETAIL No Depth Item 1 305' Otis Flow Coupling(2.88 ID) 2 310' Otis"X"Nipple(2.813 ID) 13-3/2 , „ 3 311' Otis Flow Coupling(2.88 ID) 4 10729' Otis HCM Packer,IPC w/"SAP"Seal Anchor Assembly 5 10735' Mill out extension 9-5/8" 6 10742' X-Over 4"VAM Box x 3-1/2"DSS-HTC,IPC } 7 10751' Otis"X"Nipple(2.813"ID) 8 10787' Otis"XN"Nipple(2.75"ID) 9 10794' Otis Bail Catcher Sub/WL Entry Guide 2:1► PERFORATION DETAIL Zone Top Btm. Amt SPF Date 4 B-1 10882' 10914' 32' 8 Nov-90 1 111110.- 11 51 II 6 B-2 10938' 10988' 50' Cement Sqzd Nov-90 11000' 11020' 20' Cement Sqzd Nov-90 7 S 8 8-3 11066' 11111' 45' 8 Nov-90 9 B-4 11138' 11296' 158' 8 Nov-90 B-5 11314' 11430' 116' 8 Nov-90 B-i B-2 n B-3 B-4 8-5 *131 ;,,,,„,,.,,,,,,n,7 J,,,5 ,a rt 0. .2744, 8 '------------c Plug Back Depth=11,642' TD=11,735' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggj� -7/ rl 2Z/14 DATE: Monday, July 21, 2014 P.I. Supervisor \�% j SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC D-41 FROM: Johnnie Hill TRADING BAY UNIT D-41 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT D-41 API Well Number 50-733-20331-00-00 Inspector Name: Johnnie Hill Inap Num: mitJWH140614093207 Permit Number: 179-083-0 Inspection Date: 6/3/2014 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i -- D 41 w Test s� 46 0 Type Inl 1TVD 91ab - IA U 2490 2490 - 2490 - 2490 PTD 179os3oType Test' sPT p 2286 .1 OA soo „ soo . r soo soo soo Interval I4YRTST p/F P Tubing 3100 - 3100 3100 -3100 3100 - Notes: SCANNED O C T 13 2 n 14 Monday, July 21, 2014 Page I of I MEMORANDUM To: Jim Regg P.I. Supervisor ~F~f ~ ~lZ~()a >±Ito1vl: Chuck Scheve Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Friday, June 18, 2010 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-41 TRADING BAY UNIT D-41 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~-~- Comm Well Name: TRADING BAY UNIT D-41 Insp Num: mitCS100618084934 Rel Insp Num: API Well Number: 50-733-20331-00-00 Inspector Name: Chuck Scheve Permit Number: 179-083-0 Inspection Date: 6/10/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-41 ~Typ ne ~ ~ W ~ V p.T.D! 17908 Type~I'8St SPT Test psi --1--- ~ 9146 2286 IA 190 OA 150 2370 23s0 I50 1s0 23s0 150 Interval aYRTST p~F r - Tubing ~ 2soo l - zsoo_~zsoo ~ 2soo -- ! - - NOtes: pre-test pressures were observed and found stable. ~ ~~,.~~` ,.f~,iL r_ ~~ 2~jC Friday, June 18, 2010 Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical integrity Test Email to:jim.regg@alaska.gov; phcebe.brooks~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhce.bay@alaska.gov OPERATOR:. FIELD !UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Union Oil Company of California. McArthur Rjver Field / TBU /Dolly Platform 08/10/10 Jason Sulley Chuck Scheve Packer Depth Pretest initial 15 Min. 30 Min. Well D-29RD T pe Inj. W TVD 8,460' T ~ 2,475 2,450 2,450 2,450 Interval 4 P:T:D. 1850030 Ty test P Test 2115 Casi 80 2,240 2,230 2;230 P/F P Notes: OA 160 160 160 160 Well. D-34A Ty Inj. W TVD 9,164' Tubing 2,400 2,400. 2,400. 2,400. Interval 4 P.T.D. 1790110 Type test P Test psi 2291 Casing 100 2,3.90 2,370 2,370 P/F P Notes: OA 15 15 15 15 13-41 Type h~j: W TVD 9,146' Tubing 2,500 2,500 2,500. 2,500 Interval 4 P.T.D. 1790830 T pe test P Test psi 2287 190 2,3703 2,3'50 2,350 P/F P Notes: OA 150 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE 1NJ Codes D =Drilling Waste G=Gas 1 =.industrial Wastewater N =Not Injecting W = Water T1fPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D = Differential Temperature Test 1NTE32VAl_ Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~~ ~ ~~'- MIT Report Form Revised: 06/19/02 MIT Dolly_Varden 06-10-10.~ds ra~1r ~ Ui ~ 1 Ma~~d~C, has E {DQ~1) _. _ _ . -From: Martin, J. Nal jHaLMartin@chevron.com] Sent: Wednesday, June D2, 2D10 4:D8 P11A To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Agler, Brit G; Loomis, Jon M; Ande n, ChristyU Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 &~ D-41 ~ O Tom \~~ As we discussed earlier today and to continue the thread below... The Dolly waterflood injection was shut-in in April 2009 due to surface piping issues. On 5/26/10, waterflood injection on the Dolly was restarted. We are monitoring all injectors as before the shut-in. Three wells (D-29RD, D-34A, and D-41 -see below) were due for their state witnessed 4-year Standard MIT test in November 2009, but were deferred since waterflood was down per AOGCC preference. Injection in these wells was restarted on 5/26/10 as well and appear to still have integrity. As we discussed, the Dolly folks will schedule to have a state representative come out next week and witness the MIT test on these three wells. Question -Will the 4-year MIT clock be reset as of Tune 2010 or will it be from November 2009? Let me know your thoughts and if you have any questions. Thanx, Hal From: Regg, James B (DOA) ~mailto:jim.regg~a alaska.goV] Sent: Friday, February 05, 2010 9:27 AM To: Martin, ]. Hal Subject: RE: State witnessed MIT on Dolly Varden D 29, D 34 & D-41 Sorry to bother you about this; should have checked our well files before sending message based solely on a query of our MIT database for tests due. The correspondence was in our well files. No change to plan as stated previously - we will continue to monitor and defer MITs until wells put on injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 AnCtweage, AK X591 907-793-1236 -_ _. From: Martin, J. -Hal jmailto:HaLMartin@chevron.com] Sent: Thursday, February 04, 2010 4:3b PM 6/11 /2010 Page I Regg, James B (DOA) From: Martin, J. Hal [Hal.Martin@chevron.com] 4111 I ce( - Sent: Tuesday, November 24, 2009 10:20 AM �G�G To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Aubert, Winton G (DOA); Greenstein, Larry P; Lee, John R; Anderson, Christy D Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 1-7 Jim, Thanks for the reply. D-29RD and D-41 are shut-in and will remain so until waterflood injection is restored. D-34A has been on nominal effluent injection (generally less than 100 BFPD) over the last 2.5 weeks due to a rig workover that is now complete, but is now shut-in and will remain so until waterflood injection is restored. These wells will be put in the monthly waivered injection well report. Thanx, Hal From: Regg, James B (DOA) [mailto:j im.regg@alaska.gov] jl F fa 3 ZoQ Sent: Tuesday, November 24, 2009 9:43 AM To: Martin, J. Hal Cc: Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 If shut in (zero injection), we will wait until wells are put back on injection to witness the MIT. In the meantime, the wells (D-29RD, D-34A, and D-41) should be included in the monthly waivered injection well report until put on injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto: Hal. Martin@chevron.com] Sent: Wednesday, November 11, 2009 1:13 PM To: Regg, James B (DOA) Cc: Anderson, Christy D; Greenstein, Larry P; Lee, John R Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Jim, A point of clarification that I need to make and then also understand from you. You mentioned below that you would have an inspector contact the platform about 1 1/24/2009 • Page 2.of� conducting the MITs. I want to make sure you know that these wells are now shut -in and have been since mid - October. Since I thought you preferred having the wells on injection and stable before conducting the standard MIT test, let me know if you want to wait until injection is restored (sometime next year) or if you want to conduct an MIT test. Thanx, Hal From: Martin, J. Hal Sent: Wednesday, November 04, 2009 11:53 AM To: 'Regg, James B (DOA)' Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & D -41 Jim, Thanks for the reply. Sorry about misreading your e-mail concerning the issue about conducting an MIT following the "shut -in ". Now that I look back at it I see where you were coming from. I've got a few other issues I'm dealing with at the moment, but maybe next week sometime I'd like to give you a call and discuss a couple of the regulations that I'm not clear on and the scheduling of MITs for mutual benefit and the impact on the due dates. Thanx, Hal f From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, November 04, 2009 10:06 AM To: Martin, J. Hal Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D reenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & -41 Thank you for clarifying that these wells are not shut in, but j t isolated from the injection pumps and are still connected to the treated effluent system, and that small v me injection is continuing. You are correct that our preference is to witness the MIT while on injection; we i normally only deviate from that practice when it cannot be avoided. I will have an inspector contact the platform about witnessing MITs on these 3 wells. TBU D -29RD (PTD 1850030) j / TBU D -34A (PTD 1790110) TBU D -41 (PTD 1790830) I did not suggest that you perform the MIT "prior to the volcanic eruption ". What I said in my email note was that - based on our injection records - -Union had opportunity to perform the MITs in September or October. That statement appears to be consistent with the clarification provided. The variance I refer to is not related to loss of well integrity. It enters the picture when you go beyond the due date for conducting an MIT. Further, my comment was to understand why you would not (could not) test prior to 11/24:2009 • • Page 1 of 4 ~ Regg, James B (DOA) !~~ ~ ~~~ _ . _ _ _ _ _ _ _. l From: Regg, James B (DOA) ~ ,~ ~ -l~ ~~ ~'~~ ~_ ~ ~ ~ ( Sent: Wednesday, November 04, 2009 10:06 AM ~ To: Martin, J. Hal Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Thank you for clarifying that these welis are not shut in, but just isolated from the injection pumps and are still connected to the treated effluent system, and that small volume injection is continuing. You are correct that our preference is to witness the MIT while on injection; we will normally only deviate from that practice when it cannot be avoided. I will have an inspector contact the platform about witnessing MITs on these 3 wells. TBU D-29RD (PTD 1850030) T -34A TD 1790110) ~ TBU D-41 (PTD 179 30 ~did not suggest that you perform the MIT "prior to the volcanic eruption". What I said in my email note was that - based on our injection records - Union had opportunity ta perform the MITs in September or October. That statement appears to be consistent with the clarification provided. The variance I refer to is not related to loss of well integrity. It enters the picture when you go beyond the due date for conducting an MIT. Further, my comment was to understand why you would not (could not) test prior to shutting in the injectors if you were planning work that would cause the injectors to be SI. Successful testing would restart the compliance clock; in this case, providing another 4 years until the next MIT is due, barring some loss of inechanical integrity. One last observation - the Commission witnessed safety valve system tests on Dolly Varden on 9/4/09; that would have been a good time to do the MITs. There may have been reasons not evident to us that prevented these MITs from being done on 9/4. Please ask your field operators to make an effort in the future to combine tests whenever possible. I hope you can appreciate that taking advantage of opportunities like this ensures we are best using the limited inspection resources we have. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~~~~~~ i~ ~~' ~~~0~~ Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Wednesday, November 04, 2009 8:38 AM To: Regg, ]ames B (DOA) Cc: Bartolowits, Paui D; Noble, Robert C(DOA); Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 ~im, Below is the reply from Christy Anderson on the Dolly as he sent to us by a separate e- mail. 11 /4/2009 ~ • Page 2 of 4 Jim [~!y co~fi~~~i~n an t~rrnit~~olc~~~~ s~ I ~ nisst~t~d that th~y were ~il. Thes~ fit~ir~~ wells ~re isolaf~d firom aur injectior~ p~fm~~s fo, s~rfac~; ~ip~ ~~~~lac~:ment. (This is t~vh}~ I s~,id t!~ey v~~~re shut ir.l ~he ~n~ei(s are stil~ eonnected ta the ~i~in~ `or our trea~~c ~~flu~nt syst~~~ and theref~re stiil s~cv~ that th~y are 2c~ive. Th~y have sr7ov~rn very {ow volurrt~s of ir~j~ct~on ;:~~ring ~i~~ y~~st ~~w rrc~n~l~s ~a~c~use only i"~e tre~tea ~ffiu~i7~ rr~ s~een going to them and nct w~~ter~laod. T~he ~1uck va!°v~s a:~ C~ ~29, C~-34 & I~-4~i v~ter~ ~:r~ut Un 1t~-12-2~J09 routing ~~! tt~e treated ef~luent dovdn D-14RD in pr~p~ra~ic~n fc~r rnor~ pip~ replacem~nt. The M1T c~n s~ill ~~ cion~ on th~s~ ~~~eil's to keep in c~m~lianc~. L~t ~r~~ ~:na~ ~nd ~!ve ~vili set u~ a~~~ to ~~f then~~ dcne. (;~a~~ist~y I.7. i~l~cier=:~~7n I.,E~~cl Ope,r~atar T)c>liti ~~~~z~z:le~1 I'Iat:f~c~~r,~l F'llone 77fi-6810 F~'a:~. 776-~>€32{i In addition, I would like to add the following comments. 1. Christy`s comments point to the fact that during the shut-in period following the volcano Chevron had some internal accounting issues regarding a well's designation of being on/off and the corresponding capture of minimal effluent injection volumes. The monthly reports you have show that the wells were shut-in between April and August, but in actuality small volumes of effluent injection as you observed in September were happening during this time also. For the three wells in question, there was not a long-term shut-in as it appears on the monthly reports. 2. The surface piping repair plan began in AprilJMay of this year. Following the volcano eruption, surface piping inspection was conducted and found spot(s) with thin wall piping. This combined with the significant expenditure constraints placed on us resulted in a plan to do the repair work by reducing the spend, stowing down the time frame and get a good product by having the Dotty production personnel themselves plan/supervise/manage a lot of the work as they are able - it is actually quite a statement about the desire and willingness of the folks out there to find a way to manage their field expense funds and ~~get it done" without a lot of overhead process and cost. 3. There may have been opportunity for us to do MITs prior to the volcanic eruption, but we didn't know about the thin wall sections until we inspected the piping. Besides, the November MIT due date was a long way off and we expected to be back on waterffood injection by then. 4. I am not sure about ~~seeking a variance to the regulations" comment. We were ready to have the integrity of the well's tubing/packer/casing tested and witnessed by the AOGCC during a stable shut-in period which in my mind is similar to a stable injection period. However, since you prefer to conduct the MIT during active injection, we are certainly willing to schedule the tests once the wells have been returned to injection and reach thermal stability. Let me know if you have questions or need additional information. Thanks, Hal Martin 11 /4/2009 ~ . Page 3 of 4 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, October 30, 2009 4:14 PM To: Anderson, Christy D; Greenstein, Larry P Cc: Martin, ]. Hal; Bartolowits, Paul D; Noble, Robert C(DOA) Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 TBU D-29RD (PTD 1850030) TBU D-34A (PTD 1790110) TBU D-41 (PTD 1790830) Checked our well records; MITs are due 11/3/2009. You mention the wells are currently SI for replacement of surface piping from the injection pumps and that could take 6 months. Injection records show Union commenced injecting in September after a long SI - presumably tied to Redoubt eruption. There were 30 days injection for each well in September; unknown number of days each we~l injected in October. Really begs the question - when was the surface piping repair planned? And, why were the wells not tested after commencing injection following the long Redoubt SI. Appears based on info we have that there was opportunity to do MITs prior to SI so that Union could remain in compliance without seeking an variance to the regulations. An explanation would be appreciated. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Anderson, Christy D [mailto:andercd@chevron.com] Sent: Thursday, October 29, 2009 6:53 PM To: Regg, James B(DOA); Greenstein, Larry P Cc: Martin, J. Hal; Bartolowits, Paul D Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Jim These wells are shut in at the present time because we are replacing the surface piping from our injection pumps. It may be six months (hopefully less) before we are done and can bring the wells back on. The plan is that they w+ll be brought back on when the piping is replaced. Bob Noble was scheduled to come out Friday morning has been put on ho~d until you decide to do the MIT or not. Thanks Christy D. Anderson Leacl Operator Dolly Varden Platform Pho~~e 776-6840 Fax 776-6820 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October Z9, 2009 5:38 PM 11 /4/2009 ~ ~ Page 4 of 4 , ~ To: Anderson, Christy D; Greenstein, Larry P Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Understand these wells are SI. Is that long term? Our normal preference would be to wait for welis to be back on line before witnessing MIT Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 _ ___ _. __ _ _.. __. _ _ __ __ _ From: Anderson, Christy D [mailto:andercd@chevron.com] Sent: Wednesday, October 28, 2009 3:03 AM To: Regg, James B (DOA) Cc: Bartolowits, Paul D; Lee, John R Subject: State witnessed MIT an Dolly Varden D-29, D-34 & D-41 Jim We would like to do the Dolly Varden MIT's that are due on D-29, D-34 & D-41 on Friday October 30th Let me know if this will work. Thanks Christy D. Anderson Lead Operator Dolly Varden Platform Phone 776-6840 Fax 776-6820 11 /4/2009 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, November 16,2005 Jim Regg 0 / r ,- .. -;~;;;:~«t~~~--~~~œE:::=~~ - \Îq~ OtpJ-- Src: Inspector . ~ ----..- ~ -~------ FROM: NON-CONFIDENTIAL Reviewed By: P.I. Suprv 5132- Comm Well Name: TRADING BAY UNIT D-41 API Well Number 50-733-20331-00-00 Inspector Name: John Crisp Insp Num: mitJCr051 1 11073648 Permit Number: 179-083-0 Inspection Date: 11/3/2005 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I D-41 ¡Type Inj. I w I TVD I 9146 i IA I I 2350 2350 I 2350 ! I 0 I I P. T. 11790830 ITypeTest I SPT I Test psi I 2286.5 lOA I 290 I 310 310 I 310 ! ! i Tubing! 2600 ! 2600 I 2600 i 2600 I i Interval 4YRTST P/F P ¡ ! Notes IA pressures for the two days previous to MIT were 0 & 80 psi. ~.;;'~'Lt<.~>;'W;¡ .:;.}~."~ t"i!)'tf,;;..; (-~~ ~ l; Wednesday, November 16,2005 Page 1 of 1 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us ""1- greensteinlp@chevron.com; trodnguez@chevron.com OCb :/ \Îq~ OPE RA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Unocal Alaska McArthur River Field / TBU / Dolly Platform 11/03/05 Pat King/Norman Fahnholz John Crisp Sr weill D-29RD I Type Inj. P.T.D. 185-003 Type test Notes: Packer Depth TVD I 8,460' Test psi 2115 Tubing Casing OA W P weill D-34A I Type Inj. P.T.D. 179-011 Type test Notes: I TVD I Test psi W P 9,164' 2291 Tubing Casing OA weill D-41 I Type Inj. W I TVD I 9,146' Tubing P.T.D. 179-083 Type test P Test psi 2287 Casing Notes: OA weill Type Inj. I TVD I Tubing P.T.D. Type test Test psi Casing Notes: OA weill Type Inj. I TVD Tubing P.T.D. Type test Test psi Casing Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form BFL 911/05 Pretest 2525 160 510 Initial 2525 2140 520 15 Min. 30 Min. 2525 2525 Interval 2140 2140 P/F 515 515 4 P 2600 2600 2600 2600 Interval 4 20 2425 2425 2425 P/F P 120 325 325 325 2600 2600 2600 2600 Interval 4 0 2350 2350 2350 P/F P 290 310 310 310 Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) SCANNEU NOV G 82005 , . ..-.-.....-...- ,. M IT _Dolly- 11-03-05-1 . xis REPORT OF SUNDRY WELL OPERATIONS I Operabons pedormed Operabon shutdown __ Sbmulate __ Plugging Pull tubing __ Alter casing ~ Repair well Perforate ~ other_Workover 2 Name of Operator UNOCAL (Marathon 0il Company - Sub OI 3 Address P.O. Box 190247 Anchorage, AK 9951! 5 Type of Well I" v,n t- n vJ~evelopment __ ...... ; Exploratory Strabgraphlc __ Serv,ce X 4 Locabon of well at surface Leg A-l, Cond. ~6 Dolly Varden 755' FSL, 1,218' FWL, Sec. 6-8N-13W-SM At top of productive ~nterval 815' FWL, 1,941' FNL, Sec. 5-8N-13W-SM At effective depth 1,215' FWL, 1,817' FNL0 Sec. 5-8N-13W-SM At total depth 1,297' FWL, 1,787' FNL, Sec. 5-8N-13W-SM Platform 6 Datum elevation (DF or KB) 106' KB RIGINAL feet True verbcal depth psi Tubing Pressure 3900 3200 Injection Date /--/- fg - ~I SUBMIT IN DUPLICATE '~-~- 7 Unit or Property name Trading Bay Unit 8 Well number B-41 9. Permit number/approval number 90-471 10 APl number 50-733-20331 11. Field/Pool Hemlock 12 Present well condition summary Total depth measured true vertical 11,735' feet 9,965' feet Plugs (measured) 11,642' - 11,728' CMT Effective depth measured 11,548 ' true vertical 9,812 ' Casing Length Structural Conductor Surface Intermediate 20994' Production 100734' Liner 1.192' Perforation depth measureo feet Junk (measured) feet true vertical S~ze Cemented 13-3/8" 2,500 sx 9-5/8" 1,985 sx 7" 450 sx See Attachment #1 11,548' - 11,642' (PBTD) 7" Isolation Pkr Measured depth 2,994' 2,776' 10,734' 9,150' 11,728' 9,960' RECEIVED Tubing (size, grade, and measured depth) 3 1/2", 9.3# N-80 tbg., IPC, Packers and SSSV (type and measured depth) Otis RCM Pkr ~ 10,729' 13. Stimulabon or cement squeeze summary w/ DSS - HTC connections APR 1 7 1991 A)aska Oil .& Gas Cons. G0mmissl0n Intervalstreated(measured) Cement squeezed Bench 2, 10,938- 10,988' & 11,000- 11,020' and placed Homco casing patches across the squeezed intervals. Treatment descrlption lncludlng volumes used and flnal pressure Squeezed w/ 175 sxs cmt, Final pressure 3,000 14. Representative Daily Average Production or Injectmon Data Od-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operabon Subsequent to operation 5700 370 4000 0 15 Attachments Copies of Logs and Surveys run __ Dady Report of Well Operabons ..~ 16 Status of ~11 classlhcatlon as. Oil __ Gas __ Suspended __ Serwce t',la ter 17. I hereby cerbfy that the foregoing is true and correct to the best of my knowledge. Signed ev~,,-.--,% ~. ~,..*-~L Title ¢.¢_~ , '~ r\ Form 10-404 R /15/88~ ~ ~,,%r · Bench 1 Bench 3 Bench 4 Bench 5 Attachment ~1 Well D-41 Perforations (MD) 10,882'- 10,g14' 11,066' -, 11,111' 11,138' - 11,296' 11,314' - 11,430' (TVD) 9,270' - 9,296' 9,418' - 9,455' 9,477' - 9,605' 9,620' - 9,715' \docs\dvp\D41 Attachment ~2 TBU Wel 1 D-41 Daily Summary of Operations 11/11/90 RU on Well D-41. Cut mud weight back to 9.0 ppg. Filtered g.O ppg brine. Tested tubing riser to 2500 psi. Circulated g.o ppg brine, taking returns on casing valve to well clean tank. 11/12/90 Monitored well. RIH with "XR" plug. Set at 10,659'. Set BPV. ND tree. Cleaned thread in hanger. NU BOP. Changed out rams. 11/13/90 Finished NU BOP, bell nipple, and flow line. Attempted to test Hydril failed. Cycled Hydril to loosen up. Retest Hydril failed. Tested rams, kill and choke lines 250/3000 psi. Ran steam line in Hydril to warm it up. Tested Hydril 250/1500 psi, blinds 250/3000 psi. Pulled double check valve. MU landing joint. 11/14/90 Pulled and laid down tubing hanger. RU and circulated. POOH an~l~if~ ~/ 3-1/2" tubing. Rigged up Kelly. PU BHA. JP~l~t. i'lV E ~ 11/15/90 Finished picking up BHA. Pick up and RIH with 5" drill pipe. ~~ Gas Co.s. Commissio~'~ 11/16/90 Finished RIH with 5" drill pipe to top of liner at 10,536'. Installed upper kelly valve. Tested kelly valves 250/3000 psi. Washed down 10,536' - 10,688'. Tagged packer at 10,688' DPM (10,678' DIL). Milled on packer 10,688' - 10,690' DPM. POOH. Replaced rotary shoe and picked up spear. RIH. 11/17/90 Finished RIH with spear. Tagged packer at 10,688' DPM. Latched packer. POOH with packer. Full recovery. RIH with overshot dressed for 1-7/8" to TBU Wel 1 0-41 ~. Daily Summary of Operations Page 2 Milled on packer at 11,123' OPM (11,113' DIL). POOH. RIH with over shot to recover wireline tools. Tagged at 11,123' DPM. Worked over fish. POOH. 11/19/90 POOH. Recovered WL tools. RIH w/ mill. Milled on packer 11,123' - 11,125'. Packer fell free. Pushed pkr to 11,548' DPM. CBU. POOH. RIH w/ bit & 7" csg scraper. CBU. POOH. 11/20/90 POOH. RIH w/ retainer & set g 11,055'. POOH. RIH w/ squeeze pkr & set at 10,748' OPM. Tested annulus to 1750 psi. RU Dowell. Sqzed w/ 175 sxs cmt. Final sqz pressure 3000 psi. Unseated pkr. Started POOH 10 stds. 11/21/90 24 Hrs WOC. POOH 10 stds. Held 1000 psi on sqz for 6 hrs. POOH. Tested BOPE. RIH w/ 8-1/2" bit. 11/23/90 Drilled cmt from 10,686' - 10,930'. Tested B-1 sqz to 1750 psi. Drilled cmt to 11,040'. CBU. Tested B-2 sqz to 1750 psi. Drilled retainer and pushed to bottom, 11,546' DPM. CBU. POOH. RIH w/ bit and csg scrapers. 11/24/90 RIH w/ bit & scrapers. Circ and filter. Short tripped. Circ and filter. Prepared to POOH for bond log. 11/25/90 POOH. RU Schlumberger. Run CBT CET f/ 11,520' - 10,536' IES. PU TCP guns. Started RIH. 11/26/90 RIH w/ TCP guns. RU Schlumberger & ran GR/CCL correlation log. Set pkr and perforated Hemlock B-30 4 & 5. Flowed well for 30 min. SI for buildup. Reversed circulated out influx. Unset pkr. Monitored well for flow - losing 7-10 BPH. Spot high visc pill. POOH. TBU Nell 0-41 Daily Summary of Operations Page 3 11/27/90 POOH with TCP guns. RIH with 7" casing patch. Ran correlation log to located casing patch. Set casing patch 11,024' - 11,gg4'. Circulated. 11/28/90 Finished circulating. POOH with running tools for casing patch. Tested BOPE. Picked up second casing patch. RIH with casing patch to lO,gg2' DPM. RIH with GR CCL to position casing patch. 11/28/90 Finished RIH with GR CCL to position casing patch. POOH with wireline. Set casing patch lo,gg2' - 10,g32' POOH with running tool. RIH with perforating guns. Perforated ~rom 10,882' - 10,914' in two runs. Rigged up to run tubing. Started RIH with production packer and 3-1/2" tubing. 11/30/90 RIH with production packer and 3-1/2" tubing. Made up tubing hanger. Started circulating inhibited packer fluid. 12/01/90 Finished circulating inhibited packer fluid. Drop packer setting ball. Attempted to set packer. Ball sheared out early. Dropped X plug and pumped down to XN nipple at 10,787' Set packer at 10,72g'. Landed hanger and attempted to test. Hanger l~aking. Injected packing in hanger. Attempted to retest failed. Picked up hanger. 12/02/90 Replaced seals on tubing hanger. Landed hanger. Repacked hanger. Tested annulus and hanger seals to 2290 psi. Landed BOP stack. Set BPV. Nippled up tree and injection line. Tested seals to 5000 psi. Tested tree and injection line to 5000 psi. RIH with wireline to retrieve "X" plug at 10,787', no recovery. RIH to recover "X." Recovered "X" plug from 10,787'. Prepared rig for skid. Started to skid rig. Released rig. \docs\dvp\d41. doc MARATHON OIL COMPANY TRADING BAY UNIT WELL D-41 WORKOVER 12/2/90 ......... Ail nem~urenen%~ ore RKB ~o top oF equtpnen~, 41' CIV DCB-FBB tb9, ho. nsc, r, 410 %re.%ed ~o NACE NR-O1-75. 3,S' 8RD EUE X D~D-HTC bottom, 305' O%ls Flow ~ouplln9 (~,88' ]~), 310' Otis 'X' N~ppie (2.813' ID). 311' O~s ~ow Coupling (~.88~ I~). Comote'tlon S~rlno, -- 0'-10,794~ 3-1/~; 0,3#, N-80, D$S-HTC Tbg. IPC ~// TK-~,9, ~,994' 13-3/8'~ 68#~ N-BO, BUTT I0,734' 9-5/8; 43.5~ & 47#, N-80, P-IlO Butt, Cso. 10,7~9' 10.735' 10,74~' 10,751' 10,787' 10,794' O~ls HCN Packer, IPC, w/ 'SAP' Seal Anchor assembly HILl Ou~ Extension X-Dver 4' VAH Box x 0~1~ Bruit C~chep Sub/ WL Entry Guide. B-1 HENLDCK PI~RFOI~ATIDN~ g-I B-3 B-4 Interw~ E_~ P~ 10,888'-10914' 38' 8 4:5 10,938'-10,988' 50' Cm~ ~queezed 11,~0'-11,020~ 80' CM~ Squeezed 11,066'-11,111' 45' 8 45 11,138'-1L896' 158' 8 45 11,314'-11,430' 116' 8 45 Dat~ 11/90 11/90 11/90 11/90 11/90 Avergge Deviation = 88,0' B-4 · - HOMCD Steel Liner cso pa~ch covers the Cml sqzd B-8 perFs - reduces 10,53G'-11788' 7', 29~f, N-80 BUSH: Cs9, Old Isolation pk~. ~ 11,603' PBTD 8 lL64~' TD 8 11,735' Revision Da~,e. 3/88/91 Revl.~ed ]~y; JCM/evo Reosom Vor~over Previous Revlslom N/A STATE OF ALASKA ( ALASKA OIL AN D GAS CONSERVATION COM MISSION 0 APPLICATION FOR SUNDRY APPROVALS RI Gl 1 Type of Request Abandon __ Suspend Alter casing m Repair well Change approved program Operabon shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Vanance __ Perforate __ Other __ 2 Name of Operator UNOCAL (Marathon 0il Company - Sub 0 3 Address P.O. Box 190247 Anchorage, AK 9951 4 Locabon of well at surface Leg A-l, Cond. #6 Do1 y 755' FSL, 1,218' FNL, Sec. 6-SN-13N-$M At top of producbve interval 815' FNL, 1,941' FNL, Sec. 5-SN-13N-SM At effecbve depth 1,215' FNL, 1,817' FNL, Sec. 5-SN-13N-$M At total depth 1,297' FNL, 1,787' FNL, Sec. 5-SN-13N-$R 5 Type of Well evelopment __ ~e rat o_~_r h-xploratory Strabgraph~c __ Serwce X Varden Platform 6 Datum elevation (DF or KB) 106' KB 7. Unit or Property name Trading Bay Unit 8 Well number D-41 9. Perm~tnumber/Approval No. 79-83/7-897 10. APl number 50-733-20331 11 F~eld/Pool Hemlock feet 12 Present well cond~bon summary Total depth meas'ured true vertical 11,735' feet Plugs(measured) 9,965' feet 11,642' - 11,728' CMT Effective depth measured 11,603 ' feet Junk (measured) true vertical 9,857 ' feet 11,603' - 11,642' 7" Isolation Pkr Casing Length S~ze Cemented Structural Conductor Sudace Intermed,ate 2,994' 13-3/8" 2,500 sx 10,734' 9-5/8" 1,985 sx Production Liner 1,192' 7" 450 sx Perforabon depth measured true verbcal See Attachment #1 Measured depth 2,994' 10,734' 11,728' True vertical depth 2,776' 9,150' 9,960' RE([EIVED Tub,ng (s,ze, grade, and measured depth) JUN 1 9 1990 3 1/2", 9.2# N-80 ABC tbg., IPC, w/mod, cplgs. Alaska Oil & Gas Cons. Commissi°lt Pa_c .ke. rs and SSSV (type.and measured depth) 7" ~nnCll~le(a Otis WD Pkr w/SBE @10,678' - Otis WD Pkr @ 11,113' - Isolat___..._ 11,603' 13. Attachments 2 &3 Description summary of proposal ~ Detailed operations program __ BOP sketch X__ 14 Esbmated date for commencing operabon ,'July !, 1990 16 If proposal was verbally approved Name of approver Date approved 15. Status of well class~flcabon as Od ~ Gas ~ Suspended Serwce Water Injection 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. S,gned (~^'' ''.. ,4'-'-'"~ ~ , -,..,-(~~. T,tle ~.,~¢.,. Cond~bons of ap~va~ ~obfy Commission so representabve may w~tness Plug ~ntegnty __ BQP~est __ ~cabon clearance __ Mechanical Integnty Test~ Subsequent form required 10- ~ ~ /, ORIGINAl. ~qNEO BY Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMfi IN ~RI PLICATE ~ Bench 1 Bench 2 Bench 4 Bench 5 \docs\dvp\D41 Attachment #1 Well D-41 Perforations (MD) 10,882' - 10,914' 10,938' - 10,988' 11,000' - 11,020' 11,138' - 11,163' 11,236' - 11,296' 11,314' - 11,330' 11,356' - 11,388' (TVD) 9,270' - 9,296' g,315' - 9,355' 9,365' - 9,381' g,477' - 9,497' g,556' - 9,605' 9,620' - 9,633' g,654' - 9,680' RECEIVED JUN 1 9 1990 Alaska 0il & Gas Cons. Commission Anchorage Attachment #2 Revised Procedure Well D-41Workover 1. Fill casing and tubing with FIW. Pressure test 9-5/8" casing. If necessary, perforate circulation holes in tubing at 10,580' and kill well by circulating FIW. 2. Skid Rig #76 over Well D-41. 3. Set BPV. ND tree. NU and test BOPE. 4. POH and LD tubing. 5. PU DP and rotary mill. Mill packer @ 10,678'. POH. RIH w/ spear and retrieve top packer. 6. RIH w/ rotary mill and mill bottom packer and slickline tools. RIH w/ spear and retrieve bottom packer or push to bottom. 7. Clean out to top of old isolation packer 011,603'. POH. 8. RIH w/ cement retainer and set below Bench 2 perforations. 9. Cement squeeze benches I and 2. Mill up cement to top of retainer and pressure test the squeezed perfs. 10. Mill up retainer and clean out to top of old isolation packer. 11. RIH w/ TCP system & (re)perforate the following intervals: Hemlock Bench i 10,882' - 10,914' 3 11,066' - 11,111' 4 11,138' - 11,296' 5 11,314' - 11,430' 12. RIH w/ completion assembly and set packer @ -10,700' MD. Pressure test backside. 13. ND BOPE. NU and test tree. NOTE: Maximum anticipated SBHP is 4800 psi. :ldk\docs\oe49\43 RECEIVED JUN 1 9 1 90 Alaska 0/I & Gas Cons. Commission Anchorage MARATHON OIL COMPA( DOLLY VARDEN PLATFORM BOP STACK ATTACHMENT #3 Flowllne U i 13 S/8'x SOO0 pal Annular Prevanler Kill Line Bhnd Rama I ~ ~ Drill Deck FIoM J (~) S' Howco Lo Torque S000 psi Valve All Flanges ere 3' SOOO pal Pressure Sensor Remole AdJusleble Choke Rig Floor Spool Pie~ea to Ceainghead RECEIVED 3/4' Manual Chok,. j Choke Une 3' 5000 pal o o G. 2' Blind Flange 6' lo Shaker CHOKE MANIFOLD JUN 1 9 1990 Ala~ Oil &'Gas Cons. Commission 3- v.., L,.. ~ ~.~/ Anchorage p Cock Valve 3' ~ L.~ (ToBa Left Open) I 1/2' Manual Choke I / 3' Bull Plug Unocal North Ameri~ Oil & Gas Division" Unocal Corporation P O Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, G u Regional Drilling Manager GSB/lew DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG ~A-1: LAT = 60o48' 28.272" LONG =151°37' 57.620" 2,490,836.22 208,461.20 757.5 FWL LEG ~A-2: 1212.0 1 2 3 4 5 6 7 8 9 10 ll 12 2,490,836.95 208,454.55 D-27 758.1 1205.5 2,490,840.99 208,456.66 D-28 762.1 1207.4 2,490,842.79 208,460.79 D-29 764.0 1211.5 2,490,841.51 208,465.11' D-32 762.9 1215.8 .2,490,837.76 208,467.60 D-40 759.2 1218.4 2,490,833.28 208,467.10 D-41 754.7 1218.0 2,490,830.18 208,463.83 D-26 751.5 1214.8 2,490,829.90 208,459.34 D-25 & RD 751.1 1210.3 2,490,832.58 208,455.72 753.7 1206.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 1209.5 2,490,838.66 208,462.17 D-31 & RD 760.0 1213.0 2,490,834.00 208,462.61 D-24A 755.3 1213.5 LEG r, B-1 · LAT = 60048' 27.485" LONG :151°37' 57.564" 2,490,835.42 208,381.20 754.7 1 2 3 4' 5 6 7 8 9 0 1 2 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 D-17 759.4 2,490,842. O0 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387. l0 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD & 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-1 3 752.5 LEG #B-2: 2,490,756.22 208,462. O0 677.5 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 ' 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 674.8 (Reserved for Compressors) 1132.1 1125.5 1127.4 ll31.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 1219.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operatton shutdown __ StImulate m Plugging __ Pedorate m Pull tubing ~ Alter camng __ Repar well ~ 2. Name of Operator ! 5. Type of Well. Iopment UNOCAL (Marathon 0il Compan.y- Sub O~)erator[~eExp~oratory~ 3 Address / Strabgraphlc __ P.O. Box ]90247 Anchorage, AK 995]~ Serv,ce_~X_ 4 Locatlon of well at sudace Leg A-I, Cond. #6 Bolly Varden Platform 755' FSL, 1,218' FWL, Sec. 6-8N-13W-SM At top of productive ~nterval 815' FWL, 1,941' FNL, Sec. 5-8N-13W-SM At effective depth 1,215' FWL, 1,817' FNL, Sec. 5-8N-13W-SM a depth Att°tll,297' FWL, 1,787' FNL, Sec. 5-8N-13W-SM Other_~_Jet Pump Test 12 Present well condition summary Total depth measured true verbcal 11,735 ' feet Plugs (measured) 9,965' feet Effective depth' measured true vertical Casing Length Structural Conductor Surface Intermediate 2,994' Producbon 10,734 ' Liner 1,192 ' Perforation depth measured 11,603 ' feet Junk (measured) 9,857' feet S~ze Cemented ]3-3/8" 2,500 sx 9-5/8" 1,985 sx 7" 450 sx true vertIcal & Tubing (size, grade, and measured depth) 3 1/2", 9.2# N-80 ABC tbg., Packers and SSSV (type and measured depth) Otis WD Pkr w/SBE @10,678' - See Attachment #1 IPC, w/mod, cplgs. Otis WD Pkr @ 11,113' 6 Datum elevation (DF or KB) 106' KB 7 Unit or Property name Trading Bay Unit 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment descnpbon ~nclud~ng volumes used and final pressure 14. Pnor to well operation Subsequent to operation 15. Attachment~ 2 Cop~es of Logs and Surveys run __ Dady Report of Well Operations x 8 Well number D-41 9 Permit number/approval number 9-265 10 APl number 50-733-20331 feet 11. Reid/Pool Hemlock 11,642' - 11,728' CMT 11,603' - 11,642' 7" Isolation Pkr Measured depth True vertical depth 2,994' 2,776' 10,734' 9,150' 11,728' 9,960' 7" Isolation Pkr @ 11~603' RECEIVED Representative Dady Average Production or Injection Data .'J'as.V,a u~l ~ was Cons. OiI-Bbl Gas-Md Water-Bbl Casing Pressure ~ '_J~'~~ure 16 Status of well class~flcabon as. Oil __ Gas __ Suspended N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ /~/",z--~-'~,~ Title ~'-'-~ ~-z. Form 10-404 Rev 06/15188 SerwceWater Injection ,,,,, Date ~"~ SUBMIT IN DUPLICATE Bench 1 Bench 2 Bench 4 Bench 5 \docs\dvp\D41 Attachment # ~ Well D-41 Perforations (MD) 10,882' - 10,914' 10,938' - 10,988' 11,000' - 11,020' 11,138' - 11,163' 11,236' - 11,296' 11,314' - 11,330' 11,356' - 11,388' (TVD) 9,270' - 9,296' 9,315' - 9,355' 9,365' - 9,381' 9,477' - 9,497' 9,556' - 9,605' 9,620' - 9,633' 9,654' - 9,680' RECEIVED Attachment #2 TBU Well D-41 Daily Summary of Operations 4/1/89 RU wireline. RIH w/ shifting tool and shift open XA sleeve at 10,659~. RD wireline. 4/4/89 RU wireline. RU National jet pump w/ BST SSSV. RU pressure and temperature gauges. Install 12A nozzle in pump and test SSSV @ surface, OK. RIH w/ jet pump assembly and set in X-lock @ 10,659~ WLM, POOH. Open water injection; TP = 3680, CP: 180; SD and bleed pressure to 140 psig. Test SSSV, OK. Open injection water and test jet pump @ 2250 psi tbg pressure. 4/7/89 End test. RU wireline and PT lubricator, OK. RIH and pull jet pump assembly. RIH w/ shifting tool to 10,638~ WLM and close XA sleeve. POOH. RD wireline unit and place well back on injection. Verify integrity of tubing and XA sleeve by noting 3800 psi tubing injection pressure and 80 psi casing pressure. em\docs\DVP\D41 STATE OF ALASKA COM I~,,.,SION KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon ~ Suspend ~ AJ~er casing ~ Rep~ur well __ Change approved program ~ Operabon shutdown ~ Re-enter suspended well __ PluggIng ~ Time extension __ Sbmulate ~ Pull tubing w Vanance ~ Perforate ~ Other 2. Name of Operator J 5. Type of Well. I.. . De~lopment ~ i!,~,r)rAI(M~.nthnn ¢)'11 Cnm.nnn~v - S,mh Iuperal;Ol~ioratory~ 3..N:ldress ! Strat~graphJc ~ P,0. B0;< [90247 Anch0raae. AK 99~[9 Serv,ce_A 4 Loca~3n~well atsurface Leg A-I, Cond. #6 Do'll,y Varden Platform 7 55' FSL~r~te~v~[ 18' FWL, Sec. 6-8N-13W-SM At t(:~ o~ producbve 9. Perm,t number 815' FWL, 1,941' FNL, Sec. 5-8N-13W-SM 7q-R3 At effecbve ~epth 10. APl number Pump 6 Datum elevabon (DF or KB) 106' KR 7 Umt or Property name Tradinq Bay Unit 8 We, number D-41 Testi feet 1,215' FWL, 1,817' FNL, Sec. At total depth 1,297' FWL ~ 1,787' FNL i~ Sec. 12 Present well condition summary Total depth measured 11,735 ' true vemcal 9,965 ' 5-8N-13W-SM 5-8N-13W-SM 50-- 733-20331 Reid/Pool Hemlock feet Plugs(measured) 11,642' - 11,728' CMT feet Effective depth, measured 11,603 ' true vert,cal 9,857' feet Junk(measured) 11,603' - 11,642' feet 7" Isolation Pkr Casing Length Size Structural Conductor Surface Intermediate 2,994' 13-3/8" Producbon 10,734' 9 - 5 / 8" Liner 1 lq2' 7" Perforat)on depth measured - true vertical Cemented Measured depth True verbcal depth 2,500 sx 2,994' 2,776' 1,985 sx 10,734' 9,150' 450 sx 11,728' 9,960' See Attachment #1 R [~'~ ~.] ~ I '~¢' ~ ~ Tubing (size, grade, and measured depth) '~'<';" "' ~ 3 1/2", 9.2# N-80 ABC tbg., IPC, w/mod, cplgs. /J~,skaOjl&GasC0ns. C0mmiSsi0[l Packers and SSSV (type and measured depth) ~ "-, ~mcti0rage Otis WD pkr w/SBE ~10,§78' - 0tis WD Pkr @ !1,113' - 7" Isolation Pkr @ 11.1~603' 13. Attachment~ #2 & 3Descnption summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Esbmated date for commencing operabon April 3, 1989 16. If proposal was verbally approved Russ Douglas March 28, 1989 Name of approver Date approved 15. Status of well classlflcabon as Oil ~ Gas ~ Suspended __ Serv,ce Water Injection 17. I hereby cerbfy that the foregoing is true and correct to the best of my knowledge. Signed/~.. ~/~ T,tle Environmental Engineer 'Ro~ D. R~berts ' FOR COMMISSION USEONLY Cond~bons 6f approval Nobly Commission so representative may w~tness Plug integnty __ BOP Test ~ Location clearance __ ~/¢~ ,ow ~'~ MechanlcallntegrltyTest__ Subsequentformrequlredl0-__ ~,P°~et~e¢~)~' ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Commissioner Date 5/5/89 , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Benc~ BenCh Bench Bench 5 D~ttach~ent # 1 Hell D-41 perforations 10,B$2' - 10,914' 10,93B' - 10,9BB' 11,000' - 11,020' 11,195' _ 11,169' 11,236' _ 11,296' 11,914' _ 11,990' 11,956' - 11,98B' 9,270' _ 9,296' 9,315' _ 9,955' 9,965' _ 9,951' 9,477' _ 9,497' 9,556' _ 9,605' 9,620' 9,654' . 9,650' t~SP lem1551Sunar9 ,.,,,.,,(~,~ CiJ & 6as Cons, Oommissio;~ Attachment #2 Well D-41 Jet Pump Testing Procedure 1. Shut in injection water to Well D-41. 2. RU slickline. PT lubricator to 2500 psig. 3. RIH w/ shifting tool. Shift open Otis XA SSD @ 10,659' MD. 4. RIH w/ National Jet Pump/BST safety valve and X-lock assembly. 5. Pump power fluid down tubing. Operate jet pump. Flow well at minimum rate and stabilize. Reduce power fluid and close SSSV. Bleed well off and check SSSV pressure integrity. RD slickline. 6. Increase power fluid to operating pressure to 4000 psi, and test well at various power fluid rates. Test at each rate for 12 to 24 hours. 7. Terminate test. RU slickline. Remove pump/SSSV assembly and close SSD. 8. Place well D-41 on injection. Monitor csg pressure to ensure SSD integrity. Note: Well D-41 is scheduled for major workover in August, 1989. NEF/em/55/DVP Attachment #3 ~'~.)LLY VARDEN PL/I~'.'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 3 1/8' 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi ~__-- 2' 3000 psi 'U~------- 13 3/8' CASING )O STATE OF ALASKA /-'--" A IL AND GAS CONSERVATION CO,..,, .,SION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well Fi Alter casing [] Time extension El Change approved program [] Plugging El Stimulate F1 Pull tubing ~] Amend order [] Perforate El Other [] 2. Name of Operator tTROCAL (Harathon Oil Company - Sub Ope:ato:) 3. Address P.O. Sox 190247 Aachorage, At(. 99519 4. Location of well at surfaceLeg A-l, Cond. ~6 Dolly Varden Platfoz~ 5. Datum elevation (DF or KB) 106' KB 6. Unit or Property name Trading Bay Unit 7. Well number 755' FSL, 1,218' FWL, Sec. 6-8N-13W-SM At top of productive interval 815' FWL, 1,941' FNL, Sec. 5-8N-13W-SM At effective depth 1,215' FWL, 1,817' FNL, Sec. 5-8N-13W-SM At total depth 1,297' ~E,, 1,787' t~fr_., Sec. 5-8N-13W-$M D-41 8. Permit number 79-83 9. APl number 50-- 733-20331 10. Pool Hemlock feet 11 Present well condition summary Total depth: measured true vertical 11,735 ' feet 9,965' feet Plugs (measured) 11,642' - 11,728' CMT Effechve depth' measured 11,603 ' feet true vertical 9,857 ' feet Camng Length Size Structural Conductor Surface Intermediate 2,994' 13-3/8" 10,734' 9-5/8" Production L~ner 1,192 ' 7" Perforahon depth' measured true vertical Junk (measured) 11,603' - 11,642' 7" Isolation Pkr CemeDted~ Measured depth True Vertical depth 2,500 sx 2,994' 1,985 sx 10,734' 2,776' 9,150' 450 sx 11,728' 9,960' See Attachment #1 RECEIVED Tubing (s~ze, grade and measured depth) 3 1/2", 9.2# N-80 ABC tbg., IPC, w/mod, cplgs. Packers and SSSV (type and measured depth) Otis WD Pkr w/SBE @10,678' - Otis WD Pkr @ 11,113' NOV i ? ! S7 Alaska 0il & Gas Cons. C0mmJss[0,~ 7" '" . ~ch0ra~ zSO.Lat~.on rjr ~ 11,603' 12 Attachments #2 & 3 Description summary of proposal [] Detailed operat,ons program [] BOP sketch El Attachment #4 13 Eshmated date for commencing operation November 1987 14 If proposal was verbally approved Name of approver Date approved 15. I hereb~,,ertify that the for~e, going is true and correct to the best of my knowledge S,gned (~zC.,~_.d%':~-~",i,,~,-~',,*'.~'C_ Title Envir'onmenta] Specialist - Candace' Lockwood Commission Use Only ~ Approved Copy --- ' Returned I~i Mechan,cal integrity Test Approved by~~~-~" ~ t' - ~-'- Commissioner Form 10-403 Rev 12-1-85 Nohfy commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Locahon clearanceI Date ,, by order of the commission Date II/J~~ Submit ~n triplicate ~ Bench Bench 2 Bench 4 Bench 5 Attachment #1 Well D-41 Perforations 10,882' - 10,914' 10,938' - 10,988' 11,000' - 11,020' 11,138' - 11,163' 11,236' - 11,296' 11,314' - 11,330' 11,356' - 11,388' (TVD) 9,270' - 9,296' 9,315' - 9,355' 9,365' - 9,381' 9,477' - 9,497' 9,556' - 9,605' 9,620' - 9,633' 9,654' - 9,680' NEF/em/55/Sundr3 RECEIVED NOV 1 7 1987 A!ask~ Oil & Gas C~ns. Gommissic~ Anchorage Attachment #2 Well D-41Workover Procedure 1. Fill casing and tubing with FIW. Pressure test 9-5/8" casing. If necessary, perforate circulation holes in tubing at 10,680' and kill well by circulating FIW. 2. Skid Rig ~76 over Well D-41. 3. Set BPV. ND tree. NU and test BOPE. 4. POH and LD tubing. 5. PU DP and rotary mill. Mill packer @10,678'. POH. RIH w/spear and retrieve top packer. 6. RIH w/rotary mill and mill packer. RIH w/spear and retrieve bottom packer or push to bottom. 7. Clean out to top of old isolation packer @ 11,603'. 8. RIH w/TCP system & (re)perforate select intervals in Benches 1 through 6. POH. 9. RIH w/ packer & perform inJectivity test including injection pro- file. 10. Evaluate need for vertical conformance treatment and perform same using BP and packer as necessary. POH. LD DP. 11. Set sealbore packer @±10,700'. RIH w/ completion assembly. Pres- sure test backside. 12. ND BOPE. NU and test tree. Pressure test backside. 13. Commence water injection and run a second injection profile after rate stabilizes. Note: Anticipated maximum bottomhole pressure is 3,500 psi. Completion fluid will be FIW sufficiently weighted to keep the well overbalanced. NEF/em/55/Sundr3 Conductor 404 ~ Howco stage collar 6,487 9-5/8" 43.5, 47# N-80, P-II0 buttress casing 7" Liner cop @ 10,~6 9-5/8" Casin8 ~o 10,754 Ohs t~D packer 10,678 DIL u/ SB ext. (4.00" Bell Guide 10,691 ,i~cls'VDpkr. 11,113 DIL OltS X-nip. 11;}32 DIL I (2.75" ID) Bell Guide 11,140 DIL ~7" Liner co '-: TEU D-4 I COHPLETION SCHEMATIC 3-l/2" Cl~¢ OCB EUE x EUE tubing ha~ ([/4" plus tn bom pore) 3-1/2'* 9.28 N-80 A~C Cubing, ZPC, v/ AB mod. cplgs. IO,659 10,686 · 10,7AO 10,753 5-1/2" Otis XA sleeve, 2.75" ID 4" OD O?ts seal assembly, 3.00" ID (12' seals) 3-1/2" Otis X n~pple, 2.75"'ID Hal,-cut mule shoe, 3.00" ID Perforations DIL Bench I 10,882-10',914 Bench 2 IO,938-10,988 11,000-11,020 Bench 4 11,1~8-11,16~ 11,2~6-11,296 Bench 5 11,514-11,550 11,~56-11,388 11 603 Top of old 7" Isolation pkr. II,6&2'~PBTD *. $-9-8.~ 7" Liner Co 11,728' TBU Veil D-Al Proposed Completion Tubin~ Henser 2,994' 13-3/8" 68J, K.-$5 Butcreqs Ce~. 3-1/2' Tbs, Completion Strtn8 10,536' 7" Liner Top 10,700' Sealbore Pecker 10,73A' 9-5/8" &3.5 & 171, N-80, PIIO Buttress Cos. Perforations (DIL) Bench ! 10,882' - 10,91~' Bench 2 10,938' - 10,~88' 11,000' - 11,020' Bench & 11,138' - 11,163' 11,236' - 11,296' 11,603' Top o! old 7# isolation pkr. 11,6&2' PBTD 11,735' 13) MARATHON OIL GO.- --DOLLY VARDEN PLATFORM -- At t a chmen t4 ~4 Well D- U --M~I Pon Drlilin~,l iXlippi~ :5"~ 5,000'~- Kill Lin~-- ~-ES~A'' Double.- Gote..- Ghoke Line- .~x5,O00 D~ill Deck Floor Riser ~-BOP _~fack For D~illin~' From Uhd~r Sur{~ce O~sing To ~D.-- 1 ~/¢11 Room Floor GI~J ..~win~- Bolt Connectors RECEIVED NOV 1 7 1987 Alaska Oil & Gas Cons. CommissIO~ Anchorage 2 Ff. Spool 12"~3,000~ C~sin~I Hec~d w/VlgnQed Outlets ~ Valves Collor ~onduc~or Unocal Oil & Gas Divisi~ Unocal Corporabon ~ PO Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Group Alaska D~stnct November 1, 1985 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE INTENTION D-41 Attached for your approval are 3 copies of a Sundry Notice of Intention to remove the retrievable bridge plug from well D-41 and re-establish injection into benches 4 and 5. Work is expected to commence as early as November 2 therefore, we would appreciate verbal approval as soon as possible. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST tj Attachments /~r STATE OF ALASKA . ALASK ,L AND GAS CONSERVATION C( ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL {~ OTHER [] 2 Name of Operator 7 Pe./l~lt~% Union Oil Company of California* 8' _~l~J~m~6 3 31 3. A~roeSSO ° Box 6247 Anchorage, AK 99502 50 - 9. qa, t ork~se Na~ Tra~ng say Unit Leg A-1, 755 ' FSL, Cond. 1218' FWL, #6, Dolly Varden Platform Sec. 6-8N-13W-SM KB above 'MSL 12 I 6~LE~?-'le'3ies~t'qj)atl~n and Serial No 10 Be/lz~d~mber 11 F,eld and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m '~r~phcate) (Submit m Duplmate) Perforate [] Alter Casing [] Perforanons [] Altering Casing [] Stimulate [] t Abandon [] Stimulation [] Abandonment [] Repmr Well [] , Change Plans [] Repmrs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note. Report mulnple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13. Describe Proposed or Completed Operations (Clearly state all pernnent detads and g~ve pertinent dates, ~nclud~ng estimated date of start,ng any proposed work, for Abandonment see 20 AAC 25 105-170) TBU WELL D-41 It is Marathon's intention to remove the retrievable bridge plug at 11,132' DIL, and re-establish injection into Benches 4 and 5. The plug was set in May 1983 to isolate polymer injection in Benches 1 and 2. Wireline operations to retrieve the bridge plug are expected to begin as early as November ~, 1985. . , ~ *Marathon Oil Company - Sub Operator , ECE VED Alaska 0il & Gas C-~ ,:, Cm':~m,as~0n 14 I here~a/~t~ fo(~~true Signed Law'~ence 0v: Cut'tSing The space below for Commission use and correct to the best of my knowledge ~_~ T,tle Env i ronmenta 1 Spec i a 1 i st Date 1 1 / 01 / 85 Conditions of Approval, ~f any Approved by IIlI~IIAI. ]111[I Approved By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr,phcate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [-1 '~ 2 Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99504 4. Location of Well Surface: Leg A-l, cond. #6, Dolly Varden Platform 755' FSL, 1218' ~TL, Sec. 6-8N-13W-SM 5. Elevation ~n feet (~nd~cate KB, DF, etc ) 106' KB above MSL 12 Lease Designation and Serml No ADL 18729 7 Permit No 79-83 8 APl Number 50-733-20331 9 Unit or Lease Name Trading Bay Unit 10 Well Number 9-41 11 Field and Pool McArthur River Field Check Appropmate Box To Indicate Nature of Notice, Report, or Other Dbta NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF (Submit m Tmphcate) (Submit m Duplmate) Perforate [] Alter Casmg [] Perforations [] Altemng Camng q Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completmns on Form 10-407 with a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly irate all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonm, ent see 20 AAC 25 105-170) D-41 Acid Stimulation On July 7, 1983, well D-41 was stimulated with 5100 gal of 15% HC1, 5100 gal of 12-3 HF mud acid w/ a 375# benzoic acid flake diverter plug. 1275 gal 15% HCl @ 1.25 BPM 2550 gal 12-3 HF @ 1.25 BPM 1275 gal 15% HCl @ 1.25 BPM 375# Benzoic plug @ 2.5 BPM 1275 gal 15% HCl @ 1.25 BPM 2550 gal 12-3 HF @ 1.25 BPM 1275 gal 15% HC1 @ 1.25 BPM The acid was displaced w/ 150 bbls. of F.I.W. After pumping the displacement water, the well went on vacuum and was then returned to injection. Injection before acid 1800 bwpd @ 3150 psi. RE[E~V~P Injection after acid 1803 bwpd @ 760 psi. ,'aUG-- ~ ~8'~ * Ma~on Oil Company - Sub-operator 14., here~y cett,fy thai the ~eg~s true and ~orrect to ~e ~e~ o~ ~ ~.o.,e~ C~ons of Approval, ~f any Date 7/27/83 By Order of Approved by COMMISSIONER the Commmslon Date Form 10-403 Rev 7-1-80 Submit "lntent,ons" m Triplicate and "Subsequent Reports" m Duplicate ~(' STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE LL)(~ OTHER [] 2 Name of Operator Union 0il Company of California* 3 Address Post Office Box 6247, Anchorage AK 99502 4 Location of Well Surface: Leg A-l, Cond. //6, Do!ly Varden Platform 755' FSL, 1218' FWL, Sec. 6-8N-13W-SM 5 Elevation ,n feet (indicate KB, DF, etc ) 106' KB above HSL 12 Lease Deslonatlon and Serial No ADL-18729 7 Permit No 79-83 8 APl Number 50- 733-20331 9 Unit or Lease Name Tradinq Bay Unit 10 Well Number D-41 WO 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 Tr~pl,cate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations X~ Alter,ng Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X~ Pull Tubing [] Other [] Pulling Tubing X~ (Note Report multiple completions on Form 10-407 wlthasubmltted Form 10-407 for each completion) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and give perunent dates, including estimated date of starting any ~ proposed work, for Abandonment see 20 AAC 25 105-170) Convert D-41 to Injection The workover was completed on May 7, 1983. attached. The completion procedure is *Marathon Oil Company - Sub-operator 14 I he~:~ certify that th~ f/~o~ RE£E VED ]UN 0 Alaska Oil & Gas Cons. Comm~ssior~ Anchorage 6/1/8~ · ~true and cgrrect to the best of my knowledge ~**'.,~~_~ ~f . Title DISTRICT DRLG SUPT below for Col ImlSslon use/~ ~l ~~~~ htlonsofApproval, lfany ~.,,'-/ /,,---v ) - - ~,,,-,"¢---~,,,~ Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate Convert D-41 to Injection Completion Procedure 1. Moved Rig //76 over well and rigged up. 2. Rigged up Otis and pressure tested lubricator to 2000 psi. 3. RIH w/ Otis & attempted to open XA sleeve--would not open. Broke Otis wi re & left 20' of tools in hole. 4. RU Dresser Atlas and tested lubricator to 2000 psi, RIH w/ 2-1/8" tbg perf gun w/ 2 HPF, (8 shots total) and perfd tbg 10,655'-10,653' WLM. POH & RD Dresser. 5. Circ & kill well w/ FIW. Installed BPV, ND tree, NU & test BOPE, pul 1 BPV. 6. Pull & LD 3-1/2TM production string, recovered WI_ tools. 7. Milled pkr from 10,787'-10,799'. Recovered pkr w/ taper tap. 8. Milled pkr from 11,041'-1t,043', pushed fish to PBTD @ 11,642'. Left fish in hole. New PBTD @ 11,603' (TOF). 9. Perfd B-1 w/ 12 HPF, 120° phasing @ 10,884'-10,914' DIL. 10. Perfd B-2 w/ 12 HPF, 120° phasing @ 10,938'-10,988' Dll_ & 11,000'- 11,020' DIL. 11. RIH & set RBP @ 11,094', set test pkr ~ 10,702', opened RTTS to back flow perfs (moderate blow at surface diminished to 0). 12. Began injectivity test. 13. RU SOS & test lubricator to 4000 psi. RIH w/ CCI, RAT, temp & full bore spinner. Completed logging. POH w/ SOS. 14. RIH & released pkr. Reset RBP ~ 11,500' & reset pkr @ 1~),708I. Ran injectivity test. 15. Released pkr and BP and POH. 16. RIH w/ SOS, set inj pkr @ 11,115' DIL. POH. 17. RIH w/ SOS, set WD pkr ~ 10,680' DIL. POH, RD SOS. 18. RIH w/ 3-1/2" inj tbg. Stabbed into pkr. I,anded tbg. Set BPV, ND BOPE, NU & test tree. Pull BPV. ECEIVE WJL: lyd JUN 0 Alaska 0;I & Gas Cons C;Jmm~$sior~ Anchorage K(~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator Union Oil Company of California* 3 Address P.O.:Box 6247, gmehorage, Alaska 4 Location of Well Surface: 7 Permit No 79-83 99502 8 APl Number 5o-733-20331 9 Unit or Lease Name Trading Bay Unit Leg A-I, Cond. #6, Dolly Varden Platform 755' FSL, 1218' FWL, Sec. 6-8N-13W-SM 5 Elevation ~n feet (ind~cate KB, DF, etc ) 6 Lease Designation and Serial No 106' KB above MSL ADL-18729 10 Well Number 9-41 11 F~eld and Pool McArthur River Field 12 Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tnplmate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Camng [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Well 9-41, Polymer Injectivity Test Procedure: 1. Obtain 30-day water injection pressure and rate baseline. 2. Inject 1000 ppm partially hydrolyzed'polyacrylamide polymer for 60-day injection test. 3. Tail in with remaining polymer from washdown and deactivation of polymer manufacturing plant. 4. Re-establish 30-day water injection pressure and rate baseline. ~.,u~q]~tSSl0~~ * Marathon Oil Company - Sub-operator 14 I here~rt~fy that the foregoing ~s tru.~end correct to the best of my knowledge S,gne~~j.~ /~..~.~ ~~/ T,tle . ~STRICT DRL~ SePT T he~ebelowforCo~,ss,onuse ~ ~Z ~/~~~ Returned Date 611183 Approved by. BY LOItHIE C. SI, AITii COMMISSIONER By Order of the Commission Date Form 10-403 Rev 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ,\ ! ' K/t STATE OF ALASKA / /~,~? j ALAS ~IL AND GAS CONSERVATION (~ ~IMISSION ( ~ ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO'N Drdlmg well [] Workover operation IX] Name of operator Union 0il Company of California* 7 Permit No 79-83 3 Address 8 APl Number Post Office Box 6247, Anchorage AK 99502 50- 733-20331 4 Location of Well at surface Leg A-l, Cond #6, Dolly Varden Platform 155'FSL, 1218'FWL, Sec. 6-T8N-R13W-SM 6 Lease Designation and Serial No ADL-18729 5 Elevauon ~n feet (indicate KB, DF, etc ) 106' KB above HSL 9 Unit or Lease Name Trading Bay Unit 10 Well No D-41 WO 11 Field and Pool McArthur River Field For the Month of Apri l , 19 85 ,12 Depth at end of month, footage drdled, fishing jobs, d~rect~onal drdhng problems, spud date, remarks 11,6421PBTD; 11,728' TD RU on 4-19-83 to convert to inj well. RIH w/ fishing tools to 10,789' & rec pkr, seal Tagged pkr @ ll,041'--¢ould not rec pkr & tail bore ext & tail pipe assy. pipe on fifth attempt. 13 Casing or hner run and quantities of cement, results of pressure tests N/A 14 Conng resume and brief description N/A 15 Logs run and depth where run N/A DST data, perforating data, shows of H2S, m~scellaneous data Perfd Hemlock Bench 1 ~ 10,884'-10,914' Perfd Hemlock Bench 2 @ 11,020'-11,000'; 10,988'-10,9681; 10,938, -10,968 i~'¢ 17 I hereby/~rt~fy that the foregoing ~s true and correct to the best of my knowledge '~'"~.)~. ' N 'TE ~h 'ftYs- ;- r, ~f-~O --Report o t ~j o m ~s equ~ ed o e~ cai ne dar month, regardless of the status of operaUons, and must be hied ~n d~hcatew~ththeAlaska Od and Gas Conservation Comm~ssjon by th~tb of the succeeding month, unless otherwise d~rected Form 10~04 ~ Submit ~n duphcate Re'v 7-1-80 *Harathon 0~Comp~y Sub-operator f STATE OF ALASKA C( ALASKA OIL AND GAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Union Oil Company of California 3 Address P.O. Box 6247, Anchorage, Alaska 4. Location of Well Surface: A~lm o, Leg A-l, Cond #6, Dolly Varden Plattorm 755' FSL, 1218' FWL, Sec. 6-8N-13W-SM 7 Permtt No 79-83 8. APl Number 50- 733-20331 9. Umt or Lease Name Trading Bay Unit 10. Well Number 9-41 11 F~eld and Pool 5. Elevat,on in feet (indicate KB, DF, etc ) I 6 Lease Demgnatlon and Serml No 106' KB above MSL ADL-18729 12. Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT'DF: McArthur River Field ,. (Submit ~n Tmphcate) (Submit m Duplicate) Perforate 7~ Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans X~ Repairs Made [] Other Pull Tubing ~ Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each complenon ) 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starung any proposed work, for Abandonment see 20 AAC 25 105-170) Convert Well D-41 to Injection Procedure: le 2. 3. 4. 5. e 7. 8. 9. 10. 11. Move Rig 76 over Well D-41 and rig up. _ Kill the well, install BPV, remove tree, install and test BOPE, remove BPV. Pull and LD 3-1/2" production tubing. Retrieve permanent packers from 10,744' DIL and 11,030' DIL. Reperf~rate and back flow B-1 & 2. Establish injection into B-1 & 2 and stimulate w/ matrix acid. Establish injection into B-l, 2, 4, and 5. Set isolation packer above B-4 and an injection packer above B-1. RIH w/ injection tubing. Set BPV, ND BOPE, NU and test tree, pull BPV. Begin water injection. Verbal approval for the change of procedure was received from Russ Douglass on April 15, 1983, by W. J. Laverdure. ~uB.~eque.nt Wor~ Bepc~fe~ * Marathon Oil Company- Sub-Operator on 14 I hereb~ertffy that the foregoing m true and correct to the best of my kn~lpdge ,or I C~,,ons of Appr;val, ,f any // - ;- - - APProved copAPR 2 0 1983 E~urned Approved bv BY LOHBIE C. SBITH COMMISSION~n Date 4/21/83 Form 10403 Rev 7-1-80 Subm,t "Intentions" tn T, phcate and "Subsequent Reports" ~n Duphcate L ALASKA IL AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2 Name of Operator 7 Permit No UNION Oil COHPANY OF CALIFORNIA* 79-83 3 Address 8 APl Number P0 BOX 6247 ANCHORAGE AK 99502 so-733-20331 4 Location of Well 9 Unit or Lease Name Surface: Leg A-l, Cond #6, Dolly Varden Platform TRADING BAY UNIT 755' FSL, 1218' FWL, Sec. 6, T8N, R13W, SM. 10. Well Number D-al 11. Field and Pool 5 Elevat,on ,n feet (,nd,cate KB. DF, etc ) I 6 Lease Des,gnat,on and Ser,al No McArthur River Field 106' KB above MSLI ADL 18729 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 Cas,ng [] Stimulate ~[] Abandon [] St~mulat,on [] Abandonment [] Repmr Well [] Change Plans ~ Repairs Made [] Other [] Puli Tubing ~] Other [] Pulhng Tubmg [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descr,be Proposed or Completed Operations (Clearly state all pertinent detads and gwe pertinent dates, mcludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Convert Well D-41 to Injection Procedure: 1. Move Rig 76 over D-41 and rig up. 2. Kill well, install BPV, remove tree, install and test BORE. 3. Pull 3 1/2" tubing. .<'~ A/oTICF. ~F 4. Abandon B-5 with a cement plug: DI~TED A. Set cmt retainer ~ ll310' DIL on WL. B. RIH w/ retainer stinger on DP. ~,~//_ /I-i~-E,~ C. Sting into retainer. Breakdown Bench 5 with water. D. Sting out of retainer. Mix cmt & circulate down to stinger. E. Sting into retainer. Squeeze Bench 5. Sting out of retainer. Rev DR clean. ROOH. 5. Reperforate Hemlock B-1 & 2. Establish injectivity. Treat as necessary. 6. Set an isolation packer above B-4. 7. Set an injection packer above B-1. 8. RIH w/ injection tubing. 9. Install BPV, remove BORE, install and test tree. MAR 2 4 ~983 10. Begin water injection. *Marathon Oil Company - Sub-operator AJaska 0~ & Gas Cons. Commi$ 14 I cert,fy~at the foregmng ~s t~ and correct to the best of my knowledge .., .... ~/~~~/~~ District Drlg Superintendent 3/22/83 S~gne T~tle Date The/a~e"l~elow fc[ Corem,ss,on use ~,~'~~'"- v-- " ~dltlons of App oval, if any -// Approved Copy Returned - By Order of Approved by COMMISSIONER the Commission Date ;ion Form 10-403 Rev 7-1-80 Submit "1 ntent~ons" .1 Tr~phcate and "Subsequent Reports" ~n Duplicate '~L STATE OF ALASKA ALASKA AND GAS CONSERVATION C -~...,'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator Union 0i ] Company of California* 3. Address P.0, Box 6247, Anchorage, Alaska 99502 4 Locat,on of Well Surface: Leg A-l, Cond #6, Dolly Varden Platform 755'FSL, 1218'FWL, Sec. 6-8N-13W-SM 5 Elevauon ,n feet (,nd,cate KB, DF, etc ) 106' KB above HSL Lease Des,gnat,on and Serial No ADL-18729 7. Perm,t No 79-83 8. APl Number 50- 733-20331 9. Un,t or Lease Name _ Trading Bay Unit 10 Well Number D-41 11 F,eld and Pool McArthur River Field 12 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit ~n Tr,pl,cate) Perforate ~X Alter Cas,ng [] Perforations Stimulate ~X Abandon [] Sumulatlon Repa,r Well [] Change Plans [] Repairs Made Pull Tub,ng ~ Other [] Pulling Tubing (Note Report multiple complet,ons on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF. (Subm,t m Dupl,cate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ,ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Convert Well D-41 to Injection Procedure: , 5. 6. 7. Move Rig 76 over D-41 and rig up. Kill well, install BPV, remove tree, install and test BOPE. Pull 3 1/2" tubing. Abandon B-5 w/a cmt plug. Reperforate Hemlock B-1 & 2. Establish injectivity. Treat as necessary. Set an isolation packer above B-4. Set an injection packer above B-1. ¢~' 8. RIH w/injection tubing. ~ D/~TED 3/.t~/~.~:, 9. Install BPV, remove BOPE, install and test tree. 10. Begin water injection. RECEIVED ~8~ ,,.arathon Oil Company- Su~-Operator f4,,.24~ aC ~¢~ Anchorage l~4 I her~y certdy that the foregoing ~s ~rue and corr~ to ~he best of m~ knowledge The s~ce below for C~m,ss,on ~e- ~- ~~ ~tle DIST DRLG SUPT Date ~pproved Returnod 8Y LONNI[ C. SMITH Approved by CO~ISSIONE~ the Comm~ss,on Form 10~,03 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ,n E)upl~cate / STATE OF ALASKA ALASKA( _AND GAS CONSERVATION C( MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLX3[ OTHER [] 2 Name of Operator 7. Permit No. Union Oil Company of California* 79-83 3 Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20331 4. Location of Well Dolly Varden Platform, Leg A-i, Cond #6, 755'FSL, 1218'FWL, Sec. 6-8N-13W-SM Elevation m feet (,nd,cate KB, DF, etc.) 106.2' KB MSL I6. Lease Des,gnat,on and Ser,al No. ADL-18729 A-926 9. umt or Lease Name Tradin~ Bay Unit 10. Well Number 9-41 ~ 1 1. Field and Pool 12. McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Subm,t m Tr,phcate) (Subm,t m Dupl,cate) Perforate [] Alter Casing [] ~ Perforat,ons [] Altering Casing [] Stimulate [] Abandon [] St,mulation [] Abandonment D Repa,r Well [] Change Plans [] Repa,rs Made [] Other [] Pull Tub,ng [] Other I--I Pulhng Tubing [] (Note. Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13. Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, ~nclud~ng est,mated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170) On November 22, 1980, perforated following Hemlock intervals under drawdown: Bench 2: 10,938' - 10,988' 4 HPF 2-5/8" DA 0° Phasing Bench 5: 11,402' - 11,432' 4 HPF 2-5/8" DA 0° Phasing Production Test: Before Perfs - 402 BFPD After Perfs - 841 BFPD 42% WC 233 BO?D 63% WC 311 BOPD Verbal approval to perforate received from Russ Douglass to Tony Swan on October 24, 1980. *M~thon Oil Company - Sub-Operator Anc,~Or~O~ Commissioq S,gned T,tle Dist. Drlg. Supt. Date 12/8/80 C~ons of Approval, ~f any By Order of Approved by. COMMISSIONER the CommissIon Date Form 10-403 Rev. 7-1 -~0 SubmIt "Intentions" ~n Tr~phcate and "Subsequent Reports" ~n Duphcate Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such I)rol~osals.) O,L I::TI GAs r'-I WELL~.J WELL L..J OTHER 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P. 0. Box 6247, ^nchora~e AK 99502 4o LOCATION OF WELL At surface Leg ^-1, Cond #6, Dolly Varden Platform, 755'FSL, 1218'FWL, Sec 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB 14. Check Appropriate Box To Indicate Nature of Notice, Rel NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF L-------i FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING L.....! MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) 5. APl NUMERICAL CODE 733-2O331 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 A-926 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradins Bay Unit 9. WELL NO. D-41 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5t T8Nt R13W~ SM 12. PERMIT NO. 79-83 )orr, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) .., (NOTEt Report results of multiple completion on Well ComlNltlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detllll~ ancl give pertinent dates, including estimated date of starting any proposed work. On 04-01-80, perfd following Hemlock interval under drawdown: Bench 5: 11,330'-11,356'DIL 4 HPF 2-5/8" DA 0° Slim Kone gun On 04-03-80, reperfd following Hemlock intervals under drawdown: Bench 1: 10,882'-10,914'DIL 2 HPF 2-5/8" DA 180° Slim Kone gun Bench 4: 11,138'-11,163'DIL 2 HPF 2-5/8" DA 180° Slim Kone gun Production Test: Before Perfs: 262 BFPD 27% WC After Perfs: 790 BFPD 29-1/2% ~I:~?a 0 RECEIV!:D Verbal approval to perforate received from Russ Douglass to Tony Swan on 03-20-80. *Marathon Oil Company - Sub-Operator 16. I hereby ~that the foregoing is true and correct SIGNED _ __ -- _ LE (Th~'a'~ for State office use) Dist. Drlg. Supt. DATE 4/21/80 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: COMMISSIONER DATE See Instructions On Reverse Side ~rm ]~o ~ ~- 1-70 STATE (,' ALASKA' OIL AND GAS CONSERVATION COMMI'FI'EE SUBMIT I~ 13U1PLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL WKLL W~,LL NAME OF OP~TOR Union Oil Company of California* ~s o~ o~- P, O, Box 6247, Anchorage AK 99502 ~CA~ON O~ w~ Leg A-l, Cond #6, Dolly Varden Platform, 755'FSL, 1218'FWL, Sec 6-8N-13W-SM AP1 NUMERICAL CODE 733-20331 LEASE DESIGNATION AND SEI~IAL NO ADL- 18729 A-926 ~7 IF II~IDIA]~ ALOi t~:~- OR TRIBE NAME 8 L.~IT FARM OR LEASE lqAME Trading Bay Unit D-41 10 F{~:i;Y~ A_ND POOL OR WILDCAT i]~lcArthur River Field ~11 SEC T, R, M (BO'I'TOM HOLE oa,mc-'Tiv~ Sec. 6, TSN, R13W, SM SET AND VOLTO'MES USED P~O~TIONS. ~TS ~ ~SUL~ FISHIHG JO~ J~K L~ HO~ ~D SIDE-~C~ HO~ ~aRUARY RfPORT 0~ ~R ~ LL [ ~ 0PERAT[ ONS 02-01 11,735'TD 11,64 2 ' PBTD Instld flow line & GL line. RU DA & perf Bench 5, Hemlock Zn from 11,356'-11,388'DIL w/ 2-1/8" Jumbo Jet (4 HPF) under draw- down cond. POH. RIH w/ 2-1/8" perf gun to cent perfg. 02-02 11,735'TD 11,642'PBTD DA perfd Bench 5, Hemlock, from 11,314'-11,330'DIL w/ 2-1/8" Jumbo Jet (4 HPF). RD DA. RU Camco & ran HP gauge. GL & unloaded well while controlling the flowing BHP. No fluid entry. SI GL gas--no BU. POH w/ HP gauge. 02-03 11,735'TD 11,642'PBTD Fin POH w/ HP gauge. Loaded tbg w/ 45 bbls FIW. RU DA & reperf B5, Hemlock Zn, from 11,358'-11,388'DIL w/ 2-1/8" Jumbo Jet (4 HPF). After POH for 400', 7/32" WL parted ~ grease head. RU clamps & rec WL & perf gun. Chgd out DA WL unit. RIH w/ 2-1/8" Jumbo Jet to cent reperf Hemlock. 02-04 11 , 735 ' TD 11,642'PBTD DA reperfd B5, Hemlock, from 11,314'-11,330'DIL w/ 2-1/8" Jumbo Jet (4 HPF). RU Camco & RIH w/ HP gauge. GL B5 to FBHP of 800 psi. Rec 5 bbls fm fluid. Last cut 65% wtr. SI GL gas. BHP built from 800 to 862 psi in 1 hr. POH w/ HP gauge. Loaded w/ 30 bbls FIW. RU DA & perfd Bench 4 of Hemlock from 11,264'-11,296'DIL w/ 2-1/8" Jumbo Jet (4 HPF). 02-05 11 , 735 ' TD 11,64 2 ' PBTD DA perfd B4, Hemlock from 11,236'-11,264' and 11,138'-11,163' DIL w/ 2-1/8" Jumbo Jet (4 HPF). RD DA. RU Camco & RIH w/ HP gauge. GL & unloaded well. Rec 57 bbls fluid. Last 4 bbls of fluid was heavy emulsion w/ 43% BS&W. *Marathon Oil Company - Sub-Operator 14 I hereby ce that the foF~'~o~ true ~d correct ~~a,~j~,/~~..~.4,~/.~ Dist. Drlg. Supt. 2/19/80 Report on this f~ Is required ~r ~ calendar ~th~ regardless of the status of operatbns, and must ~ flied in dupli~te with the oil and gas conservatbn commiflee b~ the 15~ of the suec~ding mn~, ~le~ Otherwise dwected. SUBMIT It STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ta TYPE OF WELL on. ~ ~As t I k_J Other %% ELI WFLL ~ DRY b TYPE OF COMPLETION ~[[! ¢)IFR ~ / EN ~ B~CK EES'* R Other ATE * other hi- revel .-e s.te, §API NU3iERIC~ CODE $2- ?o 7~-20331~, 6 !-EASE DI~3!GN~.TiON A-NID SER~ NO~ ADL- ] 8729 A-926 '7 IF INDi~, ~l-r~ OR TRIBE N~ 8 UNIT,FARM OR LF.~SE NA_ME Trading Bay Unit D-41 10 FLELD A.ND POOL, OR WII..DC&T McArthur River Field 11 SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12 PER,MIT N'O 79-83 ' i16 E3..EVATIONS tDF, RKB, I~T, GR, ETC)'II? EI.~V C.a~SINGHEAD 106.2'KB MSt ~1 62' MSt , _ INTER~ALS DRILLED BY CABLE TO01 S 23 WAS DIRECTIONAL SURVEY MADE Yes t l. £O~OUNT PULLED 2 NAME OF OPERATOR Union Oil Company.of California* 3 ADDRESS OF OPERATOR Post Office Box 6~47. Anchorage AK 9950? 4 IOC~TI0\ 0F ~ELL {Report locatwn clearly and tn accordance w~th a~y State r~tl~re~znts)* 755'FSL, ~FWL, Sec 6-8N-I~W-SM, Cond ~6, Leg A-1 (NE) At top prod i~terval reported below At total dep~ 1297'[~t~1787'FNt, Sec 5-8N-15~-S~ ~ ~T~ S~U~D~ ~ ~ T D ~C~ [~ ~ CO,~ SUS~ Oa ~A~ 11--24--79[ 01--21--80 ~ 02--10--8~ Top of Hemlock: 10,880'MD (9268'TVD) Btm of Hemlock: 11~548'MD (9812'TVD) g4 T~E E~CTRIC AND OTH~ ~OGS DIFSL/GR, FDC/CNL, FDC/Caliper/GR, BHC/GR, Cyberlock, ,Gyro i ii . I ~ CASING REC:ORD (Re~rt all strmgs set in well) C~/~NTING REC OF~ ~-~/,,, ~t [ ~-~ [ 2,~%~, 2~00 ~-5/~" . ~t [ ~-80[ ~,6~-6' 9-5/8" 47~ /P-1 lq 10~934' 26 LIN~ R~CO~ 7" [ 10,556' ~1~,,728' [ 450 28 PERORATIONS P~ TO PRODU O~ ' (ingerval, raze and number) Bench ~: ~0,882'-10,9~4~ DA 2-~/8" 4 H~F Bench 4: ~,~58'-~,~65' DA 2-~/8" 4 Beach 4: 1~,256'-~,296' DA 2-~/8" 4 MPF' __ Bench 5' ~,5~4'-~,550' DA 2-~/8" 4 ~' Bench 5: ~,556'-~,588' DA 2-~/8" 4 30 PRODUCTION DAlE FIRST ~I-IODUC~ON ~ ~ODUCTION MEI[{OD (Flown, g, ['~3 hfc, pdmpmg~slze and type of pump, 02-08-80 ~ Gas Lift DATE OF TEST. [~OURS 2EST~ ' ICItOI{E SiZE IP~oD N FOR OI~BBL G~%~CF 02-1~-80 ! 24 I ' I 524 ~O%V, ~ BING ~CA~G PRESS~E ICALC~T~ OI~BBL GA~?~CF 1 01 t [ ,,1 D~SPOSmWN Or OaS (Sold, u, e4 for fuel, vented, ere ) Lif~ Gas and Sales .o7 I SCidgEN {hiD) SIZE D~P;iS{ SET (MD) ~ PACt~ER SET (MD) 5-1/2" 11.049' i 1],050' & ,[ 10,774' 2J ACID, SHOT, FiI.AC2 ~RE, C~L~T SQUEeZe, ETC HOLE SIZE I 17-1/2"I 12-1/4"I 12-1./4"1 1st Staqe 1185 sx; [~2_1/4,,L 2nd S, tate 800 sx TUBING RE JOILD AMDUN£ 2d~D Ii!ND OF 1ViATE?JAL USED ] V~ELL STATUS (Producmg or Produci mn W£~TER--BBL I GAS-OIL I1-~2~fO I 105 I 967 WA'rJ~--BBL ] OIL GRAVITY-~I (CO~) T~T %% ITNESSED BY 2/19/80 30.LIST OF ATTACHMENTS Well History, Tubing and Casing Detai Is 33 I hereb~ cert21~ that the f.9~eg.~i~g and attached information is complete and correct as determined from all-a~allable record~ ' /~~/i ~o_ ~.. / Dist. Drlg. Supt. DATE l~ TITLE SIGNED --rg~ - , ~/ *(See Instructions and Spaces I:or Additional Data on Reverse Side) *Marathon Oil Company - Sub-Operator INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well completion report end log on all types of lan:is and leases ~n Alaska Item: l&: Indicate which elevation ~s used as reference (whe,e not otherwise sho,,vn) for depth measure- ments g~ven ~n clher spaces on th~s form and ~n any attachments Items 20, ~,nd 22:: If th,s well is completed for separate prcducl~on from more than one ~nterval zone (mulllple complehon), so state ~n ~tem 20, and ~n ~tem 22 show the plcJuc~l~g ~nt6rval, or ~nte~vals, top(s), bottom(s) and name (s) (~f any) for only the ~ntervoJ reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~denhf~ed, for each additional ~nte~val to be seperately produced, show- ~ng the acJkJ~honal data pertinent to such ~nterval Item26: "S~cks Cement". Attached supplemental records for th~s well should show the details of any mul- tiple stage cemenhng and the Iocahon of the cementing tool Item 28: Submit a separate completion report on this form for each ~nterval to be separately produced (See instruchon for items 20 and 22 above) i , ~4 SUMMA. HY OJ~ ~RMAT~bN TESTS INC'LUDIN(, IN"IER. V~I., TESTED PRF.,S.SUI1E DATA. ~ REC'~¥£RIES OF OIL, GAS WATER AND MUD NAI~ See I~em 30 See I~em 22 i i ~ il r ii , - I Il I I l[ I [I f I I I I I I I [ II I I [ Il ]Il I la I ltl 0ore ~1: 10,921~-10,938~ - Rec 17~ oil ss, shsle, & coal Core ~2: 10,938'-10,969' - Rec 31' sh, oil ss, sltst Core ~3: 10,969'-10,993' - Rec 24' oil ss & congl Co~ ~4: 10,993'-11,017' - Rec 23' oil ss & congl Core ~5: 11,017'-11,035' - Rec 18' oil ss & congl ,~ , ,, ........................................... , .... , FORM 484 REV 3--63 DATE 02- 15-$0 MARATHON OIL COMPANY HISTORY OF OIL OR GAS WELL FIELD McAr~hur ~iver WELL NO. D-41 STATE Al aska LEASE Trading Bay Unit PARISH Kenai Penin- COUNTY. sula Borough BLOCK SEC. 6 I . TWP 8H R13W 106.2' ELEV KB i ToP OF OIL STRING __ ELEV MEASUREMENTS TOP OF ROTARY TABLE__ ELEV TAKEN FROM I, GRD OR MAT. ELEV . HISTORY PREPARED BY L. G. Haywood TITLE, S~.cret ar¥ 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 11-18 11-19 11-20 11-21 11-22 11-23 11-24 11-25 11-26 11-27 1-28 1 1-29 11-30 12-01 12-02 491 'TD 869 ' TD 1,369 'TD 2,600'TD 3,000 ' TD 3,000'TD 3,000'TD 3,000'TD 3,000'TD WELL HISTORY - WELL TBU D-41 (Marathon AFE 4669) Moved rig eqpmt from Rig 77 to Rig 76., Cont w/ RU ops on Rig 76. Cont w/ RU ops. Moved Rig 76 over D-41 coductor. Fin moving rig over D-41 cond. Instld OCT starting hub on conductor. Cont to RU. RU drlg eqpmt. Mixed spud mud. Started NU 20" BOPE. Fin NU 20" BOPE & tstd same. PU BHA & RIH to 363'. CO bridge @ 363'. RIH to 390'. Circ @ 390'. C&C mud @ 390'. CO to 404'. Circ for gyro surv. RU DA & Sperry-Sun & ran gyro surv from 389'-surf @ 25' intervals. Drld to 491'. Unplugged cutting chute & desander & desilter. WO elec power to mud pumps. POH to unplug bit. RIH to 390'. Circ & raised visc of mud. RIH to 491'. Surv @ 491'. POH & RIH w/ DD & 12-1/4" bit. Oriented DD & faced S58°E. DD 491'-575'. POH & LD DD. RIH w/ 12-1/4" bit to 400'. C&C mud to raise visc. Washed to 491'. Made trip to unplug bit. Washed to 575'. Drld, circ, & surf to 869'. Drld 869'-994'. POH. RIH w/ DD run ~2. Oriented DD & DD from 994'-1189'. POH. LD DD. RIH w/ 12-1/4" bit. Reamed 984'-1189' w/ new BHA. Drld 1189'-1369'. Drld & surv 12-1/4" hole from 1369'-2600'. Drld & surv to 3000'. POH. LD DP. MU HO ~1 & started in hole., Opened 12-1/4" hole to 17-1/2" from 491'-2260'. Opened 12-1/4" hole from 2260'-2996'. C&C mud. Made short trip. Circ hole cleanc POH. LD hole opener. RU to run 13-3/8" csg. RU & ran 77 jts 13-3/8" K-55, 68#, Butt csg. RU Halliburton & cmtd 13-3/8" csg w/ 1500 sx CIG cmt w/ 1/2 gal/sk Econo- lite & .1% HR6L followed by 500 sx CIG w/ .75% CFR-2 & .3% Halad 22-A. Tailed in w/ 500 sx C! G neat. Bumped plug w/ 1500 psi. Had cmt returns. CIP @ 0530 hrs, 12-01-79. \ ND 20" BOP & riser. Cut off 13-3/8" csg. Instld 13-3/8" Bradenhead & welded same. Weld failed to test. Cut off 13-3/8" csg stub & started rewelding 13-5/8" Bradenhead. Well History - Wel I TBU D-41 Page 2 12-03 3,000'TD 12-04 3,000'TD 12-05 3,000'TD 12-06 3,000'TD 12-07 3,162'TD 12-08 4,462'TD 12-09 5,060 ' TD 12-10 5,220'TD 12-11 5,359'TD 12-12 5,970'TD 12-13 6,357'TD 12-14 6,679'TD 12-15 7,100'TD 12-16 7,382'TD 12-17 7,856'TD 12-18 7,883'TD 12-19 8,060'TD Welded Bradenhead on 13-3/8" csg & tstd same. Relocated crown block to center traveling blocks over RT. Repaired BOP remote control panel. Started NU BOPE. Tstd BOPE & related eqpmt. Tests were witnessed by State rep. Instld flow nipple on Hydri I. Found ring groove on top of Hydril to be too large. Hydril head had been sent in for machine work on ring groove while rig was dwn. Removed Hydril head. While offloading Hydril head from platform to send to machine shop for remachining, crane operator dropped Hydril head into Inlet. Could not locate another 13-5/8" Hydril or Hydril head in the area. Hydril is sending a head from Houston to arrive the evening of 12-04-79. CU A-1 well room & repaired misc rig eqpmt while WO arrival of 13-5/8" Hydril head. ETA of head @ DVP is 1100 hrs, 12-05-79. 13-5/8" Hydril head arrived ~ DVP @ 1030 hrs, 12-05-79. lnstld head & connected all lines to Hydril. MU BHA & RIH to FC @ 2909'. Tstd Hydril to 1500 psi. Tstd 13-3/8" csg & pipe rams to 2000 psi--all OK. Started drlg FC. Fin drlg FC & drld cmt to 2982'. Tstd 13-3/8" csg to 2000 o psi--OK. Drld cmt to 2994'. C&C mud. Ran gyro surv @ 100' intervals on sand line to 2987'. POH. RIH w/ bit #6. Drld to 3004'. Conducted leak off test to 13.9 ppg mud equiv. POH. RIH w/ bit #7. Drld 3004'-3162'. Drld & surv from 3162'-3826'. POH. RIH w/ bit #8. Drld to 4462'. Drld 4462'-4571'. POH. Cut & slipped drlg line. RIH w/ bit #9. Drld 4571'-4787'. Lost pump press. POH. Found bit washed out @ jet nozzle. RIH w/ bit #10. Drld 4787'-5060'. Drld from 5060'-5220'. POH. Tstd BOPE & related eqpmt--OK. MU DD & started in hole. Fin RIH w/ DD. RU DA & Sperry-Sun steering tool. DD from 5220'-5329'. POH. RIH w/ bit #12. Reamed 5220'-5329'. Drld from 5329'-5359'. Drld from 5359'-5639'. POH. RIH w/ new bit. Drld 5639'- 5970'. Drld 5970'-6270'. Circ & surv. POH for BHA chg. RIH & washed 1 jt to btm--no fill. Drld 6270'-6357'. Drld~to 6414'. POH. RIH w/ bit #15 & drld to 6679'. Started out of hole. Fin POH. RIH w/ bit #16. Drld 6679'-7047'. POH. RIH w/ bit #17. Drld to 7100'. Drld 7100'-7320'. POH. RIH w/ bit #18. Drld to 7382'. Drld 7382'-7616'. POH. RIH w/ bit #19. Drld to 7856'. Circ & surv. POH & LD BHA. Tstd BOPE--all OK. PU DD. RIH & oriented tool. DD to 7883'. , DD 12-1/4" hole 7883'-7886'. POH & PU BHA. RIH to 7826'. Reamed 7826'-7886'. Drld & surv 7886'-8060'. POH for bit chg. RIH w/ bit #22. Well History - Well TBU D-41 Page 3 12-20 8,335'TD 12-21 8,604'TD 12-22 8,804'TD 12-23 9,115'TD 12-24 9,354'TD 12-25 9,638'TD 12-26 9,835'TD 12-27 10,001 'TD 12-28 10,141 'TD 12-29 10,320'TD 12-30 10,368'TD 12-31 10,511'TD 1980 01-01 10,556'TD 01-02 10,603'TD 01-03 10,725'TD 01-04 10,725'TD 01-05 10,758'TD 01-06 10,758'TD 01-07 10,758'TD 01-08 10,758'TD RIH w/ bit #22. Drld 8060'-8335'. POH for new bit. RIH w/ bit #23. Drld 8335'-8604'. POH. Fin trip for bit #24. Drld 8604'-8804'. Drld 8804'-8829'. POH. RIH w/ bit #25. Drld 8829'-9115'. Started out of hole. Fin POH. Tstd BOPE & related eqpmt. RIH w/ bit #26. Drld 9115'-9354'. POH to chg bits. Started in hole w/ bit #27. Fin RIH w/ bit #27. Drld 9354'-9638'. Dropped surv. POH. RIH w/ bit #28. Drld 9638'-9835'. Started out of hole. Fin POH. RIH w/ bit #29. Drld 9835'-10,001'. Started out of hole. Fin POH. RIH w/ bit #30. Drld 10,001'-10,141'. Circ & surv. POH. RIH w/ bit #31. Drld to 10,320'. Drld to 10,325'. POH. RIH w/ bit #32. Drld to 10,368'. Started out of hole. Fin POH. RIH w/ bit #33. Drld 10,368'-10,511'. Started out of hole. Repaired drawworks motor. Fin POH. Chgd bits. RIH w/ bit #32RR. Drld to 10,556'. Drld 10,556'-10,579'. POH. Tstd BOPE & related eqpmt. Repaired air pump on Koomey unit. RIH w/ bit #34. Drld to 10,603'. Drld 10,603'-10,725'. Made 20-std short trip. Circ for open hole logs. POH. RU to log. Fin RU to log. SOS ran DIL/SP/Sonic & FDC/CNL logs. RD Schl. RIH w/ bit #35. Corrected TD from 10,725' to 10,738'. Drld 10,738'-10,758'. C&C mud & 12-1/4" hole. Made lO-std short trip. Hole OK. C&C mud to run 9-5/8" csg. POH. Fin POH. RU & started running 9-5/8" csg. Fin running 265 jts, 9-5/8" 43.5# & 47#, N-80 & P-110 csg. FS @ 10,734', FC @ 10,646', & DV clr ~ 6488'. HOWCO cmtd 1st stage w/ 915 sx CI C cmt w/ 1/2 gal/sk Econolite, 0.3% HR6L, & 1/4 #/sk flocel (13.4 ppg). Bumped plug w/ 2500 psi--held OK. CIP @ 0130 hrs, 01-07-80. Opened DV clr @ 6488 w/ 1000# w/ no cmt rtns. HOWCO cmtd 2nd stage w/ 800 sx CIG cmt w/ 1/2 gal/sk Econolite & .3% HR6L (13.5 ppg). Closed DV clr w/ 2500#. CIP @ 0640 hfs, 01-07-80. Bled press-plug held OK. ND csg tools. Instld 9-5/8" csg slips. Cut csg. ND BOPE. lnstld tbg spool & NU/BOPE. Wel I History - Wel I TBU D-41 Page 4 01-09 10,758'TD 01-10 10,909'TD 01-11 10,938'TD 01-12 10,969'TD 0 1-13 10,992' TD 01-14 10,993' TD 01-15 11,017'TD 01-16 11,066'TD 01-17 11,232'TD 01-18 11,439'TD 01-19 11,662'TD 01-20 11,703'TD 01-21 11,735'TD 01-22 11,735'TD 01-23 11,735'TD 11,642'PBTD Tstd BOPE & related eqpmt. Instld seal in hydromatic brake. PU BHA & RIH to DV clr ~ 6488'. Tstd 9-5/8" csg to 2500#--0K. C&C mud prior to drlg DV cir. Drld DV clr ~ 6488'. Tstd 9-5/8" csg below DV clr to 2500#--0K. Drld cmt 10,600' to plug ~ 10,604'. Drld plug & cmt to 10,720'. Tstd 9-5/8" csg to 2500#--0K. Drld 10,720' to shoe @ 10,733'. Drld shoe & cmt to 10,758'. Drld new hole to 10,768'. Conducted leak-off test to 11.2 ppg. Drld to 10,880'. POll. RIH w/ bit #37 & drld to 10,909'. Drld 10,880'-10,921'. POH. Repaired Iow clutch. PU Christensen core bbl & RIH. Cut core #1 from 10,92t'-10,938' (17'). POH & rec 17' of core #1 (100%). RIH w/ core bbl. Cut core #2 from 10,938'-10,969' (31') POH & rec 31' of core #2 (100%). RIH w/ core bbl. Cut core #3 from 10,969'-10,992'(23'). Cut core #3 from 10,992'-10,993' (1'). POH & rec 24' of core #3 (100%). Instld seals in Iow drum clutch (7 hrs). RIH w/ bit #37RR. Reamed 90' to btm & dropped surv. POH. POH w/ bit #37RR. RIH w/ core bbl & cut core #4 from 10,993'- 11,017' (24'). POH. Rec 22-1/2' of core #4. RIH to cut core #5. RIH. Cut core #5 from 11,017'-11,035' (18'). POH. Rec 18' of core #5 (100%). Total core cut in 5 runs: 114'; Total Recovery: 111.5'. Tstd BOPE & related eqpmt. RIH w/ bit #39. Reamed 10,976'-11,035'. Drld from 11,035'-11,066'. Projected TD: 11,732'. Drld w/ bit #39 from 11,066'-11,123'. Surv & POH. Tstd BOP's. RIH w/ bit #40. Reamed 11,090'-11,123'. Drld 11,123'-11,232'. DRId w/ bit #40 from 11,232'-11,409'. Circ & surv. POH & PU bit #41. RIH & reamed 11,355'-11,409'. Drld 11,409'-11,439'. Drld 11,439'-11,517'. Made wiper trip to 9-5/8" shoe. Drld 11,517'-11,601'. Made wiper trip to 9-5/8" shoe. Drld 11,601' 11,662'. Drld 11,662'-11,703'. C&C mud. Short trip to 9-5/8" shoe. C&C mud & hole for OH logs. POH. RU to run OH logs. Schl running SP/DIL & Sonic logs. Schl ran Density log. RD Schl & NU flow lines. RIH w/ bit #42 & drld 11,702'-11,735'. C&C mud & hole for 7" Inr. RU to run 7" Inr & started running same. RIH w/ 28 its 7", 29#, Butt Inr to 1~_~1 728'. Set BOT hgr ~ 10,551'. Top of 7" Inr ~ 10,536'. Tstd surf lines & pumped 30 bbls wtr followed by_4~O _~s~ C]G cmt w/ 1% CFR-2, 0.3% Halad 22A, 3% KCL, & 1/4 #/sk floc~el (15.8 ppg slurry). Dropped plug & d ispl w/ 10 bbls wtr & mud. Bumped plug w/ 3000#. PU & circ. CIP ~ 1745 hrs. POH & WOC. Cleaning rig & upgrading r i g eq pmt. WOC. Tstd BOP's. RIH w/ 8-1/2" bit & drld cmt 10,191'- 10,435'. Well History - Well TBU D-41 Page 5 01-24 11,735'TD 11,64 2 ' PBTD 01-25 11,735'TD 11,642'PBTD 01-26 11,735'TD 11,642'PBTD 01-27 11,735'TD 11,642'PBTD 01-28 11,735'TD 11,642'PB.TD 01-29 11,735'TD 11,642'PBTD 01-30 11,735'TD 11,642'TD 01-31 11,735'TD 11,642'PBTD 02-01 11,735'TD 1-1,642'PBTD 02-02 11,735'TD 11,642'PBTD 02-03 11,735'TD 11,642'PBTD 02-04 11,735'TD 11,642 ' PBTD 02-05 11,735'TD 11,642 ' PBTD 02-06 11,735'TD 11,642'PBTD Drld cmt 10,435'-10,536'. POH. RIH w/ 6" bit & 3-1/2" DP. Press tstd Inr lap w/ 2500# for 20 min--OK. RIH to 11,428' & drld cmt 11,428'-11,642'. POH. RIH w/ Halliburton DST tool for Inr lap test. Set tool @ 10,511' w/ 2000'WC. Recorded 1 hr flow period & 2 hr SI. POH. Lnr lap tstd OK. RU DA & ran Sperry-Sun gyro. Prep to run CBL. DA ran CBL & NLL logs. RD DA. RD DA. RIH w/ bit to btm of 7" Inr ~ 11,728' & displ mud w/ FIW. POH. LD DP & BHA. RU DA. RIH w/ JB & GR to 11,100'. POH. No restrictions in 7" Inr. Did not rec any junk in basket. RIH w/ Otis WD pkr. WD pkr hung up in tie-back sly (7-1/2"1D) @ top of Inr ~ 11,536'. Failed to work Otis WD pkr free. DA set pkr @ 11,536' & POH. RIH w/ Bowen spear & latched pkr. POH. Rec pkr & tail pipe. Left pkr rubber & slips in hole. PU 8-1/2" bit. RIH w/ 8-1/2" bit & csg scraper to top of 7" Inr @ 10,536'. Rev circ from 10,536'. POH. RIH w/ 6" bit & scraper to PBTD @ 11,642'. Rev circ hole clean. POH. RU GR & JB to 11,050'. DA set Otis WD pkr ~ 11,030'DIL. POH. RIH w/ 2nd Otis WD pkr. DA set Otis WD pkr @ lO,774'DIL. RD DA. RIH w/ 5" & 3-1/2" DP. POH & LD DP. RU & RIH w/ 3-1/2" prod pkr. Fin RIH w/ 3-1/2" tbg & landed in Otis WD pkr @ 10,774'. Tstd seal assy to 2100#--0K. Removed BOPE & started NU Xmas tree. Tstd Xmas tree to 5000#--OK. Instld flow line & GL line. RU DA & perf B5 of Hemlock Zn from 11,356'-11,388'DIL w/ 2-1/8" Jumbo Jet (4 HPF) under DD cond. POH. RIH w/ 2-1/8" perf gun to cont perfg. DA perfd B5 of Hemlock from 11,314'-11,330'DIL w/ 2-1/8" Jumbo Jet (4 HPF). RD DA. RU Camco & ran HP gauge. GL & unloaded well while controlling the flowing BHP. No fluid entry. SI GL gas--no BU. POH w/ HP gauge. Fin POH w/ HP gauge. Loaded tbg w/ 45 bbls FIW. RU DA & reperfd B5 of Hemlock from 11,358'-11,388'DIL w/ 2-1/8" Jumbo Jet (4 HPF). After POH for 400', 7/32" WL parted @ grease head. RU clamps & rec WL & perf gun. Chgd out DA WL unit. RIH w/ 2-1/8" Jumbo Jet to cont reperf Hemlock. DA reperfd B5 of Hemlock from 11,314'-11,330'DIL w/ 2-1/8" Jumbo Jet (4 HPF). RU Camco & RIH w/ HP gauge. GL B5 of Hemlock to FBHP of 800 psi. Rec 5 bbls fm fluid. Last cut 65% wtr. SI GL gas. BHP built from 800 to 862' psi in 1 hr. POH w/ HP gauge. Loaded tbg w/ 30 bbls FIW. RU DA & perfd B4 of Hemlock from 11,264'-11,296'DIL w/ 2-1/8" Jumbo Jet (4 HPF). DA perfd B4, Hemlock, from 11,236'-11,264' and 11,138'-11,163' DIL w/ 2-1/8" Jumbo Jet (4 HPF). RD DA. RU Camco & RIH w/ HP gauge. GL & unloaded well. Rec 57 bbls fluid. Last 4 bbls of fluid was heavy emulsion w/ 43% BS&W. GL well @ stabilized rate of 494 BFPD @ 25% WC (370 BOPD). SI well @ 1730 hrs, 02-05-80, for BU surv. FSIP = 3395 psi. Opened well for DD surv @ 0630 hrs, 02-06-80. Well History - Well TBU D-41 Page 6 02-07 11 , 735 ' TD 11,642' PBTD 02-08 11 , 735 ' TD 11,642'PBTD 02-09 11,735'TD 11,642'PBTD 02-10 11,735'TD 11,642'PBTD 02-11 11,735'TD 11,642'PBTD Fin running DD surv ~ 2030 hfs, 02-06-80. Well stabilized 496 BFPD ~ 26-1/2% WC (356 BOPD) w/ FBHP = 843 psi. Ran gradient surv & found well to be lifting from btm GLV. POH. RD Camco. RU DA & perfd B1, Hemlock, from 10,882'-lO,914'DIL w/ 2-1/8" Jumbo Jet (4 HPF). GL Benches 1, 4, & 5, Hemlock, @ 528 BFPD @ 25% WC (396 BOPD). Dismantling eqpmt on Rig 76 for storage. Started moving drlg eqpmt to Rig 77. GL well to prod facilities. Cont to RD Rig 76 & mothballing same. GL well ~ 447 BFPD ~ 24% WC (349 BOPD). Cont RD Rig 76. GL well @ 447 BFPD ~ 24% WC (349 BOPD). Fin RD Rig 76. Released rig @ 1900 hrs~ 02-10-80. FINAL REPORT February Report of Drilling Operations Page 2 02-06 11,735' TD 11,642' PBTD 02-07 11,735'TD 11,642'PBTD 02-08 11,735 ' TD 11,642' PBTD 02-09 11,735'TD 11,642'PBTD 02-10 11,735'TD 11,642' PBTD 02-11 11,735'TD GL well @ stabilized rate of 494 BFPD @ 25% WC (370 BOPD). SI well @ 1730 hrs, 02-05-80, for BU surv. FSIP= 3395 psi. Opened well for DD surv @ 0630 hr s, 02-06-80. Fin running drawdown surv @ 2030 hfs, 02-06-80. Well stabilized @ 496 BFPD @ 26-1/2% WC (356 BOPD) w/ FBHP= 843 psi. Ran gradient surv & found well to be lifting from btm GLV. POH. RD Camco. RU DA & perfd Bench 1 of Hemlock Zn from lO,882'-10,914'DIL w/ 2-1/8" Jumbo Jet (4 HPF). GL Benches 1, 4, and 5, Hemlock Zn, @ 528 BFPD @ 25% WC (396 BOPD). Dismantling eqpmt on Rig 76 for storage. Started moving drlg eqpmt to Rig 77. GL well to prod facilities. Cont to RD Rig 76 & moth- bailing same. GL well @ 447 BFPD @ 24% WC (349 BOPD). Cont RD Rig 76. GL well @ 447 BFPD @ 24% WC (349 BOPD). Fin RD Rig 76. Released rig @ 1900 hrs, 02-10-80. FINAL REPORT ( ( , Sl=e -sun CONFIDEN[IAL d. A. Fouch~ President Mr. Curtis Do~en Marathon Oil Ccmpany P. O. Box 2380 Anchorage, AK 99502 February 13, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16534 Well D-41 Trading BayUnit Field Date of Survey: January 25, 1980 Please find enclosed the "Original" and eleven (11) copies of our Boss Gyroscopic MultishotDirectional Survey run four (4) different methods. ~, Included in the four methods-are Radius. of Curvature,-Average Angle, Tangential and Trapezoidal. _Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc RECEIVED FE~ 1 9 1980 Al~ka Oil & G~s f,.~nt~ ~,o~,,,,r¥~lon MARATHON OIL COMPAI~Y D-41 TRADIK6 EAY U~,IT ALASKA BOSS SURWEL TRUE MEASUREB VERTICAL DEPTH DEPTH SPERRY-SUN INC. RECORD OF SURVEY SUB COURSE COURSE DOG-LEG StA Ik~LINATION :IRE~TioN SEV TVD BEG YIN DEG MIN DEG/iO0 PAGE 1' DATE OF SURVEY dANUARY 25~ 19RO VERTICAL SECTION DIEEC~ION N-60-5/4-OO-E BOSS-1653q TOTAL '~ECTAkGULAR COORDiN/~T~ VERTiCAl NORTF/SOUTH EAST/WEST SECTIO~ 0.00 b.o6 100.00 100.00 200.00 1~9.99 300.00 299.99 ,,00.'00 3s9.98 --i06.20 ORIGi~J ~T ~URFiCE -6,20 0 :;.30 S 9 0 E 93,79 0 3.30 N 56 0 E 1S3,79 0 45 N '9" 'b E 293,78 0 34 N ~6 0 W 0.00 N - - O.~--E 0.00 .50 .~+3 S .07 E -.~',~ · 84 .62 S .50 E · · 55 .27 N .96 ~ .97 · 63 1.26 N , .71 E 1.2/4 500.00 600.00 700,00 ~oo .oo gO0.O0 q99;95 ..... 3~32i5 2 0 ..... S-i~'- {3- E 599,76 493,56 ~+ 30 $ 66 0 E 699,46 593,26 q 30 S .63 0 E 799,15 692.95 '4 25 S"63 0 E 898,86 792.66 q 25 S 63 0 E 2,55 ,2~ ,08 0,00 1.1~ N - lziBb if-~ ~.36 .83 S 7.32 [ 5.97 ~.21 s lq.qo E 1o.,+7 7.74 S 2i,~ E '-' 14,7~ 11.24 S 28.19 E 19.02 10 11 12 13 15 16 17 18 19 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 .00 .00 .00 .00 .00 .00 .00 ~98.50' 892.30 5 iO S 76 0 E 1097.81 991.61 8 0 N 76 0 E 1196.45 1090.25 10 Q5 N ~9 0 E 12~4.~ 1188.1/4 i~ '4'~'- ~ ' N ~5 d E 15S1.~5 1285.19 15 ~ N 45 0 E 1~-87.3q i~8i.i~ 'ii 34 'N 45 0 E 1581.90 1~+75.70 20 19 N z~5 0 E 1675.01 1568.81 22 25 N 45 0 E 1766.q~ 1660,28 ~5 10 N"45 0 E 1856.16 1749,96 27 19 N ~5 0 E 1,32 q,20 5,11 '2,i6 ....... 2.32 2.75 2.10 2.75 2.15 lq.07 S 35;99 ~2-- - -~4;~-~- 13.48 S /47,11 E 3/4,39 5.68 S 60,90 E 50.23 8.24 N '-?-5.?zV-£ ...... ?0.oo 25.24 N 92.7~ E 93.16 45.i0 N -ii2.60 E .... i~~ 68.05 N 135.5~ E 151./48 93,80 N 161.30 E 186,58 122.32 N -'- i89,{3~' ~ ........ ~2~.4~' - ~53.58 N 22Z.08 E 268.03 20 21 22 O0 O0 O0 O0 O0 .00 .00 .00 .00 .00 2029.49 1923.29 31 ~5 N 45 0 E 2114.21 2008.01 32 25 N q~ 0 E 2198.~6 2092.36 32 34 N ~4 0 E 2282.72 2176.52 32 Ag N Q5 0 E 1.59 .85 .i5 .60 187.92 N 224.65 N 290,90 E 363.77 262.53 N 328.13 E q1~.82 301,17 N 365,4~ 339,70 5 26 27 28 29 00,00 00,00 00,00 00,00 00,00 2~50.20 23~.00 33 34 N ~5 0 2533.29 2427.09 34 ~ N ~5 0 2615.91 2509.71 34 30 N 46 0 26S8,21 2592.01 3~ qq N 46 0 E E E E .50 .50 .71 .23 /416.99 N 480.59 E 623.53 456.3~ N 519.9~ E 677,15 495.82 N 560.12 E 731.5~ 5~5,28 N 600.98 E 786,53 MARATHON OIL COMPANY O-~l TRADIkG BAY UNIT ALASKA BOSS SLRWEL TRUE MEASURED -'-VERTICAL DEPTF DEPTH SUB SE~ TVD ......... ~ ~D E ~ R ~z- § ~""N~ i~-~. RECORD OF SURVEY COURSE COURSE DOG-LEG iNCLiNaTION DiR~CiiO-N- SEV DEG PIN DEG MIN DEG/IO0 PAGE DATE OF SURVEY dANUARY 25, 1980 VERTICAL SECTION DIRECTION N-60-54-OO-E BOSS-16534 TOTAL RECTANGUL/~R COORDINAYE~ NORTF/SOUTH EAST/WEST V£RTICAL SECTION 3000.00 .... 27~0-;4~ 3100.00 2862,7~ 3200.00 2944,96 3300.00 .... ~bdi.~7 3400.00 3109,45 2674.27 2756.54 2838,76 2920.9'~"-' 3003,25 613,00 N 683,96 E 651,75 N 725,67 E 952,. 690,65 N 767.2~ E'-- 1007~70 729,42 N 808.80 E 1062,g6 35~o 3600 3700 38oo 3900 · dO ....... ~1~2.0~ ~0d~;e~ - · 00 3274.79 3168.59 ,00 3357,40 3251.20 .oo .... ~ 4'~-6'-. i ~ .... ~'~3.9o · 00 352),09 3416,89 -~4 5 34 12 34 25 34 0 33 49 N 46 47 E N'47 30 ~- N 47 :30 E ,18 805,91 N 891,31 [ 841,57 N 932,33 E 1227,15 882.~8 N 973241'f-- 1~81281 920,57 N 101q,60 E 1336,16 ,~boo 4100 ~200 ~00 4500, 4600. 4700. 4800. 4900. · 00 3606,19 ,00 3689,24 · 00 3772.65 .oo 3~56.~0 .00 3939.9~ O0 4023.64 O0 4107.32 O0 41°.1.28 ~275,47 O0 4359,97 3583.04 33 54 3666,A. 5 .33 q. 3833,75 .93 4 4001.12 33 4 4085.08 32 44 4169.27 ........ ~ ~' '- ~+253.77 32 ~ N 47 54 E ..... ;23 ...... '~8;01 N 1~5'~,-'"t'~--L~-. .... N 47 17 E ,36 995,56 N 1096.87 E N 47 2~ E .84 1032,95 N 1137,44 E N 47 47 E '-;3~' 'i069,90 N --'I1??;gO ~- k 47 17 E ,42 1106,88 N 1218,52 E 1498,39 15'5 I% 7g --- 1605.17 -'-~-~7 17-E .... .~5 ...... i144,0~ N ---I2~;~5F-'1~~''. N 47 24 E .26 1181,11 N 1298,81 E 1711,76 N 46 5q E .43 1218,05 N 1338,63 E 176~,60 'N-~'?-~"~- '-;~--' 125~.57 N '137~;35-E .... I817;15 N 17 la E ,5~ 1290.~9 N 1~17.96 E 1869,~0 5000.00 5100.00 5200.00 5~5o.oo 5300.00 4529,33 4614.78 q. 657.90 '4701.57 N 46 q2 E ,98 N 47 35 E ,61 N' 5b--'~4- E- ~;3~ ..... N 57 12 E 6,57 132~:.77 N" 1363,11 N 1398.44 N i4i4.97 14 1429.25 N -' 'I~57'2-'1~-E .... I92162E--- 1195,69 E 1972.70 1553,78 E 2023.23 --'155~';93 E '- 204~,0'4- 1572.58 E 2072,17 55 56 57 O0 O0 O0 nn .0 .0 ,0 .0 4875,58 '4961,23 5045.85 4769.38 .90 27 4855.03 31 41 q. 939,65 2}2 43 5n~3.17 34 0 N -5~- '3'5- E .... I-;55 ...... 14.:4; $8 'N' ' N 60 A7 E 1.07 1479.53 N N 61 47 E 1.34 1504,31 N N ~'3-'I~ E 1;~8 1528.91 N N 63 42 E 1,31 1553.48 N 1-6iS;~-~---.--.2120;6~ -- 1657,33 E 2170,69 1702,59 E 2222,2~ 1749.55 E 2275,5~ 1799,0~ E 2330.45 MARATHON OIL TRADING BAY ALASKA BOSS SCRWEL COMPANY UNIT TRUE MEASURED VERTICAL DEPTH DEPTH SPERRY-SUN INC, RECCRO OF SURVEY SUB COURSE COURSE DOG-LEG SEA ...... i'N~LINATibN bi~Tt~N SEv TVD DEG MIN DEG MIN DEG/IO0 PAGE DATE OF SURVEY dANUARY 25~ lg80 VERTICAL SECTION DIRECiION N'GO-5/4-OO-E BOSS-1653/4 TOTAL -'RECTANGULAR C (~D YN)kT ['~ - NOR TH/SOUTH EAST/WEST SECTION 6000.00 5293.25 6100.00 5373./42 6200.00 6300:00 552,~.56 5187,05 36 0 5267.22 37 2~ 53/+5,92 38 /+7 5423.36 39 /43 6500,00 568q.17 6600,00 5762.01 6 7oo. 0'6 ........... 5~/4o./4 i ..... 6~00;00 5919o22 55oo.53 ~ i~ 5577,97 39 1/4 5655,81 38 32 573/+.21 38 12 5813.02 37 /+7 6900.00 7000.00 7100.00 72002-00 7300.00 6077.90 5971.70 6157.60 6237,7~ "6i31,53 6318.65 6212 37 30 37 12 37 7 36 ~ 35 36 7400.00 ..... ~gbd.i~ 7500,00 6/482,26 6376,06 7600,00 6565,09 6/+58,89 7700.00 664~3~" 7800.00 6731.76 6625,56 ~900.00 681'5,/+4 ..... 6709,2/+ 8000.00 6898.70 6792,50 8100.00 6~80,90 687/4,70 8200,00 7062,6~ 8300°00 71~/4o21 70~8o O1 ~5 fi 3/4 28 ~3 /40 33 31 33 32 35 2 35 i~ 35 22 N 6q /+8 E N 65 1E E 6J'66 5'~ N 66 1~ E N 66 18 E N'66 /+1 E N 66 18 E N 67 ~1 E N 67 /+8 E N 69 35 E N 70 1~ E N 70 5 E N 70 2/4 E -~--?d 35 E N 71 30 E 'N 68 N 68 0 E N 68 0 E N 68 ~/4 'E N 69 30 E 1.16 1603./+9 N 1,/43 1628,69 N 1,/47 165/+.07 N · 9/+ 1679.66 N --i~g '- ' 1705.18 N · 13 1730.51N · 70 1755,69 N .38 .... i7eo.4o N .48 180/+.95 N '14~ ....... idd9.25 N · 62. 1852,72 N · 11 1875.59 N 1,0/4 1918.97 N -';§9 ..... i938.84 N · 73 1958.18 N · 82 1977,12 N · I8 1995.59 N ,50 2013.53 N i.73 ..... 2032.19 N 1.58 2052,68 N ,63 207/4.01 N ,59 2095.17 N .35 2115.71 N -18--49,8/+ E .... 1902.16 E 1956,35 E ~-0i~.~? ~--' 207'0,/+ 3 E 2186,66 E 22/+4,16 E 2301.10 E 2357.55 E 24i-)258 E- 2~6g.52 E 2525,/+~ E 2635,77 E 2690.17 E 27~3.90 E 2796.61 E 2~48,77 2901,00 E 3003,89 E 3056.69 E 31i0227'!C- - 316~. 3/+ E ~8~6.9'J 250/4o~, _ 2~65.84 2628.81 2692.08 2755.02 2817,/47 2879,20 3oo1.i5 3061,/+0 3121,33 ~i-~.~' 3238.7/4 3295. ~ 3352,18 3/+07.35 3516,1P 3570.16 3625.02 3681./49 3738.55 3795.73 8/400.00 7225.Z~ 7i19.17 8500.00 7306.6~ 7200.A9 8600.00 73~8.7P 7282,58 8700,00 7/471,39 7365.19 8800.00 7554,33 7/4q8,13 36 35 '7 35 1 5/4 N ?d dE N 69 5/4 E N 69 /+8 E N 69 35 E ,80 2135.93 N 3219~'I5- 1.05 2155.88 N 3273,82 E 3910.80 · 50 2175.60 N 3327./+1 E 3967.17 · 57 ~-195,11 N 3380.28 £ 402~,79 · 17 221q./49 N 3~32.66 E /4077,9/4 __ MARATHON OIL COMPANY D-41 TRADING BAY UNIT ALASKA BOSS SURWEL - TRUE MEASURED VERTIC/~L DEPTH DEPTH SUB SE~ TVD .... -~-~t R-D ¥--. §U N iN-~; RECORD OF SURVEY COURSE COURSE DOG-LEG INtLiNAii6N ..... bi~ECYIdN- DEO MIN DEG MIN DEG/IO0 PAGE q[ DATE OF SURVEY JANUARY 259 1980 VERTICAL SECTION DI~£CTION N-~O-SA-OO-E BOSS-1653q TOTAL AE~TANGULAR C 001~ D I NA'TE'~~'*- VERTICAL NORTH/SOUTH EAST/WEST SECT ION 8900.00 '- 76.37~,20 7531,00 SO00.O0 7720.44 761A,24 9100.00 780A.17 7697.97 9200.00 7887.7~ 9300.'00 7971.25 7865.05 33 8 N 71 18 E 1.17 33 lO N 70 18 E ,55 33 12 N 71 5A E .63 2233.60 N 2251.91 N 3537.56 E 22~9.90 N 3589.20 E 42q1.~ 2288.15 N 36~+1-;03 £ ....... Z~295,5'~ 2305.68 N 369},13 E A3~9.58 9~dO.O0 8055.07 9500.00 81Z8.7~ 9600,00 8222,08 9700.00 8305,29 9800.00 8388.51 ~79~d.87 8032.53 8115.88 8199.09 8282,31 2359.19 N 38e8.7~ E ~5~t.38 2377,98 N - 39~0~93 E 456~.07 2396.62 N 3953,1~ E ~620.69 9900.06 847i.51 10000.00 855q.10 10100.00 8636.A7 1o20o.oo -- 8iis.~Z 10300,00 8799,66 -- 8365.3i 8447,90 8530,27 8612,23 8693.~6 2q14.68 N- - 4005.90 E 2A32.58 N 4059.38 E ~730.88 2~50.76 N ~113.08 E ~786.58 2~68.51 N 4i67.~5 E - '- 2485,95 N ~223.20 E ~899.77 i oAoo.bo ..... §d8-0.53 10500.00 8961.20 10600.00 9041.97 10700.~0 '--- 9id3.10 10800.00 920~.10 ~i7~+.33 8855.00 8935,77 9516.9d 9097.90 36 35 N 72 54 E .73 35 ~0 N 7~ 2~ E ~.27 35 56 N 74 0 E 2503.26 N 2520.5~ N ~335,92 E 501~.~3 2537.1~+ N ~392.~9 E 5072.3~ .... 2553.21 N --'4~48.~'-E~--512g;I~ ..... 2569.53 N ~505.03 E 5186.26 lO9OO.~ ..... 6Dd~28~- 11000,00 9365.E0 11100,00 9qq6,52 11200.00 9527.55 11300.00 9608.61 2585.79 N ...... ~5~ I;7~-E ..... 2602,2~ N 4618,51 E 5301.16 2618,75 N ~67~.75 E 5358.25 2635.A5 N -'-473-02'93- E-' 5~15.37 2652.76 N ~786.86 E 5~72.59 11500,00 9772,71 11600.00 9855,2q 9584,21 9666.51 9749,04 3A 39 .......... h-'-7~' 4i-'E-' .g~ 3A 3q N 70 35 E 1.20 3A 12 N 69 54, E .5q 2670.06 N ' A84[,-72-E --- 5528.R6 2687.95 N q895.62 E 5584,58 2707.0~ N ~9~8,76 E 56~0.25 MARATHOk OIL CCMPAkY D-A1 TRADING HAY UNiT ALASKA BOSS SURkEL _ - -'-SD~-~?-§UN INC. RECORD OF SURVEY PAGE ~ DATE CF SURVEY dANUARY 259 1980 VERTICAL SECTION DIRECTION N-60-5A-OO-E BOSS-1653A ** 1HE-aA-L~ULA~ioks ARE ~AS~D ~-h-TH~-"t~E'~diO~'[- oR-'AV~, FUNCTICk CF AN~L'£FM£t-HDD--~,~, .... HORIZONTAL DISPLACEMENT = 5640~77 FEET AT NORTH 61 DEG. 19 MINo EAST (TRUE) START OF SURVEY WAS 106,20 FEET ABOVE SEA LEVEL M~R~THON OIL COMPANY D-al ..... TP~FI~'G BAY UNIT ALASKA F3_ OSS _£U RVJEL._ TR_UE FE/~SURED VERTICAL DEPTH DEPTH SUB. SEA TVD P AGE '1 DATE OF SURVEY _.UAN_UARY ...... 25,m. l gSO -V--E-R1T~CAL SECTION DIRECTION N-GO-54-OD-E BOSS-1653~ SPERRY-SUN INC, RECORD OF SURVEY ..... C_D Ug.S£_ COUR $ E ..... O 0 G -L E G_ INCLINATICN DIRECTION SEV DEG MIN DEG MIN DEG/!OO TOTAL RECiA~LAR COORDINATES VER~'~ ~/~L NORTH/SOUTH EAST/WEST SECTION GO0,O0 599,P~0 .......... 79__0)_00 .......... 69 9 · 4 ~ 8CO.O0 799.19 9PC,O0 898,89 1600,00 15P2, ..... 17.0. ~., C_o .......... ! 6.7_5. IPDq. OO 1766, 1900,00 1856, -~06,20 -6,20 93,8_0 193.79 243.78 3q3,76 493,60 5q3,2.o. 692,99 792,69 R92.3q 991.68 090, ~4 188.25 12~5.32 07 1475,87 24 .... i569.0o 70 1660,50 40 1750,20 ORIGIN A1 SURFACE 30 S 9 0 E .50 .EL. 3]) .......... N__5_6__ 0 E ..... ..8~ ....... 45 N 9 0 E .55 34 N 46 0 W .63 2 0 ~ 3O ~ 25 ~ 25 510 8 0 S 76 0 E 2,51 S 66 0 E 2,55 .63__ _P_._E_ ,24 63 0 E ,08 S 63 0 E 0.00 S 76 0 E 1.32 N 76 0 E 4,20 .N _~.9_..O._E__. ..... ~_..~1 ....... N 45 0 E 2,16 N ~+5 0 E 2,32 · 03 N ,~3 E · 31_ S _L-_2~ E · ,61 N 1,82 E 1.70 N , 1,46 E 2.10 1,81 N 7.90 E 7,77 _. 1,57 S .19_,~_8] ......... 12,26 5,10 S 21,91 E 16.57 6.59 S 28,77 E 20,83 _ ~Lq_5 !2 45 15 4 11,52 S 48.06 E 36,16 ._ 4.00 ~ 62._._51._E 52..~.~__ 9.89 N 77.~0 E 72,26 26.89 N 94.40 E 95,42 '%'. E 69.71 N 137,22 E 153.76 i23,99 N 191.51 [ ~27,73 155,26 N 222,77 E 270,33 17 34 N 45 0 E 20 19 N 45 0 E ...... ~2__25 ............ N_~___5 ...... o E 25 10 N 45 0 E 27 19 N 45 0 E 2.75 2.10 2.75 2,15 PlO¢~.O 2290 2300.0 2qPO.O O 2029.76 1923. 0 ......... 211.~_-..~_9 ..... 20..~.8- 0 2198.R3 2092. 0 22R2.99 2176. 2.500,00 2600,00 ____~l ~n___O.,_~9___ Pt~O0.O0 84 30 15 N 44 0 E 56 31 45 N fi. 5 0 E 2 ~ ......... te.__25 ........... N_ _t~ __O __ E ....... 63 32 $~ N ~4 0 E 79 32 49 N 45 0 E 2366.91 2260,71 ~3 ~ N 45 0 E 33 34 N 45 0 E 34 4 N 45 0 E 34 30 N 46 0 E 34 ~4, N 46 0 E ._2._5. 3.~ · 5.6_ .... 2~_2~ ,36 26i6,19 2509.99 1.59 ,15 ,60 ...... id9'~,-{~- N 256,52 E Z16.60 226,34 N 292.62 E 366.10 264,22 N ......... ;;}_2.9, 5~_~E_ .....5)7,15 302,86 N 367,17 E ~68,6~ 3q1.59 N A05.02 E 520,55 · 25 ~-~f~-~-8-~ N q4~,47 E 572,94 · 50 41P.,68 N 482,31 E 625,~6 .50 458,03 N 521.67 E 679.48 · 71 ~97,51 N 561.8~ [ 733.88 · 23 536,97 N 60~,71 E 7RS.R7 ........................ _TRUE .... __SUB PEASURED VERTICAL SEA DEPTH DEPTH TVD 3 SPERRY-SUN INC, RECCRD OF SURVEY _C_C.U_E_,SE_ ...... co u R_s~_ .... DOG-LEG_ INCLINAT ICH DIRECTION SEV DEG MIN DEG MIN DEG/1DO O00.OO 2780.75 2674.55 34 34 N 47 0 E 100.00 2863.02 2756.82 34 43 N 47 30 E 2 O0 ~O.D ........ 2950-2 4 ..... 2 839., 0 4 ......... 34__9i ........ .N___9_6__.~.2. [ ....... 3eO,O0 3027,~5 2921,25 ~ ~3 N ~7 5 E AOg,O0 3109.72 3003.52 ~ 34 N 46 54 E PAGE DATE OF SURVEY_ ,JANbARY 25~ 1980 _ VERTICAL SECTION DIRECTION N-GC-5A-OO-E BOSS _-16534__ TOTAL RECTAi[GULAR COORDINATES VERTICAL NOR TH/SOUTH EAST/WEST SECTIOt. I · 32 61A,70 N 685,69 ,46 ..... 653,45 N 72_7_j~ 9 · 22 692.35 N 768.96 · 18 731.12 N R.1 0,53 84Ao03 899~ 1010,04 1065,30 350 n,0o .'5192,31 3086,11 3~. 5 N 47 30 E O,DO ,5275,07 3168,87 34 12 N AG 47 E Q,O0 ....... _3357.67 ..... 3251 ._.47~ n.co. 34q0.~.~7 3334.17 3~ 0 N ~7 30 E 0,00 3523.37 3~17,17 33 q9 N ~7 30 E .42 807,61 N 893.04 E · 66 884.58 N 975.20 E · 18 922.27 N 1016.33 E 1120.17 117~,77 1229,_~9 _ 12.~ 4, 16 1338,5] A 100,00 3689,52. 3583,32 33 ...... _~2~_0 ._..0 0_ ___ ~772.93. _._~.666_.__7_~ ..... ~~... q3nO,O0 3856,58 3750,38 33 23 AAOP,O0 39A0,23 3834,03 33 ~TeP,OO .... 4!~1,56 A D.85,36 4R~O,OO 4275.75 A169.55 4909,00 4360,26 425q, 06 N 47 54 E ,23 959,71 N 1057,48 N ~7 17 E ,36 997,26 N 1098,60 ..... _N_~Z_~______....8.~ ..... 1.034.65 _N _ _1_139_.1_LE N q7 47 E ,38 1~71,60 N 1179.63 N ~7 17 E ,~2 110~,59 N 1220,06 N' ~7 17 E ,25 11~5,72 N 3.:3 4 N q7 24 E .26 1182.8,1 N 32 35 N ~7 54 E .56 1256.28 N 32 4 N 47 q2 [ .53 1292.20 N -- - 1392.75 1447,02 1554,13 1607.52 1260.~8 E 166, 1300.54 E 1714,11 ! 19 0_~__L___1_7_6_6 ,_9_5 __ 1380.09 E 1819.50 1419.70 E 1871,66. 5000,00 4444,81 5100,00 /+529,62 ~2FO.OO q65R, 19 F300.O0 4701.87 /+338,61 $;~ 29 N /+6 ~2 E ,68 ....... i-~)28o48 N ~ 5_ ~ 8. · ~ 7 ......... 3~6 ...... N_ .~._~ 5_ ~ .... .,_~ ~ ..... 14 0 0 · 1 ~__ N ...... ~551,99 ~9 A3 N 50 5~ E ~,3~ 1416.67 N 4595.67 28 32 N 57 12 E 6,57 1~30.96 N 5~00.00 4789.28 4683.08 55~'P.00 ~875.88 4769.68 ~7Pn. O0 50~6.16 ~939.96 ~PO0,OO 5129.68 5023.48 1615,75 E 2123-11 1659.1~ E 2173,13 17__09_, A O__E _ _ _ 2224.72_ 1751,67 E 2277,98 1~00.86 E 2332.90 F~R/~THON OIL COMPANY TPADING hAY UNIT ALASKA T_B_UE_ ............ SUB .... MEASURED VERTICAL SEA DEPTH DEPTH TVD PAGE DATE OF_ SURVEy .... d~AN__L._AR~.Y_ 25, 19~0 ~k-R-T-~-CAL SECTION DIRECTION N-60-Sz+'OO'E · BOSS-1653~+ SPERRY-SUN INC. RECCRD OF SURVEY C~UB [[ ..... C DU ES L .... DDG_-_LE$_ INCLINATICN DIRECT ION SEV DEG MIN CEG MIN D£G/li)O T.O_T Al RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECT I('IN 590C.00 5212,13 5105.93 '3q 56 6000.00 5293,57 5187.37 36 0 ._____~,_CL O_ .~5 ~3_, 75 ..... ~ 2 ~7_.~ ........ _37_. 2 q 620Q.00 5q52.~5 53~6.25 38 ~7 6300.00 5529.89 5~23.69 39 ~3 N 6q q8 E 1.16 J~__6_5_! t[___l .._9:3 N 66 5 E 1,q7 N 66 11 E .gA 640P,00 5607,06 5500,86 39 6500,00 568~.50 5578.30 39 lq ~TOP.O0 5~0.75 573~.55 38 12 6~OP.O0 5919,56 5813.36 37 ~7 N 66 30 E N 66 18 E ,13 tit-6.6--ZL£ _,_7_/1 N 66 ql E N 66 18 E 6900.00 5998.7q 5892.5q 37 30 700.0.00 6078.2q 5972. Oq' 37 12 ..... 7~.O.OO 6L57_, 9~ ...... 6_051.,._7_~} ......... 720n,00 623e,07 6131,87 36 22 73P~.00 6318.99 6212,79 35 36 N 66 ~+B E N 67 ql E .62 ~_ 6_~7.__/+__B_ E_ ......... ,_Li. .... N 68 2~ E N 69 .'55 E 1.0~ 7POP,O0 6815.79 ~-:'/-?J9,5~ 32 51 N 6S 35 E POOO.O0 6899,06 6792,86 3~ 2~ N 68 0 E P20C.O0 7062.99 6956.79 35 19 N 68 5q E 830P.00 71qq.56 7038.36 35 22 N 69 30 g 1580,18 N 1851,66 E 1605,25 N 1903,98 E 16 3_0 · .q_ 6_ N .... 195_8~LT..._E~ 1655,86 N 201~,39 E 2568,31 1681.q5 N 20,72.26 E 2631,28 1706.97 N 2130.51 [ 269q.55 1732.30 N 2188.~9 E 2757.q9 1_15 Z. g.8_ I;L .~_22~ 5, 9_9__F.~ _ 2 819 · ~__. 1782.18 N 2302.93 E 2R81.67 1806.73 N 2359.38 E 29~2,89 1~31.0~+ N 2qlS,ql J[ 3003.63 185q,50 N 2q71.35 E $065.8P. 1_67_7.38 _.N 252 Z, 2~6___E ..... 312..~_._RO_. 1899.69 N 2582.76 E 3183.10 1920.75 N 2637.61 E 32ql.22 , .,.~m~j_.~ ~ 1959,96 N 27q5.7g) E 335~,66 1971~,89 N .27.98,.~6 .E. 1997,-97 N 2850,61 E 3~6~.36 2015,31 N 2902.85 E 3518.~7 1.73 ~.6~3,99 N 2954.,31 E 3572,66 1,58 205A,q. 7 N 3005,76 E 3627.53 ,6~ ...... 2075, 80__N ~&/&~E .... ~6~A, DO__ ,59 2096,96 N 5112,1~ E .35 2117.51 N 3166e22 E 3798.25 1.05 ,50 ,57 .17 2i-3i,72 N 3221,02 E 31~55.91 2157,68 N 3275.69 [ 3913.37 2177,q0 N 3329.29 E 3969.69 2196,91 N 3382,15 E ~325,31 2216.29 N 3q3A.54 E qOSO.a6 ~RATHON CIL COMPANY TFADIP;6 RAY UNIT AL A.e !<., A ...... E_O_S S__2 UR,¢ EL MFASURED VERTICAL SEA INCLINAT ICN DIRECTION SEV DEPTH DEPTH TVD DEG PIN DEG MIN DEG/IOO SPERRY-SUN INC. RECCRD OF SURVEY _...T]~_U. E ........... S_ U_B ..... _C.O_U R_SE ...... C O_U_B_$ E ...... D_O {~ _'_L.E G ....... T °@0~,00 7720,81 761q,61 33 8 N 71 18 E 1,17 ........... ~ ! ~ c ,_ 0_0___78.0_~_, 5_3. ___? 69 8, 33 ......... ~ ! 0 ...... N.._ZO_._t.q _E__ __,_5_5 9200.00 7888.08 7781.8R 33 30 N 70 54 E .47 930d.00 7971.61 7865.ql 33 12 N 71 54. E .... ~_0 60..0..,_ 0.0______?,_Q.5_.2__, 35 893_6..15 10700,00 9123.48 q017,28 lOP('n. O0 920A..q8 9098.28 N 71 24 E N 70 41 E P&GE GATE__OF_ _.~U RVEY _ ,_dAN UARY _25 ~ _1980 VERTICAL SECTION DIRECTION N-~O-54-OO-E _. O.T_AI, RLCTANGULAR NORTH/SOUTH 2253,71 N 22_7_1.6~_N ____._ 2289,95 N 2307.48 N 2324.65 N 2342.44 N 1090r'.C0 llPCO.O0 _lllPn, o0 11200.00 1130n.oo IlqPO. O0 tiLl_O_ _5 ._E ...... t;~ ~ ...... 2~60 · ~)8_N__ _ _ N 70 lB E .28 2379.78 N N ?0 E N 3~ 22 N 71 11 E , .35 2~3~.38 N ~~ .......... _R. 71.2.~.~. ........,..~.7. ......... 2q52.57 N ~5 11 N 72 ~0 E ,7~ 2~70,32 N 36 11 N 72 Al E 1.01 2q87,77 N 35 52 N 73 5 E .39 2505.0-7 N 36 35 N 72 5~ E .73 2522.35 N COORDINATES VE~-TICAL EAST/UEST SECTION 3746,79 E 4q05,62 3798,58 E ~59-47 _385D~__ _ t 513.91__ 3902.82 E 4568.60 3955,03 E q623.22 4 007.80 4061.27 E q73 ~ 11_~_._~8_E~.~) 7 ~ 4169.45 E 484 4225.11 E 490 4281.32 E 495 4337.83 E 5017 11500.00 609,_o. 0 9285.23 9179.03 9365,88 9259,68 q527.93 9~+21.73 960Ro99 9502.79 9690.79 958~.59 9773.10 9666,90 9855.',G2 97~9,,,4 2 t 5.,_.~0_ .N_ 7_~_2.9._ r.._ ..... ;!.__,.22 ..... 2538.95 N 35 5;3 N 73 4! E .~7 2555.02 N 35 56 N 74 0 E ,ig 2571.3q N q450.61 E 5131 '~506.94 E 51R8 36 22 N 74 0 E 36 7 N 73 41 E .31 _5__~.9_.. .... _N__?..3_.3..5__E ..... _, 4 7___ 36 6 N 73 18 E 35 35 N 72 1P E .78 2587.60 N 4563.65 E 52~16 2604.05 N Q, 620.43 E 5303 262_0,5_6__.N ....... ~.67_6_,67 :E. .~ 5.360 2637.25 N 4732.8~ E 5~17 265~.57 N ~788.78 E 5075 3~ 3-9 N 72 41 E 34 34 N 70 .35 E 1.20 2671.87 N *18~3-64 E 268.0.76 N 4897.5A E 27o~,~5 N ..... ._4 9_5_ O · 6_9__r,. 5531 5587 56~2 3.42 9,12 _ 5,27 2.32 '. ,7 .81 .72 · 80 __ .15 ,~2 .16 .82 MAFA THON TFADING ALASKA EO g_S._S U.R W. EL OIL COMPANY P, AY UN IT ~ATE _.OF SURVEy_ ................. V~-~-TICAL SECTION DIRECTION N-GO-5A-OO-E SPERRY-SUN INCo B 0 SS~-__IG5 3~ RECORD OF SURVEY ** THE CALCULATIONS ARE BASED ON THE AVERAGE ANGLE ~E-TH~-** START OF SURVEY i~AS 106,,20 FEET ABOVE SEA LEVEL MARATPON OIL COMPAKY D-q1 ~R~Oi~G-BA~ bkii - ALASKA BOSS SURWEL TRUE SUB MEASURED DEPTH DEPTH TVD PAGE 1. DATE OF SURVEY JANUARY 25e 1980 VE~TYCAL S ECTI ON-D II~ECTION-N;~D-5A-D O-E SPERRY-SUN INC. RECCRD OF SURVEY COURSE COURSE DOG-LEG TOTAL DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST BOSS-16534 SECTION .... d. O0- ........ -0-,'~ ....... '32106,20 100.00 100.00 -6.20 200,00 199.99 9S.79 ~ 0 I~2'0 0 ......29§'~9~-" ' 193,78 ~00..00 399,98 293.78 5'dd~-~o ...... ~+99.92 393.72 Goo,oo 599,61 A93,A1 700,00 699.30 593,10 900.00 Bc~8,71 792.51 ORIGIN AT 'SU~DACE O.OO N .... 0'00 ~ 0 30 S 9 0 E .50 .86 S .1~ E 0 30 N 56 0 E .8~ ,37 S .86 E 0 W5 N 9 0 E .55 .98-'N .... 1',--06-E 0 34 N ~6 0 W ,63 1.61 N .35 E 2 0 S 76--~-~ ..... ~.5! o?~ N 3,74 E 4 30 S 66 0 E 2,55 2,43 S 10,91 E 4 30 S 63 0 E ,2~ 5.99 S 17,90 E 4 25 S 63 0 E 0,00 12,98 S 31,62 E 8.30 12.6~t 1628g - ' 21.15 1000,00 998.30 1100.00 1097.33 1200,00 1195,57 i3~0-d 2 b ~'-----1~-~-3 . i 1 lqO0.O0 1389.~7 ~ i'~Ob-.6o ..... i-4d'5-20'i .... i378.di 17 3~ 1600,00 1578.79 1/+72.59 20 19 1700.00 1671.23 1565,03 22 25 fsbbiob 1'~61.7q 1655.54 - ~2-~-~0 1900.00 1850.58 1744.38 27 19 2100.00 2022,00 1915.80 31 ~5 2200.00 2106.4~ 2000,22 32 25 .... 230b,00 ...... ~i~d'2'~O ...... 20~-~.50 32 3~ 2~00.00 p27~.7n 2[~8.5~ 32 ~9 11.80 $ 53,86 E' ,AA N 67,9q E 1~/05 N 3q.t+3 N 101.93 E ~5.77 N ........ 123,27 E 80,32 N 147,82 E 107,29 N 17A,78 E 1-37.3'6~'N 20~;85 E 16~.81 N 237.30 E ~06;O~-N 272.30'E 2~3,25 N 309,51 E 281.81 N 346,75 E 358.86 N ~22.~6 E ~1,10 59,37 '.-B O-;g4 - 105.68 168,_. 204,95 290.13 3TSTzF3-'-- 389,12 ~0,51 · 92.I] .... 5~,33 2500.00 2358.b~- .... }~23~" 33 . 2600.00 2A~1.87 2335.67 33 3~ 2700.00 2524.70 2'~ 18.50 3~ ~ 2POO,bO 2607.12 .... 2500.92 3q ~0 "" 2900.00 2689.30 25S3.10 3A A~ 650,16 70~.13 81~,11 MARATHON OIL COMPANY D-ql TRACikG BA~ Ukli' -' ALASKA BOSS SURWFL TRUE MEASUREC VERTICAL DEFTF DEPTH SUB SEA TVD PAGE 2' DATE OF SURVEY JANUARY 25~ 1980 VERTICAL ~C'~ON DIRECtiON N-60-Sq-OO-E SPERRY-SUN INC. RECORD OF SURVEY COURSE COURSE DOG-LEG TOTAL I~CLINATION DIRECTION SEV'~ RECTanGULAR .... ~O'RDINATES DEG FIN DEG MIN DEG/100 NORTH/SOUTH EAST/WEST BOSS-16534 VERTICAL SECTIO& 3000,00 2771,6= 2665,45 3100,00 2853,8'r+ 2747.64 3200.00 2936.07 2829.87 3300.00 3018.~i-- 291~.di 3~00;00 3100.62 299~.~2 N 47 0 E ,59 593.76 N 662.97 N 47 30 E .32 632.2/+ N 704.96 N ~6 ~2 E ,46 671.26 N 7~6,37 N a7 5 E .~- ..... 7[d.o~N---- 788,09 N 46 5q E .18 748.81 N 82,9.51 869,27 980.C 1035,39 1090,53 3500,00 3183,44 ~6oo.oo ~266.~5 3900.00 ~51~.~ 3077.2/+ 34 5 3242./+Q 3~ 25 3325.35 3/+ 0 3~08,43 33 49 N /+7 30 E ,59 -786.67-N 870.83 E N ~6 ~7 E .e2 825,15 N 911.80 E N-.~6 35 E ,24 863,99 N 952.86 E N~4:~'-'$~ C .66 9bl;iY--h- 99~,08 g N ~7 30 E ,18 939.37 N 1035,12 E 11~5.12 1199.72 1254,58 1~'0 ~); 05 1363,27 4000.00 3597.74 3491.54 3~ 47 qlO0.O0 3680.75 3574.55 33 5~ ~00.00 3931.8E 3825,65 33 q N 47 17 E .36 1014,/+8 N 1117,36 E N 47 2~ E ,8~ 1051,~1 N 1157,52 E N ~7 ~7 E .38 ~*i-d~8,38 h 1198.28 E N 47 17 E .42 1125.39 N 1471,82 1524,95 15~-~. 62 1238,37 E 1631,73 4600.00 4099.22 4700,00 q183.34 /+800,00 4900.0O 3993,02 33 ~077.1~ 32 /+267,60 q1~,40 ....... 32 35-- ~521,96 /+~15.76 4607.59 /+501,39 4694.94 4588.74 28 32 5000,00 5100,00 5200.00 - 5.300.00 32 31 30 31 6 N ~7 17 E N ~7 2/+ E N 46 5/+ E ,25 1162,6~ N N 47 5~ E N q7 42 E · 26 1199,58 N · q3 1236,52 N --.Sr~ 1272,63 N · 53 1308,36 N {~ ~6'~ N 46 42 E N /+7 35 E N 50 54 E .61 N 57 12 E 6.57 1278.73 E 1685~''-- 1318.89 E 1738,J3 1358.37 E 1790,87 1398,33 E 18~3,42 1~37,60 E 1895,18 ls45.1-~"-N i476,68 E 1947233 .... 1381.02 N 1514,71 E 1998.06 1415,86 N 1552.8/+ E 20/+8./+0 lq$1.~'~--'~- ..... --~-572.08 E 2072,~ 5400,00 5500.00 5600,00 .... ~7o0.-oo 5800°00 N 60 47 E 1.07 N 61 47 E 1.3~ ..... N ~3-"1~' ~--" 1 N 63 42 E 1,31 147: ~; 41- N t-&-~'~.-'?'l--K--21-~.-~ 14~q,14 N 1678,9~ E 2196.70 1518,97 N 1725,23 E 22~9.21 1568.11 N 1823,60 E 2359,03 MARATHCk 0IL CCFPA~Y D-~1 TRADING BAY UNIT ALASKA BOSS SURWEL TRUE SUB MEASURED VERTICAL SEA DEPTH DEPTH TVD SPERRY-SUN INC. RECORD OF SURVEY PACE 3' DATE OF SURVEY JANUARY 25, 1980 VER~'i~AL ~ECT~O~ BOSS-1653q COURSE INCLINATION COURSE D IRE[T I ON DEG MIN DEG MIN DOG-LEG TOTAL '/;i~V ......~ECT~~ - - CO0-RD-IN-KTES'--- VERTICAL DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 5900.00 5202.2=-. 5096;05 6000.00 5283.15 5176.95 6100.00 5362.59 5256.39 6300.'00 5517.q6 5~11.26 6~00.00 559~.88 5~88.68 6500.00 5672.3~ 5566.1~ 6600,00 5750,56 564~.36 6700,00 5829,15 5722.95 6800,00 5908,18 5801.98 36 0 37 2q 38 4.7 39 q3 - 39 i6 39 1~ 58 12 37 "+7 N 64 0-'£ ;gH ...... N 64.'~8 E 1.16 N 65 18 E 1,q3 N 66 5-E ......!-;47 .... N 66 11 E .94. N 66 30 E N 66 18 E N 66 2~ E N/66 ~1 E N 66 18 E 6900.00 5987.5P 7000.00 6067.17 5960,97 7100,00 61q6,91 60q0,71 7200.00 6227.q~ 6121.2~ 7300.00 6308.75 6202.55 37 12 37 7 36 22 35 36 l!j"J'3,-;-2Y 'N 18?5,07 E 1618.2~ N 1928.25 E 24.7~.8~ 16A3.62 N 1983.q$ E 2535.~ 169~.80 N 209}.16 E 2661.27 7qO0,O0 7500,00 7600,00 6390.A8 628q.28 6Q72,92 6366.72 6556.15 6449.95 35 11 31} 28 33 qO · 13 17~5.~6 N 2215,11 E 2787,15 ,70 1770.4.0 N 2272.20 E 28~9.12 · ~8 17~q.8~ N 2328.~~'-~9[~.60 ,~8 1819.50 N 2385.09 E 2971,56 N 66 48'E ,{'~ ..... fH~24~'--N N 67 ql E .62 1866.q3 N N 67 ~8 E .11 1889.2q N N 68 2q.E --2~3 ....... i¢ii;O~-N N 69 35 E 1,0~ 1931.36 N N 70 5 E I~ 70 2~ E ----,B9 1950.79 N · 73 1970,06 N · 82 1988.66 N 2~A 1 · 05 E, '----TU-3[;-OT ..... 2~96.98 E 3092.06 2552,85 E 3151.92 ---l-slY? ;'~)li --E~32 I'0-; g ~ --- 2662.5~ E 3268.15 2770.00 E 3380.,q 2822.22 E 3~35.36 7800,00 790'o.oo 8000.00 8100.00 8200,00 8300,00 6722.88 6616,68 33 32 N T~E N 71 30 E ,50 68o6~.89 6889,4.0 6971,28 713~,43 6783.20 34 2q 6865,08 35 2 ...... 69q6,68 35 19 7028.23 35 22 N--C6-35--['------1-;-'/'$ .... 2 N 68 0 E 1,58 2 N 68 0 E , .63 2 N 68 54. E ,,.5~ ~ N 69 30 E .35 2 ~0'07;01' N ..... 287~,30 E - -"3'-4~'3"~' 202~',53 N 2926,69 E 35~.3,97 0~;$~ ~--' 2977,i9'E S5~7.67 065.50 N 3029.57 E 3653.69 087.00 N 3082.80 E 3710,61 128.09 N 3190.95 E 382~.98 8qO0 8500 8600 8700 8800 o00 .00 ,00 .00 72e~7.o6 754.5.28 '--?'i 09 · OY 36 ? 7190,86 35 q 7273,19 3q 35 ?5-5-6.07' -- 34-- 1 74.39,08 33 54. N 69 54. E 1.05 N 69 ~1 E ,50 .... N ~;c1-'48 E -" ;57 N 69 35 E ,17 2167,99 N 3300.29 E 3939.81 2187,69 N 3353.52 E 399~.85 2207.01 N - 3~0~.0'2-E~ - ~051,0~-- 2226.4.6 N 3q58,30 E 4.106,14 MARATFON OIL CCMPAkY 0-~1 - 'TRAO'iN~ B~Y UNIT ALASKA BOSS SURWEL TPUE SUB C DEPTH DEPTH TVD D 9000.00 7711.76 9100.00 7755./+6 9200.00 7878.85 9300..00 · 97 98 SPERRY RECORD OF S OURSE COURSE LINATION --~RECi~ EG MIN DEG MI ' PAGE /+ CATE CF SURVEY dANUARY 25e 1980 VERTICAL ~C'~[dN OY~CTION N-60-54-OO-E SuN jiQ~; - URVEY ON SEV 7521,82 3~ 10 N ?0 18 E 7605.56 33 8 N 7! 18 E 7689,26 33 10 N 70 18 E --777~2~ ..... ~-'~0 N 70 5~'£ BOS_S -. 1653~ 7~62.53 7856.33 33 12 ' TOTAL DEG/IO0 NORTH/SOUTH EAST/WEST SECTION !.~8' 22'~5;39 N ~51i,I? E--~l&i;49 1.17 22~2.91 N 3562.9~ E 4215.19 · 55 2281.~6 N 9~00.00 80/+6.~9 79/+0.~-~- .... 32 5~ 9500.00 8129.86 8023.66 33 31 9600.00 8213.19 8106.99 33 3/+ 00.00 8379.G~ 8273.~Q 33 31 N 71 5~ E N 71 2A. E N 70 /41 E N 70 5 E N'.70 18 E N/70 2q, E · 63 2316.~3 N 3718.65 E A377.08 · ~1 -' 2333.75 N 3770.13 · 73 2352.01N 3822.2~ E ~q8~.78 · 3~ 2370.8~ N 387~.23 E ~539.31 · 28 2389.60 N 3926.63 E q594.15 · 31 , 2~08.13 N 3978.6~ E -990-0.00 8/462.27 8356.{J;'7 ........ ~2+' !7 N 7i ~8 ~ 10000,00 85q./4,81 8q38,61 3q 22 N 71 11 E 10100.00 8627,01 8520.81 3q q3 N 71 2~ E -10200.00 .......... ~8-.'~ ......... ~'O~.~q 35 11 N 72 30 E 10300,00 8789,A6 8683.26 36 1[ N 72 ql E iOAO0,O0 10500.00 10600.00 ---i07o0-.oo 10800.00 8870.q9 876/+.29 251/4.02 N /4306,9q E ~986,~,~ 2531,5q N q363,90 E 50q/4. 25q7,22 N /4/420.06 E 5101.~1 2579.86 N q532,73 E 5215,~6 10900.00 11000.00 11100,00 li2oo.ob 1130O°00 9355,33 92/49.13 36 7 N 73 ~1 E 9q~6.59 9330.39 35 39 N 73 35 E 951~.~'~ ....... ~411.19- 36 .... 6' N 73 1~ [ 9598,72 9~92,5~ 35 35 ~ 7~ 18 [ 11 11 11 ~00.00 500,00 600.00 N 70 35 E 1,20 N 69 5/4 E MAR~TFO~ OIL CCNPA~Y D-e! TRADING BAY UNIT ALASKA BOSS SURWEL SPEt~ Y-SUN INC. RECORD OF SURVEY ? PAGE DATE OF SURVEY dANUARY 25e [980 BOSS-[655~ .................... ;~--¥'~E C/~[~ULATIONS ARE BASED ON THE TANGENTIAL OR'~E~'~i~kJL-~[4~[-£'-[ME'-IrRg)-D ** HORIZONTAL DISPLACEMENT = 5669.19 FEET AT NORTH 61 DEG. 20 MIN. EAST (TRUE) START OF SURVEY WAS 106,20 FEET ABOVE SEA LEVEL MARATFOK O]L CCFPA~Y D-al TRADING DAY UNIT ALASKA BOSS SURWEL 3.RUE. MEASURED VERTICAL DEPTH DEPTH 0,00 0.00 100.00 100,00 ..... 200,00 __ 199,99 300.00 299.99 400,bo 399,98 500400 499.95 600,00 599,76 ...... 7.00,.00 ....... 699,46 800,00 799,15 900,00 898.86 SUB .... SEA TVD -106.20 ORIGI~ -6.20 0 30 __ 93~79 ....... 0 130 193,79 0 45 293,78 0 34 1000,0 1100,0 .... 1200,_Q 1300o0 1400.0 SPERRY-SUN INC. RECORD OF SURVEY COPB$E_ ..... ~OU~S[ .~ _DOG. LEG -~NCLINATION DIRECTION SEV DEG MIN DEG MIN DEG/IO0 AT SURFACE S 9 0 E _ N 56_. D_E ...... · N 9 0 E · N z~6 0 W 150 160 17_0 180 190 393.75 2.:...0 493,56 4 30 __593.26 __ 692,95 q 25 792,66 4 25 S 76 0 E 2, S 66 0 E 2. S.'6.3_ _O_L ..... · S' 3~ 0 E · S 63 0 E O, 2O 21 22 0 998,50 892,30 0 1097,86 991,66 0_~.j196,56 ...... 1090,36 0 1294,45 1188,25 0 1391,50 1285.30 25 26 ...... 27 28 0.00 1582.02 1475.82 20 19 0.00 1766.63 1660.43 25 10 o.oo 185 . 1 1750. 1 27 PAGE I ' _ _. DATE OF _SURVEY ..... JANUARY 25, 1_980 VERTICAL SECTION DIRECTION N-60-54-OO-E 00,00 1943,94 1837,74 00,00 2029,65 1923.45 OO,O0 .... 2114,38 ...... 2008,18 00,00 2198.72 2092.52 O0.O0 2282.88 2176.68 NORTH/SOUT 00,00 00,00 00,00 ....... 00,00 nn.nn 2450,37 2344,17 2533.45 ___~ 2427.25 2616.08 2509.88 PAgR.37 2592.17 __E 0 S S-.16 TOTAL_ __ R COORDINATES VERTIC'~L- ' ' H EAST/WEST SECTION 0,00 N 50 .43 S 84 ......... ,62 $ 55 ,27 N 63 1,26 N 0.00 E ,07 E ...... · 96 E ,,71 E 51 1,18 N 55 ,83 S 2) ....... 4,21 S 08 7,74 S O0 11,24 S 2,05 E 7.32 E ....... I~;~O...E ...... 21,33 E 28.19 E 1,32 14,07 S 35,g9 E. 4,20 15,48 S 47,12 E _5._11 .............. 5,67_S 2.16 8,25 N 75,76 E 2.~2 25,24 N 92,75 E N 45 o E 2.50 E 45 0 E 2.75 N 45 0 E 2,75 N 45 0 E 2.15 30 15 N 44 0 E 31 a5 N 45 0 E ..... 32 25 ..N_4__4. O. E ....... 32 34 N 44 0 E 32 49 N 45 0 E 34 30 N 46 0 E 34 44 N 46 0 E 45.10 N 68.06 N 93.81 N 122.34 N 153.60 N 112,61 E 135,56 E .... 16.1~_I~__ E ..... 189.84 E 221,10 E 1.59 224,67 N ~85 ........ 262,56 N · 15 301.20 N · 60 339.72 N 254,83 290,93 _ 32 8,_! 365.47 405.33 · 2~ .........~i8' 17 N · 50 417,01 N · 50 456,36 N ,71 495.84 N ,23 535.30 N 441,78 E 480,62 E 519,97 E 560,15 E 601,01E 0.00 ,97 2,36 5,97 14.76 19.02 2*,.42 34°39 _5_0,25~ 70,02 93.17 151,~d .186,60 225.46 268,05 31.,,32 363.81 _i.l_~ · 86___ 466.35 518,26 570,65 623,57 67~,19 731.58 786,57 MAR~T~OK OIL CCMPAkY D-41 TRADING HAY UNIT ALASKA BOSS SURWEL. TRUE SUB MEASLRED VERTICAL SEA DEPTH DEPTH TVD 3000.00 2780,64 2674,44 3100,00 2862,91 2756.71 3200..00 _ _ 2545,12._~ 2838.92 3300.00 3027.34 2921.14 3400.00 3109.61 3003.41 3500.00 3192,20 3086,00 3600,00 3274.96 3168.76 3700,00 ........ 3357., 5£... 3251.36 3800.00 3440.26 3334.06 3900.00 3523.25 3417.05 PAGE DATE CF SURVEY UANUARY 25~ 1980 vERTICAL SECTION DIRECTION N-60-54-OO-E SPERRY-SUN INC. RECORD OF SURVEY CCUPSE .... COURSE INCLINATION DIRECTION DEG MIN DEG MIN 34 34 N 47 0 E 34 43 N 47 30 E 34 43 N 47 5 E 34 34 N AG 54 E 34 5 N 47 30 E 34 12 N A6 47 E 34 0 N .b7 30 E 33 49 N A7 30 E BOSS-16534 DOG-LEG ..... TOTAL SEV RECTANGULAR COORDINATES VERTICAL DEG/IO0 NORTH/SOUTH EAST/WEST SECTIO& · 32 613,02 N 684,00 E ._,!6 651.77 N ..... 725,10__E ....... 952,~ · 22 650,67 N 767,26 E 1007,74 · 18 729.45 N 80Q.83 E 1063,00 ,42 805,93 N 891,3~ E 1172,46 ._,24 844,59 N ..... 9.52,~6_E__ 1227,19 · 66 8~2.90 N 973,50 E 1281,85 ,18 920,59 N 101~,63 E 1336.20 4000.00 3606.35 3500,15 4100.00 3689.41 3583.21 4200.00. ~772.81 3666,61 4300.00 3656.47 3750.27 4400.00 3940.12 3~33.92 33 47 N 47 54 E 33 54 N 47 17 E ~4 N 47 24 E 33 23 N 47 47 E 33 4 N 47 17 E · 23 958.03 N 1055,78 E i~.4~ · · 36 995,59 N 1096.90 E 1444,71 · 8~ ..... 10~2,97 N 11~7,~7_E. __1~98,42 · 38 1069.92 N 1177.93 E 1551.82 · 42 1106.91 N 1218,35 E 1605.21 4500,00 4023.80 4600,00 4107,49 4700.00 .... 4191,4~ 4800.00 4275.64 4~00.00 4360.14 3917.60 33 19 N {7 17 E .25 ~'144.04 4001.29 33 4 N 47 24 E ,26 1181,13 4085,25 3~A4 k 46_54.E_ .,q3 ...... 1218,07 ~169.44 32 35 K 47 54 E ,56 1254,60 4253.94 32 4 N 47 42 E ,53 1290.51 N 1298,84 E 1711,mu N 13_38,66_ [ .... 1764,64 N 1~78,38 E 1817,1~ N 1~17,99 E 186~,34 5000,00 4444.69 5100,00 ~529.50 5200.00 4614,94 5250.00 4658.06 5300.00 ~701.75 ~336.49 32 29 N 46 42 E .68 i326.80 N 4423.30 31 30 N 46 42 E ,98 1363.13 N .. 4508,74 31 __6 K _47 35._E ,61 _ 1398,46 N 4551.86 29 43 N 50 5q E 4.34 1414.99 N 4595.55 28 32 k 57 12 E 6.57 lq2g.28 N 1457,17 E 1{P1.30- 1~95,7~ E 1972,7~ 1533.81 E_ 2023,27 1552.96 E 2048.07 1572,62 E 2072.22 5400,00 4789.17 5500.00 4875,76 5600,00 4961,41 5700.00 5046.03 5FO0.O0 5129.55 so N: :.o: N 4S39.8] }2 43 63 12 E 1. 8 1528.94 N 1657,37 E ~170,74 1702,63 E 2222,3~ 1749.89 E 2275.5P 1799,08 E 2330.50 MARATHON OIL D-41 TRACIKG DAY ALASKA EOSS SURWEL_ COMPANY UhIT MEASUREC DEPTE TRUE SUB VERTICAL SEA DEFTP TVD 5qo0.oo 5211.99 5105.79 6000.00 5293.43 5187.23 6100,00 5373.60 5267,q0 6200.00 5452.30 2346.10 6300.00 b52~,74 5423.54 6400.00 6500.00 6600,00 6700,00 6800.00 6900,00 7000,00 7100,00 7200.00 7300.00 7400.00 7500,00 Y600,O0 .. 7700.00 7~00.00 7PO0.O0 ~000,00 8100,00_ 8200.00 8300.00 - . 5606.91 5500.71 5684.35 5578.15 5762.19 5655.99 5840.59 5754.39 5~1~.40 5815.20 5958.5~ 5892,39 6078,0~ 5971.88 ___6157,38 6051.58 6237,91 6131.71 6318.83 6212.63 6400.35 6294.15 6482,44 6376.24 6565,~7 ...... 66~8.57 65~2.37 67~1.54 6625.74 6815.62 6709.~2 6898.68 6792,68 ..6981,08 _.. 687~,88 7062,82 6956.62 7144.39 7038.19 8400.00 7225.55 7119.35 e500.O0 7306.8? 7200.67 8600.00 7388.96 7282,76 8700.00 7471.56 7365.36 SPERRY-SUN INC, RECORD OF SURVEY COURSE.. COURSE DOGrLEG. INCLINATION DIRECTION SEV DEG FIN DEG MIN DEG/IO0 36 0 N 64 AB E 1.16 39 16 ~ 66 30 E 39 14 N 66 18 [ ,13 38 32 N 66 24 E _ .70 38 12 k '66 41 E 37 47 N 66 18 E .~8 37 12 N 67 41 E .62 37.~ 7_. N 67 18.E_. ,11 36 22 N 68 24 E 35 36 N 69 35 E 1,04 , 35 11 k 70 18 E ,59 34 28 N 70 5 E .73 3~ .90 ..... N 10 2~_E _ _ ,82 33 31 N 70 35 E .18 33 32 N 71 30 E .50 32 51 k 68 35 E 1.73 34 24 N 68 0 E 1.58 35~ 2 _N 68_ O .E .63 35 19 N 68 54 E .59 35 22 k 69 30 E 36 7 ~ 70 0 E ,80 35 4 N 69 54 E 1.05 3q 35 N 69 A1 E .50 34 1 N 69 48 E .57 PAGE 3 DATE OF SURVEY JANUARY 25, 1980 VERTICAL SECTION DIRECTION N-60-5q-O0-E ..... 80SS-1653~ TOTAL RECTANGULAR COORD~I~¥ES NORTE/SOUTH EAST/WEST 1603.51N 1902.20 E 1628.72 N 1~56,38 E~ 1654.10 N 2012.61 E 167~.69 N 207~.~7 E 1705.21 N 2128.72 E 1730.54 N 2186.70 E 1755,72 N 22~q.20 E 1780.43 N 2301.14 E 1804.98 N 2357.59 E 182~.28 N 2~13.61 E' 1852.75 N 2469.56 E 1875,62 N 2525.~6 E 1897.94 N 2580.96 E 1919.00 N 2635,80 E 1~38,86 N 2690.21E 1958.21N 27~3.93 E 1977.1~ N 2796.65_L__ 19~5.62 N 28q8,80 E 2013.56 N 2901.04 E VERTICAL SECTION 2386.9~ 2565.8~ 2628,85 2692.12 2755.06 2817,51 2879.24 2940.46 3001.20 3061.45 3121.38 3180.67 3238.79 _ --% 3295. 3352.22 3461.93 3516.23 20~2.22 N ~9~.48 E 3570.20 2052.70 N 3003.92 E 3625.07 _2074.04 N 2095.20 N 2115.74 h 2135.95 N 2155.90 N 2175.63 N 2195,1~ N 991 b .~9 KI 3056,73.E_L__ 3681.54 3110.31 E 3738.59 3164,38 E 3795.TP __ 3217,18 E 3853.4~ 3273.85 E 3910.85 3327.45 E 3967.21 3380.31 E ~022.84 %&%9.Tn V &D??.qq MARATHON OIL D-41 TRADING BAY ALASKA _ BOSS SSR~EL COMPANY UNIT TRUE ....... SUB EASURED VERTICAL SEA DEPTH DEPTH TVD 8900,00 7637,38 7531,18 9000,00 7720.62 7614,42 9100,00 _?£04,34 ........ 7£$8,14_ 9200,00 7887,89 7781,69 9300.80 7971,43 7865,23 9400,00 8055,24 7949,04 9500.00 8138.91 8032.71 9600.00 .... 822Zo26 .... 8116.06 9700.00 8305,46 8199.26 9800,00 8388.69 8282.49 · PAGE 4- DATE OF SURVEY ._dANUARY_ 25e 1980_. VERTICAL SECTION DIRECTION N-60-54-00-£ SPERRY-SUN INC, RECORD OF SLRVEY COURSE ....... COURSE. INCLINATION DIRECTION DEG MIN DEG MIN · _E OSS-! 653_4 DOG-LEG .... TOTAL SEV RECTANGULAR COORDINATES DEG/IO0 NORTH/SOUTH EAST/WEST 34 10 ~ 70 18 E 33 8 N 71 18 E 1,17 33 10 ....... N_70_~8 E ...... ,55 33 30 N 70 54 E 33 12 N 71 54 E ,63 32 54 N 71 24 E 33 31 N 70 41 E 33 3~ .... N 70 _5. E .... 33 49 N .70 18 E ,28 33 31 N 70 24 E 2233,71 N 3485.27 2251.94 N 3537,60 2269,92 N 2288,17 N 3641,07 2305.71 N 3693,17 SECTION 413~.20 4187,72 ~2~.1,5 4295,6~ 2322,88 N 37~4,93 E 4403,14 2340,67 N 3796,73 [ 4456,99 2359,21N _3848,78_E__. 4511,43_ 2378,01N 3900,97 E ~566,11 2396,65 N 3953,18 E ~620,74 99 O0 O1 02 03 00,00 00,00 00.00 00,00 00,00 8554.28 8448.08 34 22 8718,61 8612.41 35 11 8799,8~ 8693.63 36 11 N 71 48 E 1,09 N 71 11 E ,35 N 72 30 E ,78 N 72 41 E 2414.7~ N 4005.94 E · 2432,61N 4059.41 E 2468,55 N ~167-58 E 2485,98 N 4225,2~ E 4675.56 4730,92 A7.86..63 4842,78 4899.82 IOACO,OO 10500,00 10600,00 10700,00 10800,00 8880.71 8774.51 8561.~8 8855.18 ?042.15 ....... 8935.95 9125,2~ 9017,08 920~.28 9098,08 10900,00 9285.02 9178,82 11000.00 9365.68 9259.48 11100.00 9446,70 _ .9340,50 11200.00 9527.73 9421,53 11300.00 9608.79 9502,59 15 52 N 73 5 E 36 35 N 72 54 E ,73 3..5.._9 P ........ ~ _7__~__ _27.. E_ ...... 1,2_7.. 35 5.3 N 7.'5 41 E 35 56 N 74 0 E · 19 ' ' '2503.28 N ~279.~5 E 2520.57 N 4335.96 E .... 2537.17 N ..... 9__3_92__~,52 E 2553.24 N 4448,7;3 E 2569,56 N 4505,06 E 36 22 N 74 0 E 36 7 N 73 A1 E _~_35_39 ~ 73 .35 36 6 N 73 18 E 35.235 N 72 18 E · 43 258~.82 N ~561.77 E · $1 2602,27 N 4618,55 E · 47 ...... 2618.78 N .... 4674.79 .E .48 2635.47 N 4730.96 E ,78 2652,79 N ~786,90 E 5014,., 5072,35 5129.23 5186,30 5243,67 5301,21 5358.2~ 5415.41 5472,63 114 115 116 00,00 00.00 00,00 9690,58 9772.8~ 9855,42 1o~0 2687,98 N e895,65 E · 5~ 2707.06 N 4948,80 E 5528,91 558~,63 5640,29 MARATHON OIL COMPANY 0-~1 TRA~IKG BAY UNIT ALASKA BOSS__SLRkEL ....... *-*-~-~ H~"-C ',~ L ~; U L A'~' iONS PAGE _DATE OF SURVEY__ JANUARY 259_1cJ80 VERTICAL SECTION DIRECTION SPERRY-SUN IN~,,'- RECORD OF SURVEY AR-E ~-i~E-D ON THE'~MI~IMUM '~'~D~-d~' 6~-~U~VXTURE -._ ME:I'HOD ** HGRIZ_OKTA_L._DISPLACEMENT.. : 56_~0_,82~ FEE_T___AT_NOJ~T_H_ 61 DEG,_19 START CF SURVEY WAS 106.20 FEET A~OvE SEA LEVEL MIN, _EAST · TUBI, NG/CASING DETAIL ' - , .... WELL NO.: ' DATE: I-~a-~O. ,z,- BY: ~_-,~ I rem Description '" Set Jts Size Wt Thread Grade Range Condition Length From To -- ..,~ ~r 41,4:~ o 4z. 4.:z g , ~- % ~. ~ .87c. N- aO ~ ~ ~ .,. 2.. ~o 43. ) - ~.. Z- ~{~__ ~,~ ~ N-~,O 2~ i ll~.c~o~ 22ol. I( I ' j ' ., _ =-~/? .~.,.~ ~r N-60 ~-o I 4 ~fl .766~ 7~ TUBI, I,IG/CASING DETAIL WELL NO. DATE BY: Item Description Set J, ts Size Wt Thread Grade Range Condition Length From -. ~, ~ t3~~ _,, ~_ ~ - ~ .s. z ~TC_ N-~ ~,,..,n ~ 4. =r. .~&~.O~ %- ~& Z~t~- ~ , ~ ~ 021 ..... ~_ e. 2 STo N-BO . ..,_ s . ~ 4. xo 9 ~_ IA ~_ Reraa rks; TUBI. I,IG/CASING DETAIL WELL NO.: b- 4J DATE: i--TO-- BY: ~ '~:' ~ rem Descri tion Set Jts Size Wt Thread Grade Range Condition Length From To i:'t. s4 .U.,._. c~..-o.. ,/¢' G. -~ la O GT ~ ,7_,._~c,,,,e. _I_ ,~. Sd4 , ~ _ I/Z O, 2_ ~TC. N-gO ~-g Z _t0 :- ~/z ~.?_ L~ ~-8o ~ ~ i Remarks: TUBI.I,IG/CASING DETAIL WELL NO. DATE BY: rem Description Set its., Size Wt Thread Grade Range Condition L.e,ngth From To ~-~/_.-,_ .~. 2_ ~r~q-, C.. _ ,,ki-~,._'b m_.~,'-~ 1' 4.47 3-~ C~,,- ,~A ~ce, ,_ ,2. TS" z~ 2 d.~3 /gF~z.81 ~7~7.T~ ' / o ~.~,, ..... ~ ., t,.z 5 ~ It 1 .... ~ ,,, , , .... - -,r~ a '- ,~ ,, ~-.~ & ~ ~ - '/~ ~ ~ ~ ~ ~ s ~. ,73, ,, , ~ema rks: TUBI, NG/CASING DETAIL WELL NO.: ]~) -- ~,l DATE- I- ~0- ~0 BY: ~ ~_~ Item Description ::~: 0 t o_,'~-:erm,. ,~'<2~_~:? ~ Set _Jts Size Wt ,. Thread Grade Range Condition Length From To ~t-,'~ ~,~,'~ 4 )~ 7' "3 _,",_rlc~--v-' 'I ~ ~-T / I £~,3 '~-~ .,. ,, , ,, ...... , , .... ~ , .... ....... ,,, , , , .... Remarks: TUBI!~G/£A$1'~G DETAIL WELL NO.: ~-- 41 DATE: I-2o - ~d BY' ~_~-~ Item Description Set ts Size Wt iThread Grade Range ConditionJ Length From To Bo-r' k,d,-o.: ,I,c_ ,d,C, ~.~:,_~ a-~' i 9 ~ /o~-~-z..~_~~o.~ I 7 29 ~rc~ N-8o S ~:i i Iz~.ob /o-7(~. ,s ~o~,4-. t7 ~_,~S ~ +~'~ , ~ ~ ~9 ~TC_ N-Sa ~ ~ I 174 .S~ //.~/~.~z_J I / ~ 4 I. 7/ ~,o~ ..'~e~ ~ ! 8~ / 172~ f~ l l7~ co ............. b ' t , , , 1UBI~g/CASIHG DLrAIL NO. · ]~3_- 4] ..... DATE :__j - G_-~.5 :. . _ BY: bF.~ ........ I t -,~, ~.,-s:_!'j p_Li on Jts Size _ Wt Thread L Grade _ Set Cond i t i on Length 1 ~F~. 6Z From 44. ~A .... 2'~ ._Aa__.. ,i ,j 47Z. I~EJAJL ACE D1 1SION "o. I.~'ngl-h From /~/r.x,4 co _ · _ct_ _~.~_ _fl LIp Set To Sfze Ut. 'P~d. Gr. I I 1 J_ Document Transmittal Union Oil Company of C~ union .o. DATE SUBMITTED f~o H. W. Ku~ler Alaska O&G Cons. Com~. 3001 Porcupine Drive Anchoraqe, AK 99504 TRANSMITTING THE FOLLOWING' FROM R. C. Warthen ~nion Oil Cc~y PO Box 6247 TELEPHONE NO Anchorage, AK CC '.~ J 4 ='"t $ t "'-OL ST-~T acknowledge receipt by DATE: FORM 1-2M02 (REV 11-72) PRINTED IN U S A ]P~nn No P---4 REV 5- 1-70 STATE C~i- ALASKA OIL AND GAS CONSERVATION COMMII-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SrJBMTT IN DUPLICAT~ 0H, [~ GA1 [] OTHEI WKLL WKLL NAMI~- OF OP~,ATOR Union Oil Company of California* ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 LOCATzON OF WELL RECEIV 'D Leg A-l, Cond #6, Dolly Varden Pl~.tform, 755'FSL, 1218'FWL, Se~: 6-8N-13W-St~II~ka 0~1 & ~ ~ ~ AP! NUIiERICAL CODE 733-20331 LEASE DESIGI%TATION AND SEI~IAL NO ADL-18729 A-926 IF II%~DIA]~ AI.~O~ i kE OR TI~IBE NAME 8 L~.'IT F.~t]~I OR LEASE NAME Trad i n,q Bay Un i t D-41 10 FIEL~ A_ND POOL OR WILDCAT McArthur Riyer Field Il SEC T R, l~,t (BO'I'~OM HOLE Sec. 6~ T8N~ R13Wt SM 12 PERMIT NO 79-83 13 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CA~ING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUIVI'ES USED PEP,.FOHATIONS, TESTS ANT) RESULTS FISHING JOB~ JUNK IAI HOLE AND SIDE-TRACKED HOLE AND A~Y OTI-EER SIGNIFICANT C'HA~GES IAI HOLE COH'DITIONS JANUARY REPORT OF DRILLING OPERATIONS 01-01 10,556'TD Repaired drawworks motor. Fin POH. Chgd bits. RIH w/ bit #32RR. Drld to 10,556'. 01-02 10,603'TD Drld 10,556'-10,579'. POH. Tstd BOPE & related eqpmt. Repaired air pump on Koomey unit. RIH w/ bit #34. Drld to 10,603'. 01-03 10,725'TD Drld 10,603'-10,725'. Made 20-std short trip. Circ for open hole logs. POH. RU to log. 01-04 10,725'TD Fin RU to log. SOS ran DIL/SP/Sonic & FDC/CNL logs. 01-05 10,758'TD RD Schl. RIH w/ bit #35. Corrected TD from 10,725' to 10,738'. Drld 10,738'-10,758'. C&C mud & 12-1/4" hole. Made lO-std short trip. Hole OK. C&C mud to run 9-5/8" csg. POH. 01-06 10,758'TD Fin POH. RU & started running 9-5/8" csg. 01-07 10,758'TD Fin running 265 jts, 9-5/8" 43.5# & 47#, N-80 & P-110 csg. FS @ 10,734', FC ~ 10,646', & DV clr ~ 6488'. HOWCO cmtd 1st stage w/ 915 sx CIG cmt w/ 1/2 gal/sk Econolite, 0.3% HR6L, & 1/4 #/sk flocel (13.4 ppg). Bumped plug w/ 2500 psi--held OK. CIP ~ 0130 hrs, 01-07-80. Opened DV clr ~ 6488 w/ 1000# w/ no cmt rtns. HOWCO cmtd 2nd stage w/ 800 sx CIG cmt w/ 1/2 gal/sk Econolite & .3% HR6L (13.5 ppg). Closded DV clr w/ 2500#. CIP @ 0640 hrs, 01-07-80. Bled press-plug held OK. *Marathon Oil Company - Sub-Operator t4 ~ her~t,y t. ~orrec* Dist. Drlg. Supt. 2/4/80 ...... i )I~E--Report off this form is required for eQCh calendar moflth~ regordless of the status of operations, and must bo filed in duplicate with the oil and gas conservatbn committee bythe ISth of the succeeding month, unless otherwme d~rected. January Report of Drill ing Operations TBU Well D-41 Page 2 01-08 10,758'TD ND csg tools. Instld 9-5/8" csg slips. Cut csg. ND BOPE. Instld tbg spool & NU BOPE. 01-09 10,758'TD Tstd BOPE & related eqpmt. Instld seal in hydromatic brake. PU BHA & RIH to DV clr @ 6488'. Tstd 9-5/8" csg to 2500#--0K. C&C mud prior to drlg DV cir. 01-10 10,909'TD Drld DV clr @ 6488'. Tstd 9-5/8" csg below DY clr to 2500#--0K. Drld cmt 10,600' to plug @ 10,604'. Drld plug & cmt to 10,720'. Tstd 9-5/8" csg to 2500#--0K. Drld 10,720' to shoe @ 10,733'. Drld shoe & cmt to 10,758'. Drld new hole to 10,768'. Conducted leak-off test to 11.2 ppg. Drld to 10,880'. POH. RIH w/ bit #37 & drld to 10,909'. 01-11 10,938'TD Drld 10,880'-10,921'. POH. Repaired Iow clutch. PU Christensen core bbl & RIH. Cut core #1 from 10,921'-10,938' (17'). 01-12 10,969'TD POH & rec 17' of core #1 (100%). RIH w/ core bbl. Cut core #2 from 10,938'-10,969' (31') 01-13 10,992'TD POH & rec 31' of core #2 (100%). RIH w/ core bbl. Cut core #3 from 10,969'-10,992' (23'). 01-14 10,993'TD Cut core #3 from 10,992'-10,993' (1'). POH & rec 24' of core #3 (100%). Instld seals in Iow drum clutch (7 hrs). RIH w/ bit #37RR. Reamed 90' to btm & dropped surv. POH. 01-15 11,017'TD POH w/ bit #37RR. RIH w/ core bbl & cut core #4 from 10,993'- 11,017' (24'). POH. Rec 22-1/2' of core #4. RIH to cut core #5. 01-16 11,066'TD RIH. Cut core #5 from 11,017'-11,035' (18'). POH. Rec 18' of core #5 (100%). Total core cut in 5 runs: 114'; Total Recovery: 111.5'. Tstd BOPE & related eqpmt. RIH w/ bit #39. Reamed 10,976'-11,035'. Drld from 11,035'-11,066'. Projected TD: 11,732'. 01-17 11,232'TD Drld w/ bit #39 from 11,066'-11,123'. Surv & POH. Tstd BOP's. RIH w/ bit #40. Reamed 11,090'-11,123'. Drld 11,123'-11,232'. 01-18 11,439'TD DRId w/ bit #40 from 11,232'-11,409'. Circ & surv. POH & PU bit #41. RIH & reamed 11,355'-11,409'. Drld 11,409'-11,439'. 01-19 11,662'TD Drld 11,439'-11,517'. Made wiper trip to 9-5/8" shoe. Drld 11,517'-11,601'. Made wiper trip to 9-5/8" shoe. Drld 11,601'- 11,662'. January Report of Drill ing Operations TBU Wel I D-41 Page 3 01-20 11,703'TD t.,'Utlh~iJ$$1011 Drld 11,662'-11,703'. C&C mud. Short trip to 9-5/8" shoe. C&C mud & hole for OH logs. POH. RU to run OH logs. Schl running SP/DIL & Sonic logs. 01-21 11,735'TD Schl ran Density log. RD Schl & NU flow lines. RIH w/ bit ~42 & drld 11,702'-11,735'. C&C mud & hole for 7" Inr. RU to run 7" Inr & started running same. 01-22 11,735'TD RIH w/ 28 jts 7", 29~, Butt Inr to 11,728'. Set BOT hgr ~ 10,551'. Top of 7" Inr @ 10,536'. Tstd surf lines & pumped 30 bbls wtr followed by 450 sx CIG cmt w/ 1% CFR-2, 0.3% Halad 22A, 3% KCL, & 1/4 #/sk flocel (15.8 ppg slurry). Dropped plug & displ w/ 10 bbls wtr & mud. Bumped plug w/ 3000#. PU & circ. CIP @ 1745 hrs. POH & WOC. Cleaning rig & upgrading r i g eq pmt. 01-23 11,735'TD 11,642'PBTD WOC. Tstd BOP's. RIH w/ 8-1/2" bit & drld cmt 10,191'- 10,435'. 01-24 11,735'TD 11,642'PBTD Drld cmt 10,435'-10,536'. POH. RIH w/ 6" bit & 3-1/2" DP. Press tstd Inr lap w/ 2500# for 20 min--OK. RIH to 11,428' & drld cmt 11,428'-11,642'. POH. 01-25 11,735'TD 11,642'PBTD RIH w/ Halliburton DST tool for Inr lap test. Set tool @ 10,511' w/ 2000'WC. Recorded 1 hr flow period & 2 hr SI. POH. Lnr lap tstd OK. RU DA & ran Sperry-Sun gyro. Prep to run CBL. 01-26 11,735'TD 11,642'PBTD DA ran CBL & NLL logs. RD DA. 01-27 11,735'TD 11,642'PBTD RD DA. RIH w/ bit to btm of 7" Inr @ 11,728' & displ mud w/ FIW. POH. LD DP & BHA. RU DA. RIH w/ JB & GR to 11,100'. POH. No restrictions in 7" Inr. Did not rec any junk in basket. RIH w/ Otis WD pkr. WD pkr hung up in tie-back slv (7-1/2"1D) @ top of lnr @ 11,536'. 01-28 11,735'TD 11,642'PBTD Failed to work Otis WD pkr free. DA set pkr @ 11,536' & POH. RIH w/ Bowen spear & latched pkr. POH. Rec pkr & tail pipe. Left pkr rubber & slips in hole. PU 8-1/2" bit. 01-29 11,735' TD 11,642' PBTD RIH w/ 8-1/2" bit & csg scraper to top of 7" Inr @ 10,536'. Rev circ from 10,536'. POH. RIH w/ 6" bit & scraper to PBTD @ 11,642'. Rev circ hole clean. POH. RU GR & JB to 11,050'. DA set Otis WD pkr @ 11,030'DIL. POH. RIH w/ 2nd Otis WD pkr. January Report of Drilling Operations TBU Well D-41 Page 4 01-30 11,735'TD 11,642'TD 01-31 11,735'TD 11,642'PBTD DA set Otis WD pkr @ 10,774'DIL. RD DA. RIH w/ 5" & 3-1/2" DP. POH & LD DP. RU & RIH w/ 3-1/2" prod pkr. Fin RIH w/ 3-1/2" tbg & landed in Otis WD pkr @ 10,774'. Tstd seal assy to 2100~--0K. Removed BOPE & started NU Xmas tree. Tstd Xmas tree to 5000#--OK. R£V. 3-1-70 . SUBMIT IN DUPLICATE STAT E O F A LAS KA el L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL Leg A-l, Cond #6, Dolly Varden Platform, 755'FSL, 1218'FWL, Sec 6-8N-13W-SM 5. APl NUMERICAL CODE 733-20331 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 7. IF INDIAN-ALOTrEE OR TRIBE NAME & UNIT FARM OR LEASE NAME Tradinq Bay Un it 9. WELL NO. D-41 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6¢ T8Nt R13Wt SM 12. PERMIT NO. 79-83 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED~-HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 12-01 3,000'TD 12-02 3,000'TD 12-03 3,000'TD 12-04 3,000'TD DECEMBER REPORT OF DRILLING OPERATIONS RU & ran 77 jts 13-3/8" K-55, 68~, Butt csg. RU Halliburton & cmtd 13-3/8" csg w/ 1500 sx CIG cmt w/ 1/2 gal/sk Econo- lite & .1% HR6L followed by 500 sx CIG w/ .75% CFR-2 & .3% Halad 22-A. Tailed in w/ 500 sx CIG neat. Bumped plug w/ 1500 psi. Had cmt returns. CIP @ 0530 hrs, 12-01-79. ND 20" BOP & riser. Cut off 13-3/8" csg. Instld 13-3/8" Bradenhead & welded same. Weld failed to tst. Cut off 13-3/8" csg stub & started rewelding 13-3/8" Bradenhead. Welded Bradenhead on 13-3/8" csg & tstd same. Relocated crown block to center traveling blocks over RT. Repaired BOP remote control panel. Started NU BOPE. Tstd BOPE & related eqpmt. Tests were witnessed by State rep. Instld flow nipple on Hydril. Found ring groove on top of Hydril to be too large. Hydril head had been sent in for machine work on ring groove while rig was dwn. Removed Hydril head. While offloading Hydril head from platform to send to machine shop for remachining, crane operator dropped Hydri I head into Inlet. Could not locate another 13-5/8" Hydril or Hydril head in the area. Hydril is sending a head from Houston to arrive the evening of 12-04-79. *Marathon Oil Company - Sub-Operator 14. l h~eby Dist. Drlg. Supt. 1/9/80 .TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. December Report of Drilling Operations Well TBU D-41 Page 2 12-05 3,000'TD 12-06 3,000'TD 12-07 3,162'TD 12-08 4,462'TD 12-09 5,060'TD 12-10 5,220'TD 12-11 5,359'TD 12-12 5,970'TD 12-13 6,357'TD 12-14 6,679'TD 12-15 7, IO0'TD 12-16 7,382'TD 12-17 7,856'TD 12-18 7,883'TD CU A-1 well room & repaired misc rig eqpmt while WO arrival of 13-5/8" Hydril head. ETA of head @ DVP is 1100 hrs, 12-05-79. 13-5/8" Hydril head arrived @ DVP @ 1030 hrs, 12-05-79. Instld head & connected all lines to Hydril. MU BHA & RIH to FC @ 2909'. Tstd Hydril to 1500 psi. Tstd 13-3/8" csg & pipe rams to 2000 psi--all OK. Started drld FC. Fin drlg FC & drld cmt to 2982'. Tstd 13-3/8" csg to 2000 psi--OK. Drld cmt to 2994'. C&C mud. Ran gyro surv @ 100' intervals on sand line to 2987'. POH. RIH w/ bit #6. Drld to 3004'. Conducted leak off test to 13.9 ppg mud equiv. POH. RIH w/ bit #7. Drld 3004'-3162'. Drld & surv from 3162'-3826'. POH. RIH w/ bit #8. Drld to 4462'. Drld 4462'-4571'. POH. Cut & slipped drlg line. RIH w/ bit ~9. Drld 4571'-4787'. Lost pump press. POH. Found bit washed out @ jet nozzle. RIH w/ bit #10. Drld 4787'-5060'. Drld from 5060'-5220'. POH. Tstd BOPE & related eqpmt--OK. MU DD & started in hole. Fin RIH w/ DD. RU DA & Sperry-Sun steering tool. DD from 5220'-5329'. POH. RIH w/ bit #12. Reamed 5220'-5329'. Drld from 5329'-5359'. Drld from 5359'-5639'. POH. RIH w/ new bit. Drld 5639'- 5970'. Drld 5970'-6270'. Circ & surv. POH for BHA chg. RIH & washed 1 jt to btm--no fill. Drld 6270'-6357'. Drld to 6414'. POH. RIH w/ bit #15 & drld to 6679'. Started out of hole. Fin POH. RIH w/ bit #16. Drld 6679'-7047'. POH. RIH w/ bit #17. Drld to 7100'. Drld 7100'-7320'. POH. RIH w/ bit #18. Drld to 7382'. Drld 7382'-7616'. POH. RIH w/ bit #19. Drld to 7856'. Circ & surv. POH & LD BHA. Tstd BOPE--all OK. PU DD. RIH & oriented tool. DD to 7883'. December Report of Drilling Operations Wel I TBU D-41 Page 3 12-19 8,060'TD 12-20 8,335'TD 12-21 8,604'TD 12-22 8,804'TD 12-23 9,115'TD 12-24 9,354'TD 12-25 9,638'TD 12-26 9,835'TD 12-27 10,001 'TD 12-28 10,141'TD 12-29 10,320'TD 12-30 10,368'TD 12-31 10,511'TD DD 12-1/4" hole 7883'-7886'. POH & PU BHA. RIH to 7826'. Reamed 7826'-7886'. Dr Id & surv 7886'-8060'. POH for bit chg. RIH w/ bit #22. RIH w/ bit #22. Drld 8060'-8335'. POH for new bit. RIH w/ bit #23. Drld 8335'-8604'. POH. Fin trip for bit ~24. Drld 8604'-8804'. Drld 8804'-8829'. POH. RIH w/ bit #25. Drld 8829'-9115'. Started out of hole. Fin POH. Tstd BOPE & related eqpmt. RIH w/ bit #26. Drld 9115'-9354'. POH to chg bits. Started in hole w/ bit #27. Fin RIH w/ bit #27. Drld 9354'-9638'. Dropped surv. POH. RIH w/ bit ~28. Drld 9638'-9835'. Started out of hole. Fin POH. RIH w/ bit #29. Drld 9835'-10,001'. Started out of ho l e. Fin POH. RIH w/ bit #30. Drld 10,001'-10,141'. Circ & surv, POH. RIH w/ bit #31. Drld to 10,320'. Drld to 10,325'. POH. RIH w/ bit #32. DRId to 10,368'. Started out of hole. Fin POH. RIH w/ bit #33. Drld 10,368'-10,511'. Started out of hole. · / ~ ~-I-?0 STATE O(r ALASKA OIL AND GAS CONSERVATION CONVv~ITTEE SUBMIT IN I~J~LICAI~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I WKLL __. ~gLL NAME OF OPERATOR Union Oil Company of California* AD~)RESS OF OPerATOR P. O. Box 6247, AnchoF~lge AK 9950? LOCA~ON ~ WEL~- Leg A-l, Cond #6, Dolly Varden Platform, 755'FSL, 1218'FWL, Sec 6-8N-13W-SM ( ~ ^~ N~m'~L aoBE 733-20331 LEASE DESiGNA I"ION A%-D SEI:ilAL NO AD.L- 18729 A-926 ? IF INDiA]~ AI.,OTIE£ ON TRIBE NAME ---- 8 L~.'IT FARM OR LEASE NAME Tradino Bav yqit I]-41 10 FIFI,r) A_ND POOL OR WILDCAT .Sec. 6, T8N~. R13W~. SM 12 PERMIT NO 79-85 REPORT TOTAL DEPTH AT E, ND OF MONTH, CH. ANGES IN HOLE SIZE CASING AND CEMENTING JOBS INCLUDING DEl*TH SET AND VOLUlVIES USED PER~ORATIONS TESTS AIq-D RESULTS FISHING 3013/5 JLTI~K I.N HOL~E AND SIDE-TI~ACKED HOLE AND A.lCY O~-~Z SIGNIFICA24T CH, A~GES I'N HOLE COH'DITIONS 11-18 11-19 11-20 NOVEMBER REPORT OF DR ILL I NG OPERATI ONS - "~'C: (' ' , Moved rig eqpmt from Rig 77 to Rig 76. Cent w/ RU eps on Rig 76. Cong w/ RU ops. Hoved Rig 76 over D-41 cod ucgor. 11-21 Fin moving rig over D-41 cond. Instld OCT starting hub on conductor. Cunt to RU. 11-22 -- RU drlg eqpmt. Mixed spud mud. Started NU 20" BOPE. 11-23 Fin NU 20" BOPE & tstd same. PU BHA & RIH to 363'. CO bridge @ 363'. RIH to 390'. Circ @ 390'. 1-24 491 ' TD C&C mud @ 390'. CO to 404'. Circ for gyro surv. RU DA & Sperry-Sun & ran gyro surv from 389'-surf @ 25' intervals. Drld to 491'. Unplugged cutting chute & desander & desilter. WO elec power to mud pumps. POH to unplug bit. RIH to 390'. Circ & raised visc of mud. RIH to 491'. 11-25 869 ' TD Surv @ 491'. POH & RIH w/ DD & 12-1/4" bit. Oriented DD & faced S58°E. DD 491'-575~. POH & LD DD. RIH w/ 12-1/4" bit to 400'. C&C mud to raise visc. Washed to 491'. Made trip to unplug bit. Washed to 575'. Drld, circ, & surf to 869'. *Marathon Oil Company - Sub-Operator 14 I hereby ~Y that th~lore.~ltng m true az~d correct '" ' S~GN~ _~'_---.'~./~e~~ ~TL~ Dist. Drlg. Supt. ~.~ 12/17/79 --Rel)ort on this form is required for cach calendar month~ regQrdless of Ihe status of operations, and must Ix~ filed I. duplicate with the oil and gas conservatbn committee bythe ISlh of the suaceeding monlh,unlea8 Otherwise d, rected. November Report of Drilling Operations Well TBU D-41 Page 2 11-26 1,369'TD 11-27 2,600'TD 11-28 3,000'TD 11-29 3,000'1]] 11-30 3,000'TD Drld 869'-994'. POH. RIH w/ DD run #2. Oriented DD & DD from 994'-1189'. POH. LD DD. RIH w/ 12-1/4" bit. Reamed 984'-1189' w/ new BHA. Drld 1189'-1369'. Drld & surv 12-1/4" hole from 1369'-2600'. Drld & surv to 3000'. POH. LD DP. MU HO #1 & started in hole. Opened 12-1/4" hole to 17-1/2" from 491'-2260'. Opened 12-1/4" hole from 2260'-2996'. C&C mud. Made short trip. Circ hole clean. POH. LD hole opener. RU to run 13-3/8" csg. Alaska 0tl and (;as Conservation Commission Hoyle H. Hamtlton //~ Chatman of the Contats~Y~' . . Lonnt, C. Smtth ~/~ Corn1 sstoner Bobby Foster~-~'~ Pet~le~ ~ns~ctor December 4, 1979 ~Utness BOPE Test on Marathon's T.B.U. D-41 Sec. 5, T8N, R13E, SM Permtt #79-83 ~Sunday Deceeber. 2,..1979 , ............ ! traveled to Marathon's Dolly~ Varden Platfom thts date to wttness the BOPE test on D-41. *' " ~nday December. ~.,...!97.9 ': ......... The BOPE test began at 7:00 a.ln: and was concluded at 10:O0 a.m. The results of thts test are attached't~o't~l~s report. [n summary, ! witnessed the BO~I~ test on I~rathon's D-4!. : ° A~a Oil and Gas Conservation Cc~sion , -~ l'ield Inslx~ction of Blc,,:3at Prevention Equipment Location: Dril ling Contractor~ Location, General_ Well Sign ~ner~l ilousckccplng_~~ AnnulaL- Pre/er,t 2).' .... / ..... Pipe Rom%s ....... / __ B lind Rams / Choke Line Valves ~ H.C.K. Valve / Kill Line Valves /, , Check Valve Test Ecsults: Famlures 'I'cs t Pres surc iFuli Ch~ge Pressure~Eo P~ess~re After Clo~-e/~~ .... psig 200 psig ~ve Pred~argc AtLa~ns~:~min~~ ~11 ~argc Press:~e At~ain~:__~_ mzn~ Con~ols: Master~5 __ Ke. 1 ly and L~,.~ ~' Kelly Ball ~y~e / TCS" In~lde ~P / 'fes~ Choke Manifold~ No. Valvcs/ ]No. flanges ~ __ _ .~ __ _ _ " . _ Repair or Replac~zent of failcd cq,~pnxm,~ to be ma, lc widiin November Re Trading Bay Unit D-41 Union Oil Company of California Permit No. 79-83 BUr. Loc.~ 75§~FSL, 1218~1~, Sec 6, TSN, R13W, SM. Bottomhole Loc ~ 2000~FNL~ ~J00FWL, Sec 5, ?SN~ RI/#, SM. District Land Nanager Union Otl Company of Calt~ornia P O. ~x ~47 ~0hoElge~ Al~sk~ 99502 D~e,m~ ~. Anderson~ Enclosed is the approved application for permit to drill the above, re£erenoed wi 1. well samples, c.ore chips and a ~ud log are not required. A directional survey is required. If available, a tap~ contain- lng the digitized log infomation on all logs shall be sub~itted for copying except exu_pe~i~ental logs, velocity surveys and dlpmeter surveys. ~any rivers in ~laska and their drainage systems have been classified as i~portant for the spawning or migration oE anadzc~ous fish. Operations in these areas are subject to ~S 16.50 870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the Nabttat Coordinator's office, Department of Fish and ~ame. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ~rticle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ended. Prior to Mr. Robert T. Anderson Trading Bay Unit D-41 -2- November 7, 1979 cementing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor iS being notified of the issuance of this To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- mmn~ative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate edvanoe notification so that we may have a Enclosure cos Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department o£ Labor; Supervisor, Labor Law Compliance Division w/o encl. Umon Od and Gas f '~s~on Western Region Un~on Od Company of Cahforma P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 Telex 90-25188 unl, n Robert T. Anderson D~st.ct Land Manager October 30, 1979 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill or Deepen TBUS D-41, Dolly Varden Platform, McArthur River Field State Lease No. ADL-18729 Dear Mr. Hamilton: Enclosed for your further handling are three (3) copies of the above captioned Permit to Drill. Also enclosed is our check number 18972 in the amount of $100.00 to cover the filing fees. Very truly yours, ! sk Enclosures (4) t, OV - 3 1979 AnG~urage rir..,v - 2 { .,, ,,.,,,,,,,.,. ,,,, (Other mstruction~% Form I 0 -- 4 0 I reverse side) o,, R E # 733-20331 PERMIT TO DRILL OR DEEPEN DRILL ~ DEEPEN [-] WELL WELL OTHBI ZONB ZONE 2 NAME OF OP~TOR Un,on 0~1 Company of California~ P. 0. Box 6267, ~chorage ~ 99502 4 ~OCATION O~ W~ At surface 755~FSL, 1218'~L, Sec. 6, TS~, R13~, S~, Cond #6, Leg A-1 (NE) At p~o~ed prod 7one 2000~F~L, 800~, Sec. 5, T8~, R13~, S~ 13 DISTANCE I~ MI~ES AND DIRECTtON ~RO~ NE~EST TOW~ OR POST O~I~' ApproxSmately 21 mSles ~ of Kena~ Alaska 14BOND INFO~ATION TYPE Statewide Surety and/or NoUnited Pac%f%c Insurance Co. 15 DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT 2000 ' (Also to nearest drlg, umt, 1£ any) 18 DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, 1175' 21 ELEVATIONS (Show whether DF, RT, CR. etc ) KB 106.2 MSL B-55502 t 16 NO OF ACRES IN LEASE 3085 19 PROPOSED DEPTH ll,730'MD 10,000' TVD PROPOSED CASING AND CEMEN'I~ING PROGRAM 8 UNIT~FARM OR LEASE NAME Tradin~ Bay Unit g WELL NO D-41 10 fIELD AND POOL OR WILDCAT McArthur River Fiald SEC, T R M CBOTTO'~ HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM , ~"~? $100,000 '[17 NO ACRES ASSIGNED TO THiS WELL fl0 20 ROTARY OR CABLE TOOLS Rotary APPROX, DATE WORK WILL START* 11-26-79 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAD~ SETTING DEPTH quantity of cement 17~" ~13-3/8" 68# K-55 2,500' App_rox 2500 sx ~9~,, q_~ IR,, A~ 5~ N-gO 6.500' ]?~" q-5~g" ATti N-gO 9.000'~ ADDrox'" 2710 SX in 2 stages. ~,, q_5/g,, A7{t p-IlO ]0.750~ . R~" 7" ~qt) N-gO ] PROPOSED PROGRAM Drill a Hemlock producer from the Dolly Varden Platform, Leg A-i, Conductor 6, to a location with the Hemlock top at 2000'FNL, 800'FWL, Sec. 5, T8N, R13W, SM, in the McArthur River Field. Plans are to drill and open 17-1/2" hole and set 13-3/8" surface casing to approximately 2500'; drill a 12-1/4" hole and set 9-5/8" intermediate casing to approximately 10,750'; drill an 8-1/2" hole and set a 7" liner to 11,730'. Complete the well as a Hemlock Pr°~v~)~a~%~'m~o. os~ m~O~R~ n' ~-o~,-,,I m to dee~n ',ire ~ on present p~u~ive zo~ ~d pro~ ~w prddu~lve ~ne JLJ~l a W ~rlll Or ~n ~[o~lly, give ~ent ~ on subsu~a~ ~tW~ ~d meas~d ~d ~ue ve~tcal dep~ Give bio--ut pre~eGter- v~gram 9!O~ _-- ..... ' ~~ ~DA~ October 30 1979 Dist Land Mgr. - mouern' l. Anae[son f - ~/ ' ' ~ ' SAMPLE ASD CO~ cmos R~~ ~ MV.~O'O / ~ ~U~ { { DI~ON~ SURVEY R~~ A.P I. ~C~ COD~ - .~o~ a~ , , T~. C~ssion~ _ OA~ 11/7/79 ORD~ *Marathon Oil Company - Sub-Operator MAR ATHON OIL CO. DOLLY VARDEN PLATFORM - Drill D~ck FIoo~ ~ n ri ~Flowi~ne Dr~ll~n$ U 20"Riser MIppi¢ Annular Preventer ( 20" ~, 2,000'* Hyd~ii ) -- Diagram" I -- Sf~rtih9 Riser LLse~[ Bcf)r¢ Scl- _ ~in~ 13~/8'' Sure,cc Ca,ih9- RECEIVED ~,i0v - 3 1979 x~ ~latnp- oh Hub ~.0 e...T) K A. TNoMA. ~ - MARATHON OIL CO.- Mud Pan miowl~n¢ -- DOLLY VARDEIq PLATFORM -- U ~ 13 5,ooo Room Floor C,c~sing C. oll~r Surface Conduc±or . [ J !¢G~- 28 + D-29 G-12 & r, D-2A D.2~D -24A -oe~ ¢]" '10 ;:'rd D-40~ ~ olo D-28 . ~, .9¢\ .9¢~, u - ov D -II -?r~ eD- _D-2E 15rd _D-31 7 8rd II .9,¢D-14rd II G'i6 %1 - MRO ,UST KU 'i -IA 2000' 4000' 6000' 8000' I FEET MARATHON OIL COMPANY ANCHORAGE DIVISION TRADING BAY UNIT McARTHUR RIVER FIELD TOP HEMLOCK BENCh, - I CONTOUR INTERVAL ~ IOO FT Scale' ~" · 2000' Author o AtC.~SC~/ L ~ Date FEB ~979 Fde no I000 2O0O 3OOO 4003 - 6000 7OO0 8000 -3()I ,0 SURFACE TvD:O TMD: 0 OEP : 0 5o 15° ZO° 25° 3O° EOC TV D: 2300 TMD: 2362 DEP: 404 KOP TVD : I000 TMO = I000 OEP :0 BUILD ANGLE: 2 I/2°/I00' ~2 I 12 7 3000 TMD 4000 TM D """ MARATHON OIL COMPANY DOLLY VARDEN PLATFORM WELL NO D-4I LEG A-I CONDUCTOR 6 SCALE I": I000' AUGUST 21 1979 BY BESSE, EPPS & POTTS FOR GREAT LAND DIRECTIONAL DRILLING 31 32 6 5 TD T V O: 10,000 TMD: 11,732 DE P: 5707 TARGET TVO :9250 · TMD '- 10,$2l DEP: 5191 ,tO TSN, RI3W, SM SURFACE TvD:O r-- TMD'O DEP :0 ...----------t 0 1000 ZOO0 3000 4000 5000 1979 5O00 "CMO O( · 0 6000 'I'MD AVERAGE ANGLE :54o 33' 7000 'rMD B000 TMO 9000 TMD ~ 2000 3000 0 I000 4000 I0000 TMO TARGET TVD: 9250 TMD: 10,821 OEP: ,5191 50O0 6OOO TD TVD = iO,OOO TMD: 11,732 DEP: 5707 - MARATHON OIL GO. DOLLY VARDEN PLATFORM - f / _ x, Fio,,vlin~ Drilling Nipple Drill Deck Floor ' \ -- Diogro, m ~ I -- Sf~rtih9 Riser tJLsc4 Be.l:~re ..Set- .._ 'tih~ 13~/a'' Sur~ce Wc. lt, Room U , % 2 0" i~ iser Pre¥¢~tcr (20", 2,000~ Hydril ) £~ cT) ~ :53" Oc, nduc't'o~ - MARATHON OIL GO.- -- DOLLY VARDF__I',,! PLATFORM -- ~ --~', -,- Mud Pon Drillin9 l"iippi~. o Room C, onduc±or w/Flanacd Outlets ~ Valves ! · (Pipe ,,~~ ~~ ~~) ,, A 5,000 - Kill LinC- ~ ,~ -- .... Choke Line- 3~5,000' ~,,;'~"~"~,o':'~ ...... ..~ ~"~' ~ - .... -' ;~o ...... ~ ~C1W Swi~- Bolt Clamp Rise~ ~ BOP ~t~ck For LO., , qJ ~,~,..~.~~'" ~ 2 Ff. Bpool _ G-i?rd . G-28 /D 0-1.5 D-9 0-12 7 D-24A ,10 .~,¢D-14rd D-14 G-16 ¢ 'J - MRO JST KU -1 -IA 0 2000' 4000' 6000" Ii! 000' FEET ~.D-16 ~ ~'~ o° MARATHON OIL COMPANY ANCHORAGE DIVISION TRADING BAY UNIT McARTHUR RIVER FIELD TOP HEMLOCK BENCI.,- I CONTOUR INTERVAL -- I00 FT ScaJe' I" · 2000' Da'e FEB 1979 Author F,le no 0 1000 i 20©0 SURFACE TVD: 0 TMD- 0 DEP :0 KOP 50 TVD : I000 ~0~ TMD: I000 ~5o DE P = 0 20o BUILD ANGLE 21/2°/100' 250 1218__ 30o ECC TVD: 2300 TMD = 2362 D E F': 404 I 12 7 30(30 TM D "'"'l MARATHON OIL COMPANY ~- DOLLY VARDEN PLATFORM WELL NO D-41 LEG A-I CONDUCTOR 6 SCALE I": I000' AUGUST 2.1 1979 BY BESSE, EPPS & POTTS FOR GREAT LAND DIRECTIONAL DRILLING SURFACE TVD:O TMD:O DEP =0 TSN , RI3W, SM. 31 TD TVD: 10,000 TMD: 11,752 D E P: 5707 5 -o 800' TVD :9250 TMD: 10,821 DEP = 5191 i I I I -I i 0 I000 2000 3000 4000 5000 4000 TMD 4CCO -1- oCO0 7000 &GO0 3~ ,) I ! I000 5000 I'MD 6000 TMD -t 2O00 3000 AVERAGE ANGLE 34.0 7000 TMD i 8000 TM D ' ~ 9000 4000 i~OOTMD t 5000 60/00 TARGET TVD: 9250) TMD: 10,821 DEP: 5191 TD TVD: ~O,OCO TMD: 11,732 DEP: 5707 1FELL FC~d~. CR-13 ~/72 CASING STRING CASING SIZE HOLE SIZE CASING A~D ~BING DESIGN CObC~ZZ STA_~2 bfog3 ',7. II #/g. HYD. GR. II ., ?:~/f:, INTERVAL Bottom Top Wt. DESC.~PTiO~{ 'JEIOH £ TE}:SION ~,",/ E2 -top of ST~REXG~4 Grade ~-nread U/O L7~'~ section TE'.CSiON lbs lbs !000 lbs TDF COLLAPSE COLLAPSE CDF Bb~S'f PRESS. @ P£SIST. PRESSUiRE bottom tension ~sl ~sl psi YIELD P~CE .=ER ~,~_ Ha3- lc}jo /,73 3~/~-~ 3~o7 '-/$..f ,~'-,~o ~ ~?so, 9~z,..<~o_ /00.5' 5,7 ,,v-Fo ~ ~?;s'~o_ /q't?~ 3~3W Formalae- Collapse resistance in tension = :( (Collapse pressure~,a~lr~) + ~ Burst Pressure = bLSP + I)epzh ( }{yd. Gr. II --.~) z. oo - (o. oz~ 3 x ','~a wt. ~) Calculations: Tokai Ccst / oo -- ' O.o g --> x : ~, 97 I Ogi,.ooo September 17, 1979 A D M I N I S T R A T I V E A P P ~ O V A L ~O. 89.33 Re: Application of Union Oil Conpany of California, operator of the Trading Bav Un~_. to drill complete and Droduce tho Trading Bay Un~ell as ~ part of the pressure main- tenance project approved by Conservation Order No. 80. Mr. Wayne Rodges Landman Union Oil Company of California P. O. Bex 6247 Anchorage, Alaska 99502 Dear Mr. Podges: The referenced application was received on September 14, 1979 and stated that the drilling and completion of the Trading P.a~~ Unit D-41 ~ell will provide a crestal final withdrawal point in the Hemlock Pool. The Alaska Oil and Cas Conservation Con~nission hereby authorizes th3 drilling and completion of the referencna well pursuant to Pule 5 of Conservation Order No. 8~. Yours very truly, Harry W. Kugler Commissioner BY THE ORDER OF THE COM~IISSIOR Robert T. Anderson D~strJct Land Manager Union Od and Gas(l~slon: Western Region Umon Od Company ot Cahforma P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 Telex. 90-25188 union September 12, 1979 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Complete Trading Bay Unit D-41 (12-5) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in the Hemlock Formation at a crestal final withdrawal point, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the Dolly Varden Platform by Marathon Oil Company, suboperator. Very truly yours, 3O 13 TD 12,014 II G-17 RD TD 12,14.0 G-28 ~z TD 12,4.25 G, TD 11,072 9 4 29 G-2 TD I0 RISW 5 10,312 7 9 G-4 ;~ TO IO,16~ TD ;-7 II 12,9,)0 TD 11,440 ,2 G'25 TD ~2,,~65 11,420 9 31 T9N '[78 N I I D-15 TD I 1,905~ G-22 D-4-OTM '"~ 12,600 12 I D-II ~o --DOLLY -- + TD I I000 200O io TD 10,846 ~ D-:}8 TO IZ,453 D-27 )'STD 10,250 TI 9 TD I I ~54,~ rD 12,071 IO,828 7 6 D-17 5 TD 11,808 7 D-9 D-14 10,400 rD 11,450 G-3 TO 11,278 0-::50 tTD 13~600 D-7 G-$6 ~,820 D-26 TD I 1,16( 13,380 D-29 I 0i000' TVD RD TD TD 12,557 ML. 5 10,821' MD D'2A 9,250' VD II ;-8 TD 12,175 12 G-12 RD 2 TD 13,800 13,748 13 14 lO TO 111281 15 T 9N T8N TD 16,650 4 11,356 9 I0 D-4 TO 11,980 RD ~TD 11,510 ~D-25 ,o TO ! 1,237 0 ,~D-12 TD 12,$81" RD 'D 12,247 II 13,585 D-24 TD 13,462 D-lO E IV l! P Alaska District I ,(,,{ I I I PROPOSED WELL LOCATION MARATHON SUB-OPERATOR TRADING BAY UNIT D-4.1 (12-5) SEPT. II, 79 R 14 W FEET ! ~ CHECK LIST FOR NEW WELL PERMITS Omnpany Yes No Remarks 1. Is the permit fee attached ................................... 2. , Is ~11 to ,be located in a Fool ............. 3. Is a registered survey plat attached ................................ 4. Is %~11 located proper distance frcxn property line .................. 5. Is well located proper distance frc]n other wells ....... ' 6. Is sufficient underdicated acreage available in this pool ........... 7. Is %~11 to be deviated .............................................. 8. Is operator the only affected party ................................ 9. Can permit be approved before ten-day wait .... 10. Does ~operator have a bond in force ......... i ..... Zl. IS a conservation order needed ...................................... 12. 13. Is administrative approval needed ................................... ! Is conductor string provided ........................................ Lease & Well No. Item (1) Fee (2) Loc. (3) ..%:]min. C'~/'.~4 If-::) ')'~ 14. 15. 16. 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 ~roductive horizons ..................... R~_I) __ 17. Will surface casing protect fresh water zones ....................... .~]) 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to boo o psig .. ~ Approval Reccmme~ed: (5) BOPE /g~2P //-6-7~ Additional Requ_ irements: Engineering: LCS ~' BEW''~'~' rev: 06/21/7 - 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 APPENDIX. No special effort has been made to chronologically organize this category of information. 11 000000 11 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 111111 000000 111111 000000 666666 000000 666666 000000 66 O0 O0 66 O0 O0 66 O0 0000 66 O0 0000 66666066 O0 O0 O0 66666666 O0 O0 O0 66 60 0000 O0 66 66 0000 O0 66 66 O0 O0 66 66 O0 O0 666666 000000 666666 000000 7~777777~7 7 777777 7 77 77 77 77 77 77 77 ' 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 11 5555555555 11 5555555555 1111 55 1111 55 11 555555 11 555555 11 55 11 55 11 55 11 55 11 55 55 11 55 55 111111 555555 111111 555555 777 7 77 77 77 77 17 77 77 77 77 77 77 77 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 S F L K K E N N S F L R K E NN ~ SSS F~ h ..... KKR EELE N N N S F L K K E N NN S ~ L K K E N N SSSS F LLLLL K K EERRk N N AAA A A A A A A AAAAA A A A A AAA A A A A A A AAAAA A A A A *START* USLR PCAb [10707,60157] MONITOR $W$ KLlOL34 JUL-79. *START* *START* USER PCAL [10707,60157] MONITOR SWS KLlOE34 JUL-79. *START* JOB SHIP SEQ. SHIP SEQ. 815 DATE 21-jAN-80 815 DATk 21-dAN-B0 23:00:20 23:00:20 SSSSSSSS HH HH SSSSSSSS HH HH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH SSSSSSSS HH HH II II 1I I1 1I II II II II Ii II II ii II i1 II II II ii Ii 1i II PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTT~T OOOOOO TTTTTTTTTT OOOOOO TT OO OO TT OO OO TT OO OO TT O0 O0 TT OO OO TT OO OO TT OO OO TT OO OO TT O0 OO TT O0 OO TT OOOOOO TT OOOOOO *START* USLR PCAL [10707,60157] JOB SHIP SL~. 815 DA~k 21-JAN-80 23:00:20 MONITOR SWS KLIOE34 JUL-79. ,START* tILE: DSKH:SHIP.TO<255>[10707 60157] CRkATED: 21-JAN-80 22:26:32 PRINTED: 21-JAN-80 2§:00:]6 QUEUk SWITCHES: /~iLE:FURT /COPIES:I /SPACING:I /LIMIT:Il0 /FORMS:NORMAL SHIP TO : SHIPPING INSTRUCTIONS iSSUED 21-dAN-80 22:26 PCCC THANKS........ PCCC ¥¥ YV ELEELELEEE RRRRRRRR ¥¥ ¥¥ EEEEEEEEEE RRRRRRRR VV YV EE RR RR VV VV EE RR RR VV VV EL RR RR VV VV EE RR RR VV VV EEEEEEEE RRRRRRRR VV VV EEEEEEEE RRRRRRRR VV VV EE RR RR VV VV EE RR RR VV VV EE RR RR VV VV EE RR RR VV EEEEEEEELE RR RR VV EEEEEEEEEE RR RR Iillii IIIIII ii II II II II ii II II II 1I IIIIII IIIIII YY YY Y¥ YY YY ~Y YY YY YY YY 000000 000000 11 000000 000000 11 O0 O0 O0 O0 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 1! O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 O0 O0 O0 O0 000000 000000 111111 000000 000000 11111! *START* USER PCAL [10707,60157] dOS SHIP SEQ. MONITOR ,wS KLIOE34 JUL-79. ,START* ~ILE: DSKH:VERIfY.O01<057>[10707.60157] CREATED: PRINTED: 21-jAN-80 23:00:45 QUEUE SWITCHES: /FILE:fORT /COPIES:I /SPACING:i /LIMIT:Il0 /~ORMS:NORMAL 815 DATk 21-0AN-80 21-jAN-80 22155:42 23:00:20 GIS VERSION 15.HO1 79/0]/26 SCHLUMBERGER COMPUTING 10707,60157 REEL HEADER LENGIH: 132 BYTES REEL NAMe: P.C.A.L, SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 80/ 1/21 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 60157 SERV1CE NAME: ~DiT TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: 01 DATE: 80/ 1/21 TAPE COMMENTS CASING DRILLER 9.625~10734/BI~ SZ-8.5/FLD TPE-SPEISEN-RE/fLD LSS b.4Mb / DENS 9.7/Vi6C 52/PH IO./BM 1.36~85 ~/RM~ 1,20~60 V/RMC 1.51@61 F/ DENS 9.7/VISC 52/PH 10./RM 1.]6~85 F/RM~ 1.20m60 F/RMC 1.51561 ~/ f'lbE HEADER LENGTH: b2 BYTES fiLE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREV1OUS ~ILE NAME: COMPANY : MARATHON OIL COMPANY WELL : %BO D-41 FIELD : MC ARTHUR R1VER RANGE : 13W SW TOWNSHIP : 8N SECTION : 6 COUNTY : K~NAI STATE : ALASKA DENSITY : 800. 1024 BYTES DATA fURMAT SPECIfICATiON LENGTH: 690 BYTES ENTR~ BLOCKS: TYPE 0 SlZk 1 RkP CODE 6b ENIR¥ 0 DATUM SPECifICATION BLOCKS: NAME TOOL UNIT AP1 AP1 APl AP1 FILE SiZE SAM R~P PROCESS INDICATORS I DEPT 2 SP D1L 3 iLO D1L 4 ILM DIL 5 LLSU D1L 6 GR D1L 7 GR CNb 8 CALl CNL 9 DRHO fDC 10 NPHI CNL 11 RHOB CNL 12 NRAT CNL 13 NCNL CNL 14 ~CNL CNL 15 GR BHC 16 CALl BHC 17 DT BHC FT 0 0 0 0 O 4 MV 7 1 0 0 0 4 OHMM 7 12 46 0 0 4 OHMM 7 12 44 0 0 4 OHMM 7 22 8 0 0 4 GAP] 7 31 32 O 0 4 GAP1 42 31 32 0 0 4 IN 42 28 1 0 0 4 G/C3 42 44 0 0 0 4 PU 42 68 ] 0 0 4 G/C3 42 35 1 0 0 4 C/C 42 42 1 O 0 4 P$ 4 34 92 0 0 4 PS 42 34 93 0 0 4 GAPi 60 31 32 0 0 4 IN bO 2 8 } 0 0 4 US/~ 60 52 32 0 0 4 1 68 1 68 1 68 I 68 1 68 1 68 1 68 1 6~ USkR DkFINED OUIPUT ARRAY OUTPUT SP AT 2 OUTPUT iLD AT 3 OUTPUT ILM AT 4 OUTPUT LLSU AT 5 OUTPUT GR AT 6 OUTPUT GR AT 7 OUTPUT CALl AT 8 OUTPUT DRHO AI 9 OUTPUT NPHI AT i0 OUTPUT RHUB AT 11 OUTPUT NRA~ OUTPUT NCNL AT 13 OUTPUT FCNL AT 14 OUTPUT GR AT 15 OUTPUT CALl AT 16 OUTPUT DT AT 17 DEPTH 11728.000 11700.000 11600.000 11500.000 11400.000 11300.000 11200.000 11100.000 11000.000 10900.000 10800.000 MNEMONIC VALUE SP -34.313 GR 71.375 NPHI -99925.000 fCNL -999.250 SP -34.750 GR 71.375 NPHI '1.074 fCNL 0.000 SP -42.750 GR 129.000 NPHI 29.395 fCNL 777.000 SP -85.250 GR 64.938 NPHI 20.410 fCNL 2037.000 SP -113.500 GR 58.063 NPHI 10.742 FCNL 3348.000 aP -87.750 GR 86.750 NPHI 12.500 ~CNL 1724.000 SP -115.500 GR 51.469 NPHI 11.035 FCNL 3024.000 SP -121.500 GR 47.688 NPHI 19.873 PCNL 1847.000 SP -117.750 GR 56.344 NPHI 16.113 FCNL 2238.000 SP -145.500 GR 45.125 NPHI 5.078 FCNL 3276.000 GR .688 NPH1 22.412 FCNL 1031.000 MNEMONIC 1LD GR GR ILO GR RHOB GR iLD GR RHUB GR ILD GR RHOB GR GR RHOB GR iLD GR RHOB GR GR RHOB 1LD GR RHOB GR RHUB GR ILD GR RHOB GR GR GR VALUE 10.508 -999.250 -999.250 -999.250 10.563 0.O00 2.000 52.750 6.352 131.750 2.488 134.625 16.156 65.313 2.480 64.438 16.781 62.250 2.539 57.063 25.547 80.O00 2.549 92.000 20.219 52.]13 2.494 62.219 16.219 41.063 2.391 39.969 15.852 53.500 2.438 54.906 68.938 42.719 2.566 40.938 8.617 105.063 2.461 106.938 MNLMONIC IbM CALl NRA~ CALl CALl NRAT CALl ibm CALI NRA1 CALi iLM CALl NBAT CALl IbM CALl NRAT CALl IbM CALl NRAT CALl IbM CALl CALl IbM CALl NRAT CALl IbM CALl NRAT CALl IbM CALl NRAT CALl IbM CALl N~AI' CALI VALUE 8.695 -999.250 -999.250 -999.250 8.695 5.035 0.000 9.90b 5.711 10.805 2.883 8.781 1].938 8.578 2.107 8.156 14.305 8.609 1.465 8.195 14.305 9.719 1.672 8.242 19.234 8.531 1.479 7.9]8 16.656 8.b02 2.074 7.740 17.516 8.b17 1.824 7.969 44.094 11.250 1.272 9.250 8.070 15.891 2.599 7.617 MNkMUNIC bbSU NCNb DT hhSU DRHU NCNb DT bbSU DRHU NCNb DT bbSU DRHU NCNb DT bbSU DRHO NCNb DT bbBU DRHU NCNb DT bbSU DRHU NCNb DT bbSU DRHU NCNb DT bLSU DRHU NCNb DT bbSU ORHU NCNb DT hbSU DRHU NCNb DT VAbU~ 9.711 -999.250 -999.250 -999.250 9.088 0.024 0.000 71.750 5.b99 0.282 2400.000 81.375 30.078 0.040 4692.000 b9.188 29.672 0.034 5256.000 b7.188 25.500 0.211 2832.000 68.56J 41.125 0.013 4756.000 06.750 24.359 0.004 4000.000 70.750 35.15b 0.004 4244.000 1j.OOO 207.625 0.320 4428.000 57.594 1.7J4 0.017 2~60.000 80.375 DLP~H 10700.000 10699.500 MNLMON1C SP GR NPHI FCNL SP GR NPHi PCNL VALUE -969.250 -999.250 45.898 406.000 -969.250 -999.250 45.313 391.500 MNLMONIC GH HHOB GR ILD HHOB GR VALUE -999.250 38.375 1.840 36.938 -999.250 39.844 1.847 40.094 MNLMONIC ibm CALl NRA'I CALl IbM CALl NRAT CALl VALUE -999.250 8.688 8.789 -999.250 8.688 3.617 8.797 MNkMONIC hbSU DRHU NCNb DT bbSU DRHO NCNb DT VAbUL -999.2b0 -0.7~1 1520.000 51.375 -999.250 1520.000 5/.594 SUMMAR~ 0~' DATA RECORDS NUMBER UF RECORDS: 147 LENGTH UF RECORDS: 958 BYTES LENGTH OK LAST RECORD: 958 BY~ES FILE TRAILER LENGTH: 62 BYTES FiLE NAME: EDiT .00! MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~ILE NAME: EOF TAPE ~RAILER LENGIH: 132 BYTES TAPE NAME: 60157 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: COMMENTS: 1024 BYTES DATE: 80/ 1/21
