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190-003
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) Cc:Brooks, Phoebe L (OGC) Subject:FW: Trading Bay Unit G-40 (PTD 190-003) - AIO 5.002 - Compliance Temperature Survey - March 2023 Date:Wednesday, April 5, 2023 11:52:08 AM Attachments:G-40 - Temperature Survey Overlay Plot - 03-09-2023.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Wednesday, April 5, 2023 11:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: Trading Bay Unit G-40 (PTD 190-003) - AIO 5.002 - Compliance Temperature Survey - March 2023 Mr Wallace, Per AIO 5.002 (Administrative Approval), Trading Bay Unit G-40 (PTD 190-003) requires a biennial temperature survey. The 2023 survey was completed on 3/9/2023. The survey data (see attached plot) is consistent with previous temperature surveys and 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/data. 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified 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 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:03/09/2023HilcorpG-40S Grayling 30 40 50 60 70 80 90 100 110 120 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 Temperature (Deg. F)Depth-MD, (feet)Perfs 16"13 3/8"9 5/8"TBG LS TBG SS Pkr Pkr RIH 2019 Temp RIH 2021 Temp RIH 2023 Temp Temperature Profile 1. Going in hole 2019L, 2021S, 2023S Overlay • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, March 13, 2017 11:16 AM To: Wallace, Chris D (DOA) Subject: G-40 compliance temp survey (PTD#1900030 -AIO 5.002) 03-09-17 Attachments: G-40 Temp Survey 3-9-17 vs 3-5-15.xIs Hi Chris, Please find attached the compliance temp survey for the G-40 well on the Grayling platform. Although we didn't get as deep as the 2015 survey, we did get —100' below the top perf and found the character of this survey agrees with the 2015 temp survey. Both surveys indicate that the injected fluids are exiting the casing at the perfs and appear to be contained in the approved injection zones (ie no cooling indicated above the packer at 9796' MD). Larry Sat*��® MAR �111Z 1 • Hilcorp Alaska LLC WeII:1G-40 Field:1Grayling 103/09/2017 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 Pressure-Temperature Profile 1000 - 1. RIH 3-5-15 vs 3-9-17 Overlay - - 2. Shut-In 2000 3000 4000 5000 CD CD 6000 2 t CD 7000 CI 8000 9000 10000 _ 11000 i 12000 40 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) — Perfs 16" 13 3/8" 9 5/8" TBG LS 3-9-17 Pressure TBG SS Upper Pkr Lower Pkr -aa- 3-9-17 Temp 3-5-15 Temp Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday, March 12, 2015 9:10 AM To: Wallace, Chris D (DOA) Subject: G-40 compliance temp survey(PTD#190003)AIO 5.002) 03-05-15 Attachments: G-40 Temp Survey 3-5-15 vs 11-22-13.xls Hi Chris, Please find attached the compliance temp survey for the G-40 well on the Grayling platform. Although shifted to cooler temperature readings (rigged up and ran the survey a little quicker than last time), the character of the survey agrees with the 2013 temp survey. Both surveys indicate that the injected fluids are exiting the casing at the perfs and appear to be contained in the approved injection zones. Larry SCANNED * . 1 IHilcorp I WeII:IG-40L I Field:1Grayling 03/05/2015 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 Pressure-Temperature Profile 1000 1. Going in hole 3/5/15 vs 11/22/13 2. Shut-In 2000 3000 _ - I 4000 5000 G1 G 6000T _ 01 7000 13 litIL \I _______ 8000 - \1411rIP" ____ 9000 \h. X 10000 mil 11000 i 12000 , I I I 1 1 1 I I 1 1 I 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) — Perfs 16" —13 3/8" —9 5/8" —TBG LS —3-5-15 Pressure TBG SS x Pkr x Pkr 11-22-13 Temp 3-5-15 Temp Page 1 of 1 • Maunder, Thomas E (DOA) From: Lambert, Steve A [salambert@chevron.com] Sent: Wednesday, May 11, 2011 10:56 AM To: Maunder, Thomas E (DOA) Cc: Brooks, Phoebe L (DOA); Cole, David A; Greenstein, Larry P Subject: G-40 Compliance Temperature Survey Attachments: 5 -08 Temp Survey.ZIP Tom, Well G-40 (PTD 190 -003) was granted Administrative Approval (AIO 5.002) for continued water injection on March 29, 2005. As required under the approval and to demonstrate continued production casing integrity, a temperature survey was run on May 08, 2011. (The survey was delayed beyond the anniversary date due to rig activity on the Grayling platform.) The survey confirms that all injected fluid has exited the wellbore at the perforations. If you have any questions regarding the attached survey please contact me. Injection well G -40 has been shut -in since March 2009. The well was shut -in at that time due to concerns about its overall effectiveness on offset producers and the presence of pressure on external casing strings. It is planned to leave this well in a long term shut -in status. The well may be returned to injection on a temporary basis if dictated by a major failure of other injection wells. Pressures will continue to be monitored daily. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 3800 Center Point Suite 100 Tel 907 263 7658 salambert @chevron.com ... y ,1UN 1 fi 23i 6/15/2011 I Chevron I W-40 1 Field:1Gra 105 -08 -2011 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 ! - -- 1 Ilk Pressure- Temperature Profile 1. Going in hole Overlay TVD 1000 i 2. Shut -In 2000 3000 ■ 4000 .611. .......,_ a) a) w- 5000 0 F- s a 6000 a) a 7000 8000 9000 10000 11000 , 1 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) — 5 -8 -11 Pressure Perfs 16" 13 3/8" -9 5/8" TBG LS SS TBG 5 -8 -11 Temp -3-13-09 Temp • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, March 03, 2011 2:49 PM To: 'Lambert, Steve A'; Regg, James B (DOA); Greenstein, Larry P Cc: Cole, David A; Martin, J. MAR 3 Subject: RE: G -40 (190 -003) Well Status. Steve, Thanks for the information. Since the well is not operating, delaying the temperature survey is no problem. Regards, Tom Maunder, PE AOGCC From: Lambert, Steve A [mailto:salambert@ chevron.com] Sent: Thursday, March 03, 2011 2:34 PM To: Maunder, Thomas E (DOA); Regg, lames B (DOA); Greenstein, Larry P Cc: Cole, David A; Martin, 3. Hal Subject: G -40 Well Status. Tom injection well G -40 has been shut -in since March 2009. The well was shut -in at that time due to concerns about its overall effectiveness on offset producers and the presence of pressure on external casing strings. The well was monitored continuously following the shut -in and external pressures did decline. In September of 2010 the Well Integrity Team performed pressure bleed downs on the 13 3/8 "(B) and 16 "(C) annuli. The bleed down data, which is shown in the attached document, confirmed that there is no direct communication between the A (9 5/8 "), B(13 3/8 ") and C(16 ") casing annuli. The A annulus appears to be maintaining integrity and the B and C annuli appear to be isolated and affected by independent pressure sources. As the second attachment shows, external pressures are continuing to decline. It is planned to leave this well on a long term shut -in status. The well may be returned to injection on a temporary basis if dictated by a major failure of other injection wells. Pressures will continue to be monitored daily and the well remains on the list of Grayling platform long term abandonment candidates. Well G -40 and well G -27 are scheduled for MIT temperature surveys at the end of March. Due to the current rig activity on the platform it will not be possible to obtain the survey's at that time. With your permission, we would like to postpone the MIT temperature surveys for these two wells and perform them in conjunction with the MIT temp survey scheduled for G -23 in June of this year. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 3800 Center Point Suite 100 Tel 907 263 7658 salambert@chevron.com 3/3/2011 G -40 "C" Annulus Pressure Bleed Diagnostics 900 "B" Initial 800 773 psi 700 "C" Initial , 712 psi - @ 7:15 (9 -5 -2010) "B Final 766 psi 600 • 500 "C" End of 24 Hr Build, 351 psi @ 8:41 (9-6-2010) 400 "A" Initial 307 psi 300 "A" Final 310 psi 200 "C" End of Bleed, 7 psi @ 8:41(9 -5 -2010) 100 0 4:48 9:36 14:24 19:12 0:00 4:48 9:36 14:24 19:12 G-40 "A" Annulus G-40 "B" Annulus G-40 "C" Annulus G -40 "B" Annulus Pressure Bleed Diagnostics 800 "B" initial 759 psi @ 15:00 (9 -9 -2010) 700 4 - - - - - -- 600 _... _._ "C" Initial , 472 psi "C" Final • 500 499 psi 400 "A" Initial "A" Final 300 309psi ,,,,�, 307 psi "B" End of Bleed, 5 psi 200 @20:57 (9 -9 -2010) "B" 24 Hr Build , 268 psi 100 �_ - @ 20:57 9 -10 -2010 0 I - - - 9:36 14:24 19:12 0:00 4:48 9:36 14:24 19:12 0:00 4 :48 -- - "A" Annulus —"B" Annulus —"C" Annulus g -40 Pressure Observations 1400 1 -1 1200 Hours - 1 •Tubing 1000 - •9 5/8" 1 •13 3/8" 16" 20" 1 800 v Rate 3 1 ce o. 600 I 0 0 400 - .p - Inikr 0 • 0 200 — -o 0 , 0 07/06/09 10/14/09 01/22/10 05/02/10 Time 08/10/10 11/18/10 02/26/11 06/06/11 Printed on 3/3/2011 at 2:46 PM g -40 Pressure Data 2011 03 02.xlsx 2011 February's Waivered Injection Well Report Page 1 of 2 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, March 03, 2011 10:02 AM To: Maunder, Thomas E (DOA) Subject: RE: 2011 February's Waivered Injection Well Report—TBU G-40 (190 -003) Tom, I've got Steve Lambert putting together the update on G -40 for you. It looks like this well has come off the abandonment list due to some timing issues, but Steve will be sending a proper update to you soon. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, March 03, 2011 9:48 AM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A Subject: RE: 2011 February's Waivered Injection Well Report- -TBU G -40 (190 -003) Larry, et al, I have looked at our file for this well and we exchanged some messages in early January. Are there any plans for G-40 other than LTSI? In the prior messages, the well was mentioned as a candidate for "Phase 1 abandonment ". I am aware some activities are presently underway on Grayling. Is or might G -40 be part of that work? Tom From: Maunder, Thomas E (DOA) Sent: Thursday, March 03, 2011 8:53 AM 5 MAR 0 3 2011 To: 'Greenstein, Larry P'; Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A Subject: RE: 2011 February's Waivered Injection Well Report Thanks Larry. Could either Steve or Hal provide some information on G-40? I remember having talked about that well, but not the specifics right now. I will check my files as well. Thanks in advance. Tom M n r au de PE AOGCC From: =44 stein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Thursda k ch 03, 2011 8:47 AM To: Maunder, Thoma - DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, - e A Subject: 2011 February's Waivere• •'ection Well Report Hi Tom & Jim, Here is February's monthly report for all the active monitored injection - s. Due to drilling's concern over the pressure profile of the G -40 well, we will not be usi is well for the 3/3/2011 0 Plot�essure & Rate vs Time - Well G -40 1000 - 200 •9 5/8" 13 3/8" 180 900 — 16" '''"*20" Tubing 800 — ... — - — 160 Vol 700 140 600 120 r n 500 ....._.. -..._ ____ - -- _........_ _ -..- _._- _. __._ _._. __ -... 10;2 V2 m 400 ri 80 1• 300 1 60 200 _. _._-__ -- __._._ __ -- -_- _ ___ ____ _ 40 100 .. -. _. _. - - -- _ 20 0 0 0 0 0 0 0 M N N 0 co N N 0 0) 0 � 0 0 Date 13 3/8" 16" 20" Tubing Vo Vol TIO eport 02/28/11 690 625 77 375 0 02/27/11 690 625 77 375 0 Data Sheet 02/26/11 680 625 78 350 0 02/25/11 680 625 78 350 0 02/24/11 680 625 78 350 o G -40 02/23/11 680 625 76 350 0 02/22/11 680 625 76 350 0 02/21/11 680 625 76 350 o INJECTION 02/20/11 680 630 76 350 0 02/19/11 680 630 76 350 0 02/18/11 680 630 76 350 o Permit # 1900030 02/17/11 680 630 77 350 0 02/16/11 680 630 77 350 0 02/15/11 680 630 76 350 0 1dmin Approval # AIO 05.002 02/14/11 685 630 78 350 0 02/13/11 685 630 78 350 0 02/12/11 685 630 78 350 0 API # 50- 733 - 20412 -00 02/11/11 685 630 78 350 0 02/10/11 685 630 78 350 0 02/09/11 685 630 78 350 0 08/30/2010 to 03/01/2011 02/08/11 685 630 78 350 0 02/07/11 685 630 78 350 0 02/06/11 680 625 78 400 0 02/05/11 680 625 78 400 0 02/04/11 690 625 78 400 0 02/03/11 690 625 78 400 0 02/02/11 780 630 78 400 0 02/01/11 780 630 78 400 0 0 01/31/11 690 630 76 350 0 01/30/11 690 630 76 350 0 01/29/11 690 620 72 350 0 01/28/11 690 620 72 350 0 01/27/11 690 620 72 350 0 01/26/11 690 620 72 350 0 01/25/11 690 620 72 350 0 01/24/11 690 620 72 350 0 AM 3/3/2011 10:37 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 01.xis G -40 2010 December's Waivered InjectiWell Report • Page 1 ofet Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, January 13, 2011 9:19 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) \Q Cc: Martin, J. Hal; Lambert, Steve A Subject: 2010 December's Waivered Injection Well Report Attachments: Master Well List TIO Report 2011 01 01.xis Hi Tom & Jim, Here is December's monthly report for all the active monitored injection wells. Most of the wells are trending along as expected. The G -40 well still looks like a good candidate for the upcoming plugging work (as we discussed last month), although I haven't heard any updates lately. The exception is the Anna MUCI -3 well. Until the Anna gets filtered seawater available again for this well, they have gone to small volume batch injection events of 10 -15 bbls at a time, usually once a day. As the well sits unused nearly the entire day, the tubing and casing pressures sit at zero. The small batches result in nothing more than loading up the tubing /casing and then it's over. The pressures don't show any response to this type of usage. We are installing pen charts to see if the short duration injections result in any pressure response from the well, but realistically, we may still just see zeros from both the tubing & the casing. When we can resume getting filtered seawater back to this well, the normal volumes and pressures are expected to return. No other anomalies appeared in the rates or pressures of the other wells this last month. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2011 01 01.xis» %OWED JAN 1 9,21111 Sure Tom. It's still under discussion a bit,,but the G -40 well has been showing some essures on the outer casings that intrigued us. We performed a few-diagnostics to see if the pressures re onetime events or were communicating between strings or co?rii from elsewhere. Per the attached plot, it appears the 13 3/8" and 16" a seeing pressures that aren't coming from the tubing or 9 5/8" side. Since we had planned to do some Ja ment work on G -24 & G -25, we're considering adding G -40 to the list and then figuring out what we u d do to t - ell. Talking with drilling, the fix may be a ase I and Phase II abandonme This would entail plugging off the perforations (Phase I) and then gs and cement work around other casing • 'es (intermediate plugs or Phase II). How far the abandonm9p goes with all three of these wells is what's being di ssed. We want to keep them safely shut -in or suspeud‘d until the rest of the platform is ready for abandonment an. .t's what the discussions are about...what w' that require for each one of these wells. Anythin plan to do to these wells will be sent to you for approval with a sundry from drilling...you'll . •ably kno at the final plan is before I do. 1/13/2011 Plot pressure & Rate vs Time - Well G -40 • 1000 - 200 900 180 800 160 700 140 "9 5/8" 120 16" E 20" 2 500 10 Tubing -- __ co a Vol G -40 400 80 300 1 60 200 — _ -- 40 100 ~, - - 20 0 r '0 0 0 0 0 0 0 0 O M M N N N CV n CO a o 0 0 0 0 Date 13 3/8" 16" 20" " 'off Vol G -40L TIO Report 01/01/11 695 600 73 0 12/31/10 695 600 73 350 0 Data Sheet 12/30/10 690 600 73 350 0 12/29/10 690 600 73 350 0 12/28/10 685 600 73 350 o G -40 12/27/10 685 600 73 325 0 12/26/10 680 600 74 325 0 12/25/10 680 600 74 325 o INJECTION 12/24/10 680 600 74 325 0 12/23/10 680 600 74 325 0 12/22/10 680 640 78 350 0 Permit # 1900030 12/21/10 680 640 78 350 0 12/20/10 680 640 78 350 0 12/19/10 680 640 78 350 0 1dmin Approval # AIO 05.002 12/18/10 680 640 77 350 0 12/17/10 690 650 79 350 0 12/16/10 690 650 79 350 o API # 50- 733 - 20412 -00 12/15/10 690 640 77 350 0 12/14/10 690 650 79 350 0 12/13/10 700 665 82 350 0 07/01/2010 to 01/01/2011 12/12/10 700 665 82 350 0 12/11/10 700 665 82 350 0 12/10/10 700 665 82 350 0 12/09/10 705 665 82 350 0 12/08/10 705 665 82 350 0 12/07/10 705 665 82 350 0 12/06/10 705 670 81 340 0 12/05/10 705 670 81 340 0 12/04/10 705 670 81 340 0 12/03/10 705 670 80 340 0 12/02/10 710 670 80 340 0 12/01/10 710 670 80 340 0 11/30/10 710 670 80 340 0 11/29/10 710 670 80 340 0 11/28/10 710 670 80 400 0 11/27/10 730 670 82 400 1/13/2011 9:57 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 01 01 (6).xls G -40 2010 November's Waivered Inject,Well Report • Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, December 09, 2010 1:17 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A kok0 —00 3 Subject: RE: 2010 November's Waivered Injection Well Report Attachments: Master Well List TIO Report 2010 11 30.xls; G -40 Schematic 1- 24- 07.doc Sure Tom. Q., — L-VO It's still under discussion a bit, but the G -40 well has been showing some pressures on the outer casings that intrigued us. We performed a few diagnostics to see if the pressures were onetime events or were communicating between strings or coming from elsewhere. Per the attached plot, it appears the 13 3/8" and the 16" are seeing pressures that aren't coming from the tubing or 9 5/8" side. Since we had planned to do some abandonment work on G -24 & G -25, we're considering adding G -40 to the list and then figuring out what we would do to the well. Talking with drilling, the fix may be a Phase I and Phase II abandonment. This would entail plugging off the perforations (Phase I) and then plugs and cement work around other casing shoes (intermediate plugs or Phase II). How far the abandonment goes with all three of these wells is what's being discussed. We want to keep them safely shut -in or suspended until the rest of the platform is ready for abandonment and that's what the discussions are about...what will that require for each one of these wells. Anything we plan to do to these wells will be sent to you for approval with a sundry from drilling...you'II probably know what the final plan is before I do. Hope this helps and let me know if you want me to dig further. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 09, 2010 9:54 AM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A Subject: RE: 2010 November's Waivered Injection Well Report Larry, et al, Can you provide some information on G -40 and also what "Phase 1 abandonment activities" are? I have not had a chance to look at the well file. Thanks in advance, Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Tuesday, December 07, 2010 1:59 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A Subject: 2010 November's Waivered Injection Well Report Hi Tom & Jim, 1/13/2011 2010 November's Waivered Inject Well Report Page 2 of 2 Here is November's monthly report for all the active monitored injection wells. The G -40 well has been added to the Phase I abandonment activities planned for Grayling due to the observed pressure responses of the various annuli. The Monopod is still having lots of ups and downs which makes the data look real erratic, but watching the trends in the data indicates that nothing out of the ordinary appears to be occurring. No other anomalies appeared in the rates or pressures of the other wells this last month. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2010 11 30.xls» 1/13/2011 G-40 Compliance Temperature Survey Regg, James B (DOA) Page 1 of 1 From: Lambert, Steve A [salambert@chevron.com]~i,Lt ~~ Sent: Thursday, March 26, 2009 11:26 AM ~ (~~_ap3 To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P Subject: G-40 Compliance Temperature Survey Attachments: 3-13-09 vs 9-20-06 Temp Survey.ZlP Well G-40 (PTD 190-003) was granted Administrative Approval (AIO 5.002) on March 29, 2005. As required under the approval, afollow-up temperature survey was run on 3-13-09. The survey confirms that all injected fluids are being contained within the perforated intervals. Please contact me if you have any questions regarding the survey. «3-13-09 vs 9-20-06 Temp Survey.ZlP» ~~ ,~ Air ~: 3/31 /2009 Chevron Well: G-40 Field: Grayling Date 03-13-2009 5000 150 4500 4000 3500 ~ 3000 Q ~ 2500 d a 2000 1500 1000 500 0 1 Run in hole Well Static Pulling out of hole Static Gauge at depth 11025' RKB ?.00 13.00 14.00 15.00 16.00 17.00 18.00 19.00 20.00 21.1 Time (hrs) Pressure Temperature 140 130 120 110 100 ~ d L 90 ca L 80 ~ 70 60 50 40 30 ~0 I I~c~-~ Chevron Well: G-40 Field: Grayling 03-13-2009 1000 2000 3000 4000 .~. ~ 5000 ... ~ 6000 t ~ 7000 D 8000 9000 10000 11000 i 12000 0 .....~ ~0 ~i, f l.~-Cw5 Chevron Well: G-40 Field: Grayling 03-13-2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 ;~ Pressure-Temperature Profile 1. Going in hole wl May06, 1000 - Sept.06 Overlay 2. Shut-In 2000 i 3000 -- - - - - -- -- - - ~ - - ~. 4000 -- - - ------ - ~~ ~~. ~ 5000 - -- ~'' ~ ~~ ~ 6000 .C Q ~ - -- -. ~ 7000 ~~~` 8000 '- 9000 - - I 10000 ~, 1. 11000 --- 12000 50 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) RIH Pressure 09 - Perfs 16" ', 13 3/8" 9 5/8" TBG LS ' RIH May06 Psia TBG SS Psia Sept 06 RIH Temperature RIH May Temp Temp Sept 06 ~~ Ick~;-~~c?~ Chevron Well: G-40 Field: Grayling 03-13-2009 10 20 30 40 A~ 50 W ~F ~/ c 5~ 60 ^~ y ~~ 70 80 90 100 110 120 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 50i 0 0 ~ I k Pressure-Temperature Profile 1 POOH Overlay wlSept 06, 06 March 09 Ma , y 2. Shut-In 00 00 - 00 00 1 ~~ 0 - << s Y R.. L 00 - ~~4, - 00 - _- 00 ,~A ~r 00 -.--. _ ~ ~' 00 - 00 -- - 50 60 70 80 90 100 110 120 130 140 1E Temperature (Deg. F) POOH Pressure 09 - Perfs 16" 13 3/8" 9 5/8" TBG LS -- POOH May06 Psia TBG SS Psia Sept 06 RIH Temperature POOH May Temp Temp Sept 06 )0 0 ,D~ 11~ - Gv3 Chevron Well: G-40 Field: Grayling 03-13-2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1000 2000 3000 4000 ~ 5000 ~ 6000 s Q ~ 7000 8000 9000 10000 110001 12000 60 Pressure-Temperature Profile 1 Pull out of Hole from 11025' RKB 2. MAKING STOPS 3. Well Shut-In 1k1d TVD Pressure Temp P-Grad T-Grad (feet} (feet} (psia} (~eg.F I;psb'ft} Deg.FJft 39.7 39.7 319.45 64.84 - - 2001.1 2001.0 1184.94 75.03 0.4413 Q52 4001 3 3922 88 0 4423 0 30 9 203 02 80 . . . . . . 6000.2 6766.4 2849.62 94.98 0.4419 0.76 8000.1 7619.6 3666.96 112.24 0.4410 0.93 10000.6 9445.2 4472.88 116.34 0.4416 0.17 11025. 4 10387. 2 4887.$ 6 136. 60 0.44 05 2 .25 - i I 70 80 90 100 110 120 130 140 Tem erature De . F Pressure - Perfs 16" 13 3/8" ~ ~./A" TR(` I C TR(` CC Tcmn i ro-c;~ ~ Chevron Well: G-40 Field: Grayling 03-13-2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 _. f ---•• Pressure-Temperature Profile 1 Going in hole & POOH ' 1000 Overlay TVD 2. Shut-In 2000 3000 ---- - - 1 5E L 4000 - `' .-. d ~ `~' 5000 -- -- - F- ~ F ~ 6000 - '' y s ID Y 7000 ~i I 8000 --- - -' I 9000 - ..~-. . . ~~ 10000 - 11000 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) ~'~ RIH Pressure - Perfs 16" 13 3/8" 9 5/8" TBG LS POOH Psia ~------SS TBG - - -RIH Temperature POOH Temp _ _ s //~~ ,~~))~ Regg, James B (DOAj ~ ~~U l U~~ From: Regg, James B (DOA) <'°~ , ~., ~.; f~; Sent: Wednesday, December 26, 2007 5:23 PM L To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA) Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Larry -Each of the fisted admin approvals did not establish a formal anniversary date for determining when to perform compliance temperature surveys. There has been some confusion that has resulted. Based on what !have read below and our conversation earlier today, !believe using the effective date (signature date) of the administrative approvals is consistent with your request for nearly all wells accomplishes what you are after (efficiency}. The wells you reference below are (with a due date for the next temp survey}: Granite Pt State {Anna) 19 - AIO 6.008 (3/29/2005); next temp survey due 3/29/2009 Granite Pt State (Anna) 21 - AIO 6.009 (3/29/2005); next temp survey due 3/29/2009 TBU G-11 - AIO 5.009 (12/15/05); next temp survey due 12/15/2009 (yo.a suggested 912009) TBU G-22 - AIO 5.006 (9/14/2005); next temp survey due 9(14!2009 TBU G-23RD - AIO 5.004 (6/30/2005); next temp survey due 6/30/2009 (you suggested 312009) TBU G-27 - AIO 5.003 (3/2912005); next temp survey due 3129/2009 TBU G-29RD - AIO 5.007 {9123/2005); next temp survey due 9/23!2009 TBU G-40 - AIO 5.002 (3/2912005); next temp survey due 3/29/2009 TBU K-11 - AIO 5.011 (2/6/06); next temp survey due 2/6/2010 TBU K-24RD2 - AIO 5.010 (2/6/06}; next temp survey due 2/6/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells}. This does not affect any admin approvals that have anniversary dates specifically listed in the conditions. Jim Regg AOGCC 333 W.7th Avenue, Suite 10fl Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing for me to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3!29105 -last compliance temp survey 10x`3!06. Would like to slide 10108 temp survey to 3109 to get on AA anniversary date cycle. An-21 - AA signed 3!29x`05 -fast compliance temp survey 10/4;'06. Would like to siide 10108 temp survey to 3!09 for the AA date reason. K-11 - AA signed 216/06 -last compliance temp survey 12?11i07 lust sent to you}. Would like to slide 12;09 temp survey to 2/10 for the AA date reason. 12/26/2007 ~- - °-a- - ~-- K-24RD2 - AA signed 2f6f06 - last c arcs temp survey 12f21f07 (will send to•soonj. Would like to slide 12/09 temp survey to 2110 for the AA date reason. The Grayling wells have some other things going on. We have wells with AA anniversary dates in every quarter. f sure would like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RD forward from June to March and G-11 forward from December to September. This way only two wells get off the AA anniversary date cycle and we'll have three wells due for temp surveys each visit. G-11 - AA signed 12f15f05 -last compliance temp survey 6I25f07. Would like to slide to 6109 temp survey to 09f09 for efficiency. G-22 - AA signed 9f14!05 -fast compliance temp survey 4/26f07, Would like to slide 4f09 temp survey to 9109 for the AA date reason. G-23RD - AA signed 6f30r'05 -last compliance temp survey 4/19107. Would like to slide 4109 temp survey to 3/09 for efficiency. G-27 - AA signed 3f29/05 -last compliance temp surrey 9121;06. Would like to slide 9r`03 temp survey to 3/09 for the AA date reason. G-29Rt~ - AA signed 9f23/05 -last compliance temp survey 6!24/07. Would Bice to slide 6,`09 temp survey to 9/09 for AA date reason. G-40 -AA signed 3f29f05 -last compliance temp survey 9!21x`06. Wouid like to slide 9108 temp survey to 3!09 for AA date reason. I hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. Larry 263-7661 12/26/2007 ~~ / 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these wells did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L. Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. Options Next Temp Survey Due, Based on AA Date1 AA Date2 Last Survey 3/29/2007 3/29/2009 10/3/2008 3/29/2007 3/29/2009 10/4/2008 12/15/2007 12/15/2009 6/25/2009 9/14/2007 9/14/2009 4/26/2009 6/30/2007 6/30/2009 4/19/2009 3/29/2007 3/29/2009 9/21/2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2/6/2010 12/11/2009 2/6/2008 2/6/2010 12/21/2009 last update: 12/26/2007 Well PTD AA Anniversary Date AA Date Last Survey GP State An-19 168-006 6.008 3/29/2005 10/3/2006 GP State An-21 176-049 6.009 3/29/2005 10/4/2006 TBU G-11 168-043 5.009 12/15/2005 6/25/2007 TBU G-22 175-016 5.006 9/14/2005 4/26/2007 TBU G-23RD 179-014 5.004 6/30/2005 4/19/2007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2/6/2006 12/21!2007 GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) Next Survey Due (Chevron Proposed) Next Survey Due (AOGCC) Which Option? 3/29/2009 3/29/2009 AA Date 3/29/2009 3129/2009 AA Date 9/30/2009 12115/2009 AA Date 9/30!2009 9!14/2009 AA Date 3/30/2009 6/30/2009 AA Date 3/30/2009 3/29/2009 AA Date 9/30/2009 9123/2009 AA Date 3/30/2009 3/29/2009 AA Date 2/28/2010 2/6/2010 AA Date 2/28/2010 2/6/2010 AA Date G -40 Compliance Temp Survey required under Admin Approval AIO # 5.002 Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, November 13, 2006 2:30 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) kc ...®0"z Cc: 'Lambert, Steve A' l Subject: G -40 Compliance Temp Survey required under Admin Approval AIO # 5.002 Attachments: G- 40Schm4- 26- 90.doc; G -40 Temp Survey 9 -20 -06 vs 8- 29- 04.zip Tom & Jim, Unocal is forwarding the compliance temperature survey to demonstrate production casing integrity under Administrative Approval # AIO 5.002 (approved 3/29/05) for the continuation of water injection in the Grayling Platform Well No. G -40 (PTD # 1900030) in Trading Bay Unit. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. MD and TVD temperature survey comparison plot (attached). The temperature survey run on 9/20/2006 shows no cooling anomaly changes above the packer from the last survey run on 8/29/2004. This indicates that injection is occurring only into the Hemlock and West Foreland sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run again in two years as required to confirm the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263 -7661 or Steve Lambert at 263 -7658. Larry «G- 40Schm4- 26- 90.doc» «G -40 Temp Survey 9 -20 -06 vs 8- 29- 04.zip» NOD JAN 7 Z01 1/13/2011 (Unocal Well:IG -40 I Field: IGrayling 109 -20 -2006 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0' = Pressure - Temperature Profile 1000 1. Going in hole & POOH - — - Overlay TVD 2. Shut -In 2000 3000 4000 - - -. • a CD 5000 - CS 6000 CL 7000 - 8000 9000 10000 11000 50 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) —9-20-06 Pressure — Perfs 16" 13 3/8" —9 5/8" —TBG 9 -20 -06 Temp •8 -29 -04 emp \r:::::'\,' U' r?¡ 1 i I ; ¡,¡i¡ ¡r~ \0U ) ~' ¡-' (Ä" (Q:" ¡ '. ! Iii ii' 1 ii\ \" Ii , i ff~,!' '\" \, QJ,,' 'fLJ\ 'I ,0' ,\ ¡ ;=; \ f ',~ \~ 'n)))! ,¡ u~u Ui~, ) ,m lln l ~.]I, '~ / llj / I I f j FRANK H. MURKOWSK/, GOVERNOR AT,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 5.002 Mr. Larry Greenstein Production Technician U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ~"a"~ h ~"'~~~Ei"\, non c» (/\, 2005 dt'ß··U~~'~,,_,P.!, HI" n t.,; v - " RE: Trading Bay Unit G-40 [aka Grayling 40] (PTD 190-003) Request for Administrative Approval AIO 5 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 005, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal's") request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. This well was originally reported to have not passed a MIT in August 1997. 2. Multiple diagnostic logs were run between then and September 1999. 3. Based on successive temperature log analysis that demonstrated that fluids were being confined to the intended injection zone, Unocal was approved to continue injection by Sundry permit 399-190 approved October 6, 1999. 4. As required by the Sundry permit, Unocal has been recording daily injection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the results of addi- tional temperature logs and a graphical maximum operating pressure determina- tion. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any further pressure integrity loss. 6. At this time, Unocal is not proposing to repair the well to restore full integrity. 7. An aquifer exemption is in effect below Cook Inlet for Trading Bay Unit (McArthur River Field) [40 CFR 147.102(b)(2)(ii).] Based on analysis of the submitted information, the Commission concludes that TBU G- 40 exhibits two competent barriers to release of well pressure. Accordingly, the Com- Mr. Larry Greenstein March 29,2005 Page 2 of2 ) ) mission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Trading Bay Unit G-40 [aka Grayling 40] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commiss' decision to Superior Court unless rehearing has been requested. , Alaska and dated M@w Daniel T. Seamount, Jr. Commissioner ~ o7i~~ ~,~~ .!ÍJI,,^ ~... ,., J :-t y-(.J ,'j;':'#"'ï!! \ !~í~ø' f " riLl/"'-../ , ' ...... "i':~~ ~~-~~ ,....-J . ~,""_~~\;~t,,\V~,"·,;,'..'),~~\: : ~ i '~~.m v\ \:':ti;{;J.<:\\t , ¡L· .J1.~!I ~ 0 . ~ ~!~r~~~\¡i~,--'i ' Q \~l ~"',.."..^, V.),·,.""" ~ ~ .~ :/. '~.4. ~ ~:·~}.:~:t~.;:~~: ~f\:~:: ;:,~'.,~ ~,~::(Yl;.:;,,~~ ~ ~ ~""",>,,,,,.,,,,,¡,,,,,;,,,,, .J¿f}~ +~~,~~n;i¡:¡~W "'~ ~"u¿"J ~,}J~ ' ~~_~~oo.V*' ) Unocal Alaska ) Union Oil Company of California .. 909 West 9th Avenue, P.O. Box 196247 Anchorage. Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 to UNOCALe Larry P. Greenstein Prodction Technician Date: February 22, 2005 SC,ANNED !\PR 2. 0 2.0DS Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ih Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. G-40 Injector Grayling Platform McArthur River Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 5, Rule 9 for the continuation of injection of non-hazardous Class II fluids for the Grayling Platform Well No. G-40 Injector (Permit # 190-003) in McArthur River Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled as a water injector in April of 1990. Per the attached well history, it has been injecting with a variance since October of 1999. In addition, please note that McArthur River Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(ii). The temperature survey run on 8/29/2004 matches the last survey run on 1/16/2002 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Hemlock and West Foreland Sands. The plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. ) ) Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Steve Lambert at 263-7658. Sincerely, -d?~ /! Larry P. Greenstein cc: MIT book Well File ~ UNOCALe RKB to TBG Hngr = 40.8' Tree connection: Dual 3" 5,000# ~uspected tbg leaks I n 55 between 900' & 1200' ~ L. L B ~Plnner survey onfirmed 1bg leaks @9812'& 10,125' ) SIZE 16" 13-3/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" Tubing: ~ LS 3-lt2" \ ~ SS 3-lt2" ~2,72" LIB ran on I suspected CS9 leak between 3350' & 3250' ~ _2 [ : - {} _ B-4 3 :J:C 4 ~ 5 6 7 = WF-2 = 8 ::::: WF-3 ~ WF-5 WF-6 = WF-7 ::.. 8/6/97 shows tbg to be oblonged 2,72" X 2.68" @ 5,012' B-1 75 68 47 47 47 47 47 9.2 9.2 NO. ) WT GRADE K-55 S-80 & K-55 K-55 N-80 S-95 N-80 S-95 CONN Butt Butt Butt Butt Butt Butt Butt CASING AND TUBING DETAIL MD TOP Surf. Surf. Surf 47' 9765' 10,929 11,146' N-80 N-80 Butt Butt LS ID 15.124 12.415 8.681 8.681 8.681 8.681 8.681 2.992 2.992 Trading Bay Unit Well # G-40 Completed 4/26/90 0' 0' MD TVD BTM. BTM 1926' 5128' 47' 9765' 9220' 10,929' 10,300' 11,146' 10,500' 11,232' 10,606' 10,463' 9870' 9827' 9290' 40.80' JEWELRY DETAIL ID Item Cameron DCB Dual 3-lt2" Tubing hanger. SHORT STRING A B C D 2 3 4 5 6 7 8 SLICKLINE TAGS SS Tag "XN" w/ 2.72" GR LONG STRING Otis" BWH" Perm Pkr Otis Seal Bore Ext. 3-lt2" Otis "X" Nil)ple WLEG 8/5/97 8/6/97 8/7/97 STIM ULA TIONS 2 stag acid job wi diverter, 50 bbls of DCL & 75 bbls of 3/29/90 6-1/2% X 1-1/2" mud acid 2 stag acid job, 40 bbls of DCL & 135 bbls of 6-112% X 1-1/2" 3/29/90 mud acid 3-lt2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RDH" Dual Packer, SS set 3-lt2" Otis "XN" Nipple, 2.75 Ball Catcher Sub 3-lt2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RHD" Dual Packer 3-1/2" Otis "XA" Sliding Sleeve Otis Straight Slot Locator w/8.8' of seals (10,500' OIL) @ @ @ 9813' Depth 9760' 2.75 9796' 2.90 98]3' 2.635 9825' 2.99 btm 9827' 9762 2.75 9798' 2.90 10,348' 2.75 10,385' 2.95 DPMD 10,378' 4.00 DPMD 10,383' 4.00 btm 10,390' 10,428 2.75 10,582' 2.95 htm 10.583' 5,012' 11,086' Tagged obstruction w/ 2.72" GR & 2.72" LIB Tag fill w/ 2.25" LIB WIRELINE WORK LS . Spinner ran on 1/22/98 indicates tbg leaks @ 9812' & 10,125' . WFL ran on 1/23/98 indicates csg leak between 3250' & 3350' . . WFL indicated multiple SS tbg leaks, sldg slve @ 9760', tbg jt between sldg slve & pkr and between 1200' to 3400' . West Forland HB-l & 2 PERFORATION DATA Accum. Date Zone Top Btm Amt SPF Last Opr. Present Condition 9,880' 9,882' 2' 4 3/20/90 Cmt Sqz B-1 9,892' 9,926' 34' 8 3/28/90 Open f/lnjection 8~:):'~:~:??~:}}7:::::::::::: 9,934' 9,936' 2' 4 3/19/90 Cmt Sqz 10,111' 10,113' 2' 4 3/18/90 Cmt Sqz ./..,.,.,.""""""."'~ B-4 10,128' 10,208' 80' 8 3/28/90 Open f/lnjection RT to MLLW ELEV = 103' 10,218' 10,220' 2' 4 3/18/90 Cmt Sqz TD = 11,267' ETD = 11,143' 10,455' 10,457' 2' 4 3/17/90 Cmt Sqz WF-2 10,525' 10,565' 40' 8 3/25/90 Open f/lnjection MAX HOLE ANGLE = 27.2° @ 8900' WF-3 10,680' 10,770' 90' 8 3/25/90 Open f/lnjection WF-5 10,833' 10,888' 55' 8 3/25/90 Open f/lnjectlon WF-6 10,915' 10,972' 57' 8 3/25/90 Open f/lnjection WF-7 10,993' 11,040' 47' 8 3/25/90 Open f/lnjection 11,042' 11,044' 2' 4 3/17/90 Cmt Sqz G-40Schm4-26-90.doc REVISED: 2/2/98 DRAWN BY: SLT " ) J-40 Temperature Survey:s 1/16/02 vs 8/29/04 o o 500 1000 1500 Pressure (psia) 2000 2500 3000 3500 4000 4500 I 5000 5500 ç~ ~ 8000 "-< ~ l Pressure-Temperature Profile 1. Going in hole 2, Shut-In 1000 2000 3000 4000 .-. .... CI) ~ 5000 - ... c ::i I .t: 6000 .... Q, CI) C 7000 9000 ~ 10000 - >¿ - - - - I ~ 11000 - I I I I I 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) - 8/29/04 Pressure - Perfs -95/8" -TBG -16" -133/8" -8/29/04 Temp -1/16/02 Temp O:\OOE\OOEFields\TBU\Grayling\Wells\G-40Inj\Surveys\Temp\G-40 Temp Survey 1-16-02 & 8-29-04.xls 1.OOO 2,000 3,000 4,000 5,000 c ~ - .c 6,000 ..., c. CD C 7,000 8,000 -- 9,000 -- 10,000 - 11,000 - 12,000 G·40 Maximum Allowable Operating Pressure Graph o o I 3,000 Pressure (PSI) 4,000 5,000 6,000 1,000 2,000 ~ I .., I , \ II I I ....., I . P \ 'r Variable Definitions --RP--= -Re-servoirPre'Ssure~ CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus; 45% for HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore_, '" ,. ,,_,__,_u,_,,_,___.._u_,__,.______ Hf> + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP --- -.- - - -Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft - Production CYP @ 70% - Outside Containment for Production casing -MASP (production casing) -Intermediate CYP @ 45% -Outside Containment for Intermediate casing - MASP (Intermediate casing) .~- Surface CYP @ 45% - Outside Containment for Surface casing - MASP (Surface casing) . Current Pressure Readings 7,000 8,000 9,000 10,000 1 1 1 R~ date: 2/16/2005 1 :46: 15 PM sJ~ operating pressures (suñace gauge) Prc1uc.'ion = 2300 psi. @ 70% nominal casing yield Interme1iate = 128 psi. @ 45% nominal casing yield Su 'ace = 513 psi. limited by fracture pressure at shoe Curentfressure readings TB~PRES... = 0 CS :;PRES32 = 0 CS :;PRESS~ = 600 CS :;PRESS4~ 425 CS 3PRESS5 5 - Casing Deta s Prduction Segm nt = 9,625" 47#, N-80 internal yield = 6870 psi from 1514' to 11232' MD' t-'rduction Segme t = 9.625" 41#, S-95 internal yield = 8150 psi from 10061' to 11232' MD' Prc::luction Segme = 9,625" 47#, N-80 internal yield = 6870 psi from 11015' to 11232' MD' Prduction Segmen = 9,625" 47#, S-95 internal yield = 8150 psi from 11146' to 11232' MD' Prduction Floatsho = 9,625" #. internal yield = N/A psi from 11230' to 11232' MD' IntEïl11ediate casing = 3.375" 68#, K-55 internal yield = 3450 psi from 1996' to 5128' MD' IntE 'mediate casing = ,375" 68#, S-80 internal yield = 3450 psi from 3174' to 5128' MD' Su :ace casing = 16" 7 . K-55 internal yield = 2630 psi from 45' to 1926' MD' Co ductor = 20" #, 1" W LL internal yield = N/A psi from 45' to 421' MD' Casing Parameters Assumptions Prduction casing yield @ % of nominal with fluid weight of 0.433 #/ft Inte-mediate casing yield @ 5% of nominal with fluid weight of 0.433 #/ft Su :ace casing yield @ 45% f nominal with fluid weight of 0.433 #/ft Fr~ture gradient = 0,7 #/ft Prqram attempts to model infl ence of depleted sand reservoirs AP : 507332041200 Pe 'llit : 1900030 '- Workbook: G-40 Casing Pressure p.!. alysis @70 percent 20050216.xls _~_ __ _n.. I I Disclaimers (fine print) Casing yield values taken trom published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +1- 25 ft @ 10,000 ft, MD 1 ~ '-" -- \ \ \ ~-/ Graphical Casing Pressure Analysis ver 22x.xls ) ') {' ( UIC File Review Subject July 23, 2002 Unocal TradingBay Unit (TBU) 0-40 (Water Injector) Date: PTD#: 190-003. . . 302-217 Orders: CO 80 (Subsequemorders 234A, 284 and 350 allowed commingHng) Al05 ~om Maundet, P R lt2..E.. .... .. -1.. :H... "" -0 ~ 11m Regg ~ 1~d-v >~ Applica.tion for Variance Re\li~wers: Initiating Action: ,~ Review Summary 1. Unocalsubmitted request dated 7/15102 (received 7/16/02) to continue injection and provided the latest temperature survey conducted on the wen~ presented with the 2 prior surveys. Unocal has been providing welt performance data (injection rate., tubing and IA J pressures) on a monthly basis incompliance with sundry approval 399..190. 2. Chronological Review of flles revealed: a. CO 80 (September 30, 1969) b. AlO S (July 25, 1986) -Class II underground injection authorized for the Trading Bay Unit ~sdescribed in AID c. January 3, 1990, PTD 190..003 1ssuedto Unocal to driUand oomplete 0-40 as a service well. d. Well completed April 3, 1990, per 407. " e. September 8, 1997. 403 (397-160) request filed to allow well to remaininservièeafter~ well failed anMIT on 8/5/97. Approval was granted through November 30,. 1997 or until ," a Water Flow Log (WFL) discloses the condition of the casing, whichever occurred first. f. January23~ 1998,403(398..023) request fi1ed to keep weU on injection service pending a wotkover planned in summer 1999. Approval granted with the requirement that Unocal was to place the well on monthly monitoring and provide a 404 when the repair wa.s cornpleœd. - , g. Letter notice filed January 27, 19981ransmitting WFL. Preliminary analysis indicated that 9-S/8~ casing leaks existed. h. March20, 1998, Unocal by letter requested to return 0-40 to temporary service to allow diagnostic work to be accomplished on another well. Unocal provided S~h1uberger's analysis of the WFL that (according to Schlumbcrger) indicated a casing leak at about 3000'. Schlumberger states that it is their assessment that fluid exits the casing 'at that depth and then travels down the outside to the injection interVal. Approva.l for the temporary injection activity was given by Wendy on March 20, 1998. i. June 26~ 1998) 403 (398-167) request to workover the well. Approval was given July 9~ 1998. There is no information in the file conf'trming the workover was performed and subsequent wellbore diagrams indicate that the original dual tubing ,strinp are in place. j. September 20, 1999, 403t (399-190) requesting to retùrn tho well to service after having analyzed 2 temperature surveys. Approval was granted with the requirement to perform 1 IA - inner annulus; annulus between tubing and next outer protective ca$ing ') ) (" f and report daiJy monitoring information and·conduct furtherternperature surveys at 2. year intervals.. 3~ Tec~i~lEvaluationofRequest -The available information concerning a casing ieakand the sequential temperature surveys appear to conflict Temperature surveys indicate water injection ÎSconfined to the intended intervals. SubmittedmoIÙtoring information does not indicate tubing and IA pressureçommunication. Average tubing pressure durjngthe past 3 months has been about 2250 psi with the IApressure of about 500 psi. R.eported OA pressure is about 300 psi. The available i nforfn4ti 011 shows the pressures to be stable. Reœmmend8.tioD File Review indicates compliance with provisions of 20 AAC 25. COtsnd AlO. Approval of· Unocal's requeSt is. recommended subject to following conditions: i. Monitor all casing annuli daily; report monthly unless there is a 10% change in pressure attributablø to other than well performance(AIO Rule 3 requires weekly check olIA only) b. Run temp survey every 2 years (anniveI"ssry date is date of vari8t1cc apprDval) and provide results to. Commission. c. No specific requirement for a standard MIT is necessary(AJO Rule S). CODÛnued daily monitoringofrateø and pressures: and biannual temperature surveys are acceptable m,ethods for demonstrating continued mechanical integrity. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state. ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / WGI 06/15/03 John Petty John Crisp Well[WGI-06 P'T-D'II900300 I Notes: 4-year MITIA WelIIWGI-07 P.T.D. I1900400 I Notes: 4-year MITIA WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type test Packer Depths (ft.) MD/TVDI 8,2981 7,660' Test psiI 19151 Pretest Initial 15 Min. 30 Min. TubingI 36001 36001 36001 36001 IntervaI 4 Casin~lI 9601 25001 24601 24901 P/FI P Type test I P I Test psiI 19671 I Casin~ll 5401 20401 20201 20001 P/FI P Type Inj Type l~ Type l~. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL 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 2003-0615_MIT_PBU_WGI-06_-07.xls STATE OF ALASKA ,- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 103' RT above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service: % Trading Bay Unit 4. Location of well at surface 8. Well number Leg #1, Conductor #25, 1900' NSL & 1459' WEL f/SE corner, Sec. 29, T9N, R13W, S.M. G-40 At top of productive interval 9. Permit number Top of Hemlock-9887' MD, 663' SNL & 2417' WEL f/SE corner, Sec. 32, T9N, R13W, S.M. 90-3 At effective depth 10. APl number 50-733-20412-00 At total depth 11. Field/Pool 11,267' MD, 1155' SNL& 2653' WEL f/SEcomer, Sec. 32, TgN, R13W, S.M. McAurthur River/Hemlock & West Forland 12. Present well condition summary Total depth: measured 11,267' feet Plugs (measured) true vertical 10,638' feet Effective depth: measured 11,143' feet Junk (measured) true vertical 10,499' feet Casing Length Size Cemented Measured depth True vertical depth Structural 421' 20" Driven 421' 421' Conductor 1,926' 16" 3,400 sx 1,926' 1,926' Surface 5,128' 13 3/8" 4,950 sx 5,128' 4,973' Intermediate Production 11,232' 9 5/8" 2,710 sx 11,232' ": -i'., ' Liner ..... ~, ',~, !!;,.,,, ti Perforation depth: measured See Attachment ~ I~ !~,. "i ~ ,..~.,~.~:..,~',':~ ." true vertical .A.~.,:~',',~ OiJ .~ ":'""'" "' Tubing (size, grade, and measured depth) kS: 8-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl CIr Gplg w/114-99 Internal Coating @ 10,468' SS: 3-1/2", 9.2#, N-80, Imp. Butt. w/IKO MMS Spcl Git Cpi# w/114-99 Internal Coating @ 9,827' Packers and SSSV (type and measured depth) Otis "RDH" Dual Pkr @ 9796' Otis "BWH" Perm Pkr @ 10,882' DPM (10,375' DIL) 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: Temperature Survey X Well Schematic X , 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Oas: Suspended: Name of approver Date approved Service: Water Injection 17. I hereby cer, lif¥-.0'mT~ foregoingfi~ue~ c?rect to the best of my knowledge. t, Jefferv_,_~.%~ IJID°lan ! (. 1, ).~ Signed: ~ ~f_.~.-///~ ~ ~ Title: Waterflood Technician Date: 7/2/2002 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No Plug integrity BOP Test Location clearance ~,¢--., ~ ! MechanicallntegrityTest~ ~Jk~,.,~--. Subsequent form required l0- f,¢~,.-.~¥,. '~2,~C~.~-L""'C,~,~j [-~t-~.~t,.~'~ t,,,,t.~.,~ Approved by order of the Commissioner ~/~ t~.~.~..~%kkr.., Ak Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-40 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-40 PERFORATIONS MD MD TVD Zone ToD Btm Btm B-1 B-4 WF-2 WF-3 WF -5 WF -6 WF -7 9 880' 9 892' 9 934' 10.111' 10 128' 10218' 10.455' 10 525' 10 680' 10 833' 10 915' 10 993' 11 042' 9,882' 9,926' 9,936' 10,113' 10 208' 10 220' 10.457' 10 565' 10 770' 10 888' 10 972' 11 040' 11 044' TVD Top 9 338' 9 349' 9 388' 9 552' 9 568' 9 652' 9 871' 9 936' 10 079' 10 218' 10 293' 10 363' 10 407' Amount Present Condition 9,340' 9,380' 9,390' 9,554' 9,642' 9.654' 9 873' 9.973' 10 161' 10.268' 10.344' 10.406' 10.409' 2' Cmt Sqz 34' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 80' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 40' Open f/Injection 90' Open f/Injection 55' Open f/Injection 57' Open f/Injection 47' Open f/Injection 2' Cmt Sqz 7/2/2002 10:41 AM G-40_20020702 Request for Variance.xls G-40 Perforations UNDERGROUND INJECTION CONTROL PROGRAM ALASKA OIL AND GAS CONSERVATION COMMISSION Authorization to Inject with an Integrity Loss Sundry application ~-~ ~"~ for well T ~ ~.~ Q_~ '- ~kk.~ allow the well to remain in injection service. , PTD Ic~-(X3'~is approved to This approval is subject to the following conditions: Confirmed T x IA communication, rate not quantifiable. Water Injection ONLY 4 Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITIA/LLRT 4 year CMIT T x IA Confirmed T x IA communication, > 10 gpm. Water Injection ONLY 3 Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. 2 year CMIT T x IA (tubing leak) or MIT T (packer leak) t~,~'LProduction Casing Leak Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of tl~i.s in!~ormation to the Commission. Annu'~l CMI'T',IA x O'A ' peo~-k,k~x-,,~¢~ rxt~:k IA x OA Communication Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a 1 monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA Alarm w/injection shutdown on OA. Set point minimum 1000 psi < minimum burst strength of outside casing. This approval is specific for the identified integrity loss. Should pressure/rate monitoring indicate a change in the well conditions, the following applies: Type 4 changes to Type 3, notify Commission on next business day and secure permission to continue operations. If well already has Type 4 or 3 integrity loss and monitoring indicates Type 2 or 1 may have developed, secure well immediately and notif',, the Commission on the next business day. By Order of the Commission Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL } July 15, 2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Trading Bay Unit Grayling - 40 Dear Mr. Maunder: A temperature survey was run on January 17, 2002 which demonstrates that G-40 (Permit # 1900030 API 50-733-20412-00) is injecting into the Hemlock and West Foreland and does not endanger any fresh water aquifers or shallow reservoirs. This survey is plotted in depth along with the July 20,1999 baseline survey (at the end of an 18 month shut-in period) and the August 5, 1999 survey (after 7 days of injection). Other then the expected cooling due to water injection, the plot does not reveal any anomalies which would indicate leakage into shallow reservoirs or fresh water aquifers above the Hemlock. We therefore, conclude that it is safe to continue operation of the well under the current variance conditions. We have attached the temperature survey plot, a well schematic and a 10-403. We ask that you approve the attached 10-403 granting an injection variance for this well. Sincerely, Je~ ~ ~~'-'-'~ Waterflood Technician Cook Inlet Waterflood Management Enclosures Aogcc Grayling 40 Application fbr Varience 20020702.do0 R t ¢ I ~,,,,1AL 3O 0 5OO 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 11000 Grayling G-40 Comparison Temp survey January 2002 18 month Si 7/20/99 & 7 day inj wi 12 hr. Si 8/5/99 40 50 60 70 80 90 100 110 120 130 140 150 160 170 K 55 I0128L10208' 7/20/99 Temp Survey ~8/5/99 Temp Sunzey '~1/17/02 Temp Survey 356&7 7/15/2002 8:20 AM Jeff Dolan G40 Temp Log 7420-99 & 8-5-99 & 1-7-02 xls Temp Chart Trading ga5 [.'nit Completed 4/26/9(t RKB to TBG Hngr: 40.8' Tree connection: Dual 3" 5,000# RT to MLLW ELEV: 103' MAX HOLE ANGLE = 27.2° @ 8900' G-40Schm4-26-90.doc SIZE 9-5/8" 47 CASING AND TUBING DETA1L 9-5/8" 47 %5/8" 47 Tubing: Butt 2~992 o' t8,463' 9870' Burl 2.992 8' 982T 929W 48.80' Caaleron DCB Dual 3-U2" Tubing hanger. SIlORT STRING I,ONG STRING SLICKLINE TAGS SS Tag"XN" w/2.72" GR 8/5/97 (a 9813' LS Tagged obstruction w/2,72" GR & 2.72" LIB 8/6/97 Tag fill w/2.25" LaB 8/7/97 ~t [ 1,086' WH~EL1NE WORK LS * Spinner ran on 1/22/98 indicates tbg leaks ~' 9812' & 10,t25' ~ WFL ran on 1/23/98 b~dicates csg leak between 3250' & 3350'. ~ WFL indicated multiple SS tbg leaks, sldg slve ~ 9760L tbg jt between sldg sire & pkr and between 1200* to 3400'. STIMULATIONS 2 stag acid job w/diverter, 5{) bbls of HCL & 75 bbls of 3/29/90 West Forland 6-1/2% X 1-1/2" mad acid 2 stag acid job, 40 bbls of IlCL & 135 bbls of 6-1/2% X 1-l/2" 3/29/90 HB-1 & 2 mud acid Date Last Opt, Present Condition Accum. Zone Top Btm Amt SPF 9,S80' 9,882' 32~. ~ B;~ 9~892' ~ 9,926' ~ 9,934' 9,936' 2' 4 ~:4 J~d28' ~ 10,208' , 80' 8 10,218' 10220' 2' 4 3~V.F-. _ ~_ !0,525' 10 565' , 40' + 8 3/20/90Cmt Sqz 3/10/90Grot Sqz 3/18/90Cml Sqz 3~28~90Open 3/t8/90Cmt Sqz 3/17/90~Cmt Sqz 3125190j Open fL~nj~q~!e~ 3~25~90~eq f/~nje~i~ 3/25/90Open f/ 3125190~Open f/ J} 3/25190 ~Open f/injection 11,042' ~44'. 2' 4 3117190[Cmt Sqz REVISED: 2/2/98 DRAWN BY: S£T u'NOCAL ) Trading Bay Unit Well # G-40 Completed 4/26/90 Wireline Problems: Tubing Size: Minimum I.D. Status: Max Deviation: Perforations: Iniection Survey Wireline tag on 8/6/97 w/2.72 LIB shows tbg to be oblong 2.72" x 2.68" LS 3-1/2", 9.3#, N-80, Buttress SS 3-1/2", 9.3#, N-80, Buttress Plastic Coated Plastic Coated LS SS Nipple: 2.75" ~ "XA" Sliding Sleeves & "X" Profile Nipple · 9762', 10,352' & 10,428' 2.75" ~ "XA" Sliding Sleeve & 2.635" ~ "XN" Profile 9960' & 9813' LS West Forelands Shut-In SS Hemlock Shut-In 27° ~ 8900' MD Hemlock & West Forelands 1/22/97 Hemlock WF-2 WF-3 WF-5 WF-6 WF-7 5,123 BWPD 824 BWPD 61 BWPD 92 BWPD 0 BWPD 0 BWPD 84% 14% 1% 2% 0% 0% Discussion Completed as a West Forelands / Hemlock Dual injector on 4/2/90. Worked over due to defective dual packer. Redressed and reran equipment on 4/26/90. Tested short string tubing to 3700 psi on 5/5/90. No communication between short string and tbg/csg annulus. · Have had communication to tbg/csg annulus since completion. · Well head failed MIT. · Spinner survey ran on 1/21/98 showed no leaks in the LS from surface to the dual pkr ~ 9798' · Spinner survey ran on 1/21/98 showed a 1495 BPD leak in the LS ~ 9812' and a 580 BPD leak @ 10,125' · WFL ran on 1/22/98 indicated multiple short string tbg leaks ~ 1200' thru 3400', 9760' (sldg slve) and in a tbg joint between sldg slve & dual pkr ~ 9796'. WFL also indicated a +500 BPD csg leak between 3250' & 3350' G-40Schm4-26-90.doc REVISED: 2/2/98 DRAWN BY: SLT UIC File Review Date: July 23, 2002 Subject: Unocal Trading Bay Unit (TBU) G-40 (Water Injector) PTD #: 190-003...302-217 Orders: Reviewers: Initiating Action: CO 80 (Subsequent orders 234A, 284 and 350 allowed commingling) AIO 5 Tom Maunder, P.E. ~~t'r ~(% ~ Jim Regg ~~>e/~ ~t~qOT/[~'v"~t> Application for Variance Review Summary 1. Unocal submitted request dated 7/15/02 (received 7/16/02) to continue injection and provided the latest temperature survey conducted on the well, presented with the 2 prior surveys. Unocal has been providing well performance data (injection rate, tubing and IAl pressures) on a monthly basis in compliance with sundry approval 399-1.90. 2. Chronological Review of files revealed: a. CO 80 (September 30, 1969) b. AIO 5 (July 25, 1986) - Class II underground injection authorized for the Trading Bay Unit as described in AIO c. January 3, 1990, PTD 190-003 issued to Unocal to drill and complete G-40 as a service well. d. Well completed April 3, 1990, per 407. ,, e. September 8, 1997, 403 (397-1.60) request filed to allow well to remain in service after well failed an MIT on 8/5/97. Approval was granted through November 30, 1997 or until a Water Flow Log (WFL) discloses the condition of the casing, whichever occurred first. f. January 23, 1.998, 403 (398-023) request filed to keep well on injection service pending a workover planned in summer 1999. Approval granted with the requirement that Unocal was to place the well on monthly monitoring and provide a 404 when the repa~ir was completed. g. Letter notice filed January 27, 1998 transmitting WFL. Preliminary analysis indicated that 9-5/8" casing leaks existed. h. March 20, 1998, Unocal by letter requested to return G-40 to temporary service to allow diagnostic work to be accomplished on another well. Unocal provided Sghluberger's analysis of the WFL that (according to Schlumberger) indicated a casing leak at about 3000'. Schlumberger states that it is their assessment that fluid exits the casing'at that depth and then travels down the outside to the injection interval. Approval for the temporary injection activity was given by Wendy on March 20, 1998. i. June 26, 1998, 403 (398-167) request to workover the well. Approval was given July 9, 1998. There is no information in the file confirming the workover was performed and subsequent wellbore diagrams indicate that the original dual tubing .strings are in place. j. September 20, 1999, 403, (399-190) requesting to return the well to service after having analyzed 2 temperature surveys. Approval was granted with the requirement to perform ~ IA - inner annulus; annulus between tubing and next outer protective casing and report daily monitoring information and conduct further temperature surveys at 2 year intervals. . Technical Evaluation of Request - The available information concerning a casing leak and the sequential temperature surveys appear to conflict. Temperature surveys indicate water injection is confined to the intended intervals. Submitted monitoring information does not indicate tubing and IA pressure communication. Average tubing pressure during the past 3 months has been about 2250 psi with the IA pressure of about 500 psi. Reported OA pressure is about 300 psi. The available information shows the pressures to be stable. Recommendation File Review indicates compliance with provisions of 20 AAC 25, CO, and AIO. Approval of Unocal's request is recommended subject to following conditions: a. Monitor all casing annuli daily; report monthly unless there is a 10% change in pressure attributable to other than well performance (AIO Rule 3 requires weekly check of IA only) b. Run temp survey every 2 years (anniversary date is date of variance approval) and provide results to Commission. c. No specific requirement for a standard MIT is necessary (AIO Rule 5). Continued daily monitoring of rates and pressures and biannual temperature surveys are acceptable methods for demonstrating continued mechanical integrity. Area Injection Order No. 5 http://www.state.ak, usllocallakpageslADMINIogcloindexlaiolaio5, htm .,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF UNION OIL COMPANY OF CALIFORNIA for an Area Injection Order for the Trading Bay Unit ) Area Injection Order No. 5 ) ) Trading Bay Unit ) McArthur River Field July 25, 1986 IT APPEARING THAT: 1. Union Oil Company of California (Unocal) requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Trading Bay Unit for purposes of enhanced hydrocarbon recovery. 2. Notice of an opportunity for a public hearing on July 24, 1986, was published in the Anchorage Times on June 24, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing under ground injection operations on an area basis. 2. The Trading Bay Unit (TBU) boundary encompasses the entire McArthur River Middle Kenai "G" Oil Pool; the entire McArthur River Hemlock Oil Pool; and the entire McArthur River West Foreland Oil Pool. 3. All existing injection wells and injection well sites planned for enhanced recovery of oil from these three pools lie within the Trading Bay Unit boundary. Union Oil Company of California is the sole unit operator. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Trading Bay Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c), 5. Less stringent requirements for well construction, operation, monitoring and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limit of injection strata and confining formations for the Middle Kenai "G" Oil Pool and the West Forelands Oil Pool may be defined in the Unocal TBU Well No. G-7 and for the Hemlock Oil Pool in Unocal Grayling Well No. lA. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to injection Strata, the mechanical integrity of injection wells should be 1 of 4 7/23/2002 12:59 PM Area Injection Order No. 5 http:llwww, state.ak.usllocal/akpageslADMINIogcloindexlaiolaio5.htm demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were onstructed and completed in accordance with regulations which conform to the requirement of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground Injection operations in the following described area referred to in this order as the affected area: SEWARD MERIDIAN T9N R13W T9N R14W T8N R13W T8N R14W Section 8: SE 1/4 SW 1/4, S 1/2 SE 1/4. Section 9: S 1/2 SW 1/4, S 1/2 SE 1/4. Section 10: S 1/2 SW 1/4, S 1/2 SE 1/4. Section 11: SW 1/4 SW 1/4. Section 14: S 1/2 SW 1/4, NW 1/4 SW 1/4, W 1/2 NW 1/4, SW 1/4 SE 1/4. Sections 15 and 16. Section 17: E 1/2, SW 1/4, E 1/2 NW 1/4, SW 1/4 NW 1/4. Section 18: S 1/2 NE 1/4, SE 1/4, E 1/2 SW 1/4, SW 1/4 SW 1/4, SE 1/4 NW 1/4. Sections 19, 20, 21 and 22. Section 23: W 1/2 E1/2, W 1/2. Section 26: W 1/2 El/2, W 1/2. Sections-27, 28, 29, 30, 31, ~ 33 and 34. Section 35: W 1/2 NW 1/4, NE 1/4 NW 1/4, W 1/2 SW 1/4, NW 1/4 NE 1/4. Section 13: SE 1/4 SE 1/4. Section 24: NE 1/4 NE 1/4, S 1/2 NE 1/4, SE 1/4, E 1/2 SW 1/4, SE 1/4 NW 1/4. Section 25: E 1/2, E 1/2 W 1/2. Section 36: E 1/2 NW 1/4, NE 1/4, N 1/2 SE 1/4, SE 1/4 SE 1/4, NE 1/4 SW 1/4. Section 3: N 1/2 NW 1/4, SW 1/4 NW 1/4, W 1/2 SW 1/4, Sections 4, 5, 6, 7 and 8. Section 9: W 1/2, W 1/2 E 1/2, NE 1/4 NE 1/4. Section Section SW 1/4. Section Section Section Section Section Section Section 10: NW 1/4, NW 1/4. 16: NW 1/4, W 1/2 NE 1/4, NW 1/4 SE 1/4, N 1/2 SW 1/4, SW 1/4 17 and 18. 19: N 1/2, SE 1/4, E 1/2 SW 1/4, NW 1/4 SW 1/4. 20: N 1/2, N 1/2 SE 1/4, SW 1/4 SE 1/4, SW 1/4. 21: NW 1/4 SW 1/4, W 1/2 NW 1/4. 29: N 1/2 NW 1/4, NW 1/4, NE 1/4. 30: N 1/2 NE 1/4, NE 1/4 NW 1/4. 1: E 1/2, E 1/2 W 1/2, NE 1/4 NW 1/4. 2 of 4 7/23/2002 12:59 PM Area Injection Order No. 5 http:llwww, state.ak.usllocal/akpages/ADMINIogc/oindex/aiolaio5.htm Section 12: E 1/2, E 1/2 W 1/2. Section 13: E 1/2 E 1/2, NW 1/4 NE 1/4, NE 1/4 NW 1/4. Section 24: E 1/2 NE 1/4, NE 1/4 SE 1/4. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Unocal Grayling Well No. lA between the measured depths of 9,372 feet and 9,897 feet and which correlate with the strata found in the Unocal TBU Well No. G-7 between the measured depths of 9,116 feet and 9,695 feet and between 10,208 feet and 11,208 feet. Rule 2 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 3 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be routinely checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minim um yield strength. Rule 4 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 5 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or Packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 7 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 8 West Forelands Enhanced Recovery Fluid injection into strata which correlate with the strata found in Unocal TBU Well G-7 between the measured depths of 10,208 feet and 11,208 feet must not be undertaken prior to obtaining Commission approval to conduct enhanced recovery operations for the West Forelands Oil Pool. Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator 3 of 4 7/23/2002 12:59 PM Area Injection Order No. 5 http:l/www, state.ak.us/IocallakpageslADMINIogcloindexlaiolaio5.htm demonstrates to the Cmmission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increase risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated July 25, 1986. C V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission W. W. Barnwell Commissioner Alaska Oil and Gas Conservation Com mission Area injection Order Index 4 of 4 7/2312002 12:59 PM JUN-29-98 13:41 UNOCAL ASSET GAS 6RP FAX NO, 9072637874 P, O1/O1 Unocal Corporation 909 We.si 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29,1998 Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocai's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our March 27, 1998 letter which you signed granting time extensions for various wells. Testing or work was completed on the following wells and the results of this work is listed: 8~- o'~ :, Anna 46-42 : SI MIT approved on 4/17/98. ':/~, .~4-z King 4RD : SI MIT approved on 4/17/98, ~q-t:o34 King 15RD : SI MIT approved on 4/17/98. 8o- ~ ~ o - Doily D- ! 6RD : SI MIT approved on 4/l, 7/98. ~,"l-I=~ Dolly D-22 : SI MIT approved on 4/17/98. · ~s'-~,~, Grayling 22 : Workover completed on 4/19/98. fi3' ~ Grayling 36DPN : Workover complet~ on 4/28D8. ~ ~-o~ Monopod A-12~2 : SI MIT approved on 6/03/98. ~z-oz~ Monop~ A-29 : SI MIT approved on 6/03/98. ~4- 7~ Baker 9 : SI MIT approved on ~. ~ King 22RD : V~iance granted on q~ - ~ ~ Anna 27-42 :Coil Tubing clean out completed on workover scheduled. Jug test proved communication, workover scheduled. 6/03/98, planning acid treatment to clean tubing lbr testing. 6/09/98, Jug test proved casing integrity. 6/25/98, further testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove easing integrity. Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrill in progress. Testing or work was attempt.ed on the following shut-in wells and a time extension until September 30, .1998 is reauested to complete further work and testina t,B - o ~, Anna 19-42: Coil Tubing clean out completed on 6/27/98, furtl~er testing scheduled to prove casing integrity. '3:?' ol/~ Anna 27-42: Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. · -4q' °'4 Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. ~- 0:5 Grayling 40: Workover schedule in current rig schedule. --43-~,4z. King 4RD : SI MIT granted on 4/17/98, workover scheduled. "4~' t~%d-King 15RD: SI MIT granted on 4/17/98. Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal respectfully requests a time-extension until September 30. 1998 to complete the work on the above listed Anna wells. The Grayling and King work will be executed per our current drilling schedule. Please call me if you have any questions or clarification on these issues. Cook Inlet Waterflood Management Please acknowledge the approval of the time extension and your receipt of this letter b~. f~.x, ing~b,a.ck a.s)g.n.ed ~cq~ of this letter to Christopher Ruff at 263-7874 (fax). Wendy"' Ialmn Date ' JUN 2 9 1998 AOGCC Alaska Oil & Gas 6oos. Oommi~,ion MAR-27-98 FRI 13:52 UNOOAL hSSET GhS GRP FAX NO, 90726~7874 Un0eal Corporation 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 P, 01/01 UNOCAL ) March 27, 1998 Wcndy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our JanuaDy 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or work was completed on the following wells and the results of this work is listed: Anna. 29-42: Well head inspection completed (no leaks), Variance granted on 3/3/98. Baker 4: MIT passed on 2/15/98 by Lou Gfimaldi Bruce 31-42: Coil Tubing operation completed to repair leaking cement plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/17/98, MIT completed on 12/15/97. Grayling 16: Workover completed on 3/26/98. MIT Passed. Monopod A-SRD2: MIT passed on 1/28/98 by Lou Grimaldi Testing or...work was attempted on thc following.shut-in wells and a time extensign tmtfl June 30, 1998 isrequested to com. plete further work and testing, Anna 19-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 27,42: Scale cleanout of tubing completed, further testing scheduled to prove easing integrity. Anna. 46-42: Temp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MIT attempted on 2/15/98, further wireline testing scheduled to prove casing h~tegrity. Monopod A-12RD2: SI MIT attempted, Temp Survey scheduled to prove no flow· Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : ~ indicales possible casing leak, well shutin, further testing and workover scheduled. King 15RD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : Workover/Redrill scheduled in current drilling schedule. Grayling 22 : Workover/Redrill scheduled in current drilling schedule. Grayling 28 : Workover/Redrill scheduled in current drilling schedule. Grayling 36DPN : Workover/Redrill scheduled in current drilling schedule. Grayling 40 : Workover/Redrill scheduled in current drilling schedule. Unocal respectfully requests a time. extension until June 30, 1998 to complete the work on the above listed Anna, Baker and Monopod wells. The Grayling and King work will be executed pr our current drilling sche_d, ul.e.21~se call me if you have any questions or clarification on these issues. R E C E I V ~ ~.~ ' ' na~ Oil & 6as Cons. GommmmOn Anchorage Please acknowledge the approval of the time extension and)'our receipt of this letter by faxing back a signed copy of this letter to Cttristopher Ruff at 263-7874 (fax). ~VenflyX]~d~han Dart .... AOGCC Unocal Corporation .Agricultural Products 909 West 9~h Avenue. P.O. Box 196247 Anchorage. Alaska 99:519-6247 Telephone (907) 263-7830 UNOCAL ) March 20. 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Temporary Injection Well G-40 Waterflood Injector Grayling Platform Trading Bay Unit Wendy: Per our conversation this morning regarding Well G-40, I am requesting permission to temporarily inject into tile well. if necessary. A Water Flow Log, run on the well in January 1998, revealed a casing leak at +/- 3300' MD, which is within the Grayling Gas Sands Formation boundaries. The interpretation is that the water travels down the outside of the casing, past the surface casing shoe at 5128' MD, and continues downward to the Hemlock Formation at approximately 10000' MD. The well has been shut in, awaiting workover repair. The rig schedule for the active rig program on tile Grayling Platform calls for tile workover of another injection well, G-12RD2, which is currently an active injector. Prior to the workover of this well, diagnostic work is needed using slickline. The shut down of the G-12RD2, which would be for an estimated maximum time period of 36 hours, may result in the loss ofwaterflood injection in other wells during that time if injection rates and pressures drop below the operating threshold of the injection pumps. Unocal would like to maintain injection operations. Therefore. Unocal requests permission to inject in to Well G-40 for a maximum of 36 hours while diagnostic work is performed on G-12RD2. Initially, an attempt will be made to continue operating the waterflood injection system without using G-40. If G-40 is needed, it is estimated that approximately 1000 barrels of water will go through the casing leak. The work is expected to take place this weekend. If you approve, please acknowledge by faxing back a signed copy of this letter for our records (fax # 263- 7884). If you have any questions please call me at 263-7675. Sincerely, ' '~,2 ?'"; ~! ..... ·, Hal Martin Reservoir Engineer Approval Acknowledgment ~Vendy Mtahan AOGCC Date FEB-03-98 TUE 1 ~', 59 P, 0 i/~. 8 UNOOP, L P, SSET G~S GRP FRX NO. 9072637874 Unocal l' ',,i;'~ 909 W. 9th Avenue Anchorage, AK 99501 Fax 907-263-7874 907-263-7665 (confirmation) Fax transmittal , = , Fax Number: From: Date: Pages: Cover plus Comments: FEB-03-98 TUE 15:59 UNOOhL hSSET GAS GRP FAX NO, 907?637874 Unocal Corporation Agricultural Products 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) January 29, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 P, 02/18 Re: Grayling G-5, G-16, G-22, G-36DPN and G-40 9-5/8 casing leaks. Dear Blair: Water-flow logs were run on G-S, G-16, G-22, G-36DPN and G-40. Thc results from these logs indicate poss~le leaks in the 9-5/8" casing strings. Thc wells have been shut-h~. Copies of the WFL interpretations with updated wellbore diagrams are attached for your flies. Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document notification for our records. Blair Wondzell Petroleum Engineer AOGCC Date FEB-03-98 TUE 15:59 UNOCAL ) i i , RKB to TBG Head · 41.$' Tree connection: 12,41a', 12, TIlT UNOCAL ,.. 0-1 G-2 LIB ~ on 8/4/97 G-4 G-5 G-6 HB-1 HB-2 HB-3 HB-4 ETD" 13,4~2' TD" 13,a113" KB ELEV - MAX ANGLE ' 41.41 ~ 11,067' G-16DOC aSSE? oas GRP FaX NO, Diff. between DP &DIL Diff. between tbg & DP Diff. between DIL& tbg NOTE: 12' 12.24' 24.24' 9072637874 P, 03/18 .. Trading Bay Unit Well # G-16 Re-Completed 5/8187 CASLNG AND TIYBING DRTAIL WT GRADE CONN ID TOP BTM. CMT 17.3/4' .312 wall Weld Surf. 60 I' 13-3/8': 61 K-55 Se~l Lock 12.515 8ur[ $~60' 9-5/8" 47 P- 11 o B un 8.68 i 10,680' 12.416 9-5/8" 47 N-80 BuU 8.6S I 850Y I 0,610' 9-518" 43.5 N.80 B~ 8.755 62~' a503' 9-5~" ~ N,{0 B~ ~.{35 ~' 6296' 9.5/g" 43.5 N-10 Bu~ ~. 75 5 54' ~9' 9-5/8" 47 N-I0 Bu~ ~.6l I ~. 54' ~ 29 p-I lo B~ 6,1~4 I l,~5' 13,66T T' 29 H-{0 BuR 6,1 T' DV Coll~ 61~' 6174' Tubing: 3.1/2" 93 N-tO S.L, 2.~2 0' 12,0~' 2-7/~" 6,4 N40 S.L. 2.~1 12,209 I Z 77Y I'~' lntelrtty Note: While injecting ~ 4 BPM, 2050 psi down tho 9.518" X 13-3/8" annulus, a Tamp Log ran revealed injection to 6060', Cat sqz'd, down the annulus w/gOO sx of clue "G'. Noted , . on 5/t/87. bled off. built baok-uo to 800 ~ai. Establbhcd no inlc~on rate ~ 2000 psi on JEWELRY DETAIL NO. Depth ID Item 2350sx 10~Om . . 1300 sx on 4/23/87 PBU on annulus 5/2,/87. 41.5 I i 2.042' 2.75 2 12,072' 2,406 3 12,073 3.25 4 i 2,076' 3.25 5 12,016' 2.441 6 12,087' 2.760 7 12,081' 2.992 ! 12,209' 2.441 9 12,237' 2.44 I lO 12,773' 2.406 I I 12,T/4' 3.25 12 12,77r 3,25 13 11,816' 2.313 14 12,g45' btm 12,846' 3-I/2" CIW Stainless Tubing Hanser Otis 'XA" $1~ Siva Lo~amr S~al Auy. w/It,6' ofsesls, 8~32 8cai B~a E~. ~, 8e~ Bore E~. B~ X 2-7/8" Sea{ L~k Y~ Cr~s~, 2-718" 3cd L~k B~ X 3.112' ~cd Lock pm 4jm of 3.1~', 9.2~, N40, ~, 8oal Lock ~ C~.~, 3.1~" Sc~ L~ Box X 2-7/r 8~ Lock Pin Tel~e.~erla ~ow M~el B&. Model "DB" P~. 12,750' D~ ~s "~ ~ofilc Nippl~ FISH Cml Retainer 6/I !/74 ~) i 3,462' Jtmked PLT 3/30/71 ~} 1.1,412 Cml Retainer 4/2/78 ~ 13,482 STIMULATION8 Ac{dlze w/4000 gals of t 2-3 mud no{d& ~0 ge{a of E-iS aolvenL 7/20/74 HB-4 Fracture Stimulated wi 13,50(N/of a~nd inlo perfa. 7/20/74 HB.4 Acldlze w/4000 gala of 15% HCL & 10,000 gala of 12-3 mud acid. 4/6/78 HB.4 Acidl~e w/18000 gale of ?.S% HCL 4/2~/~7 'O" Zone AcldlZe w/3~,700 gals of 12-3 mud a~td. 5/{/r/ "O" Zone SLICKLINE WORK Tagged XO w/2.72" OR 8/3t97 11 12,079' WLM (12,086' MD) Tagged obslmclion w/2,23" OR 8/3/97 @ 12,220' WLM 2.25" LIB nhowed deep gouges o~ aide & smaller In middle 8/3/97 (~ 12,220' WLM PI~'RF'oI~.TION DATA AccUm LeII Zone Top Btm Amt SPF Parr Date Present Condition -O-1 12,'{'~ ' t2,146' ' 2S' 12 '" ~11~11'/ Open II InJlc~i~n .... (3.2 12,1~4' 12,210' 40' 12 4/2S/~? Open fl Injection O-,1 12,276' 12,~15' 40' 12 4/2B/ST Open t/Injection G4 12,356' 12,450' 11 · 12 412~/17 Open ft Injection O~ 12,120' 12,110' II~ 1Z 4/2~/~7 Open fl Injection 04 12,18S' 12,725' 40' 12 4/25187 Open fl Injection HB-1 12,84a' 12,lleo' 46' le 4/26/87 Open fl Injection HB-2 12,904' 12,~8~' 81' 1/14ff4 Cml Sqz'd HB-2 13,008' 1:{,088' 83' {1t4rf4 cml ~{qz'd HB-3 13,108' 1:1,142' ~4' i114/74 Cat Sqz'd HB4 13,172' 13,270' 98' 20 4/2~/~7 Open fl Injection REVISED: 815/97 DRAWN BY: SLT FEB-03-98 TUE 1~6,.: O0 UNOOC~L ¢~SSET GRS GRP ~Vll I ~llll~l ~1 FAX NO. 9072637874 P, 04/18 r. UI A GEOQUEaT 500 W. International Airport Rd. Anchorage, Alaska g9518 FAX COVER SHEET DA'rm February 3, 1998 TIME: 10:48 AM TO,. Hal Martin/Chris Ruff PHONE: 907-263-'7675 UNOCAL FAX: 907-263-7874 I=ROM: Rob North PHONE: (907) 563-1597 GeoQuest lOS ~=^X; (907) 562-6521 G-16 WFL Results CC: Number of pages including cover sheet: 2 Message Hal & Ohds, Attached to this cover letter Is a log presentation of the WFL results for O-16, Below is a brief discussion: With the tubing to 7" annulus open during Injection the well was returning 1000 bbls to the surface, This flow Is originating at the sliding sleeve at a depth of 12042 feet as no flow was Indicated just above the packer at 12073 feet. With the annulus closed a reduced floW rate of about 100 bpd is indicated moving up from below 12110 feet, Thls flow appears to be leaking past the packer at lg073 Into the tubing x 7" annulus where It continues up to a point between 6500 and 6300 feet where It exits the 7" casing, No further up flow was seen above this point with the annulus closed. Down-flow measurements Indicate a hole In the tubing between 3500 and 4000 feet where flow is measured in the tubing x 7" annulus, This flow appears to continue down to -6400 feet where It merges with the up-flow, exits the 7" casing and flows down the 7" x 9 8/8" annulus. This down-flow continues down pest 12100 feet, Interested in your comments, Rogarda, Rob... FEB-03-98 TUE 16'00 UNOCAL ~flSSET GaS GRP FAX NO, 9072637874 P, 05/18 UNOCAL, TBU G-16, TRADING BAY UNIT, WFL, 29-Jan.eB, (9801 l) FEB-03-98 TUE 16:01 UNOCAL UNOCAL i i i RKB to TBG Hngr = 42' Tree connection: Dual 3" 5,000# ,0OD' L 25~' KB ELEV = 99' TD' t3,479' ETD - 13,364' MAX HOLE ANGLE ~ 4&3G° G.36.DOC ASSET GAS GRP FAX NO, 9072637874 P, 06/18 Trading Bay Unit Well # G-36DPN Completed 12/5/87 , i , _ al i CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/T' 54.5 K-55 Bull 12.615 Surf. 5307' 9-5/8" 43.5 & 47 N-80 & S-95 8rd LT&C 8.835 Surf 10,874' 7" 29 N-gO 8rd LT&C 6.1 g4 10,354' 13.479' Tubing: LS 3-1/2" 9.3 N-80 $,L. & DSS-11'I'C 2.992 0' I2.586' SS 3-1/2" 9.3 N-80 S.L 2.992 0' t0.281' JEWELRY DETAIL NO. Dep~t,!'~ ID Item 42' Cameron DCB Dual 3-1/2" Tubing hangers, StlORT STRING A 10,215' 2.75 3-1/2" Otia "XA" Sliding Slecvo B I0,249' 9-5/8" 0tis "RHD" Dual Packer C 10,266' 2.635 3-1/2" Olis 'XN" Nipple, 2.75 D 10,279' otia Ball Cat;her sub E I0,280' WLEO bu~ 10,28t' Illl 2 3 Suspccl tbg parted' [ @ l l,329' ! IB ran on 81t/97 .. ~ "' 10,I~' 2.75 10,249' 10,318' 2.75 4 12,467' 2.75 5 12,500' 6 12,$01' 4,00 7 12,505' 4.00 g 12,$12' 9 12,520' 10 12,553' 2.75 11 12,585' btm 12,586' LONG STRING II I Il I II I 3-1/2" ~! aXA'; Sliding $1ccvc 9-5/8" Otis "RHD" Dual Packer 3-1/2" Otis "XA" Sliding Sleeve 3-1/2" Oii$ "XA" Sliding Sleeve Otis Straighl Slot Lo~alor ~v/4' spaoer, 5' of seaiJ & mule shoe Otis "WB Perm PYa' Otis Seal Bore Ext. Otis Mill out Ext. (,'roa$ov,~', 4-112" X 3-l/2" 3. i/2" Otis "X" Nipple WLEO __ Susp¢~ tbg parted @ n jo7' IB ran on 6/10/95 FISH Retrievable Bridge Plug SLICKLINE TAGS SS "XN" w/"PX" plug leaked LS Tagged Fill Tagged obstruction (parted tbg) Tagged obstruction (parted tbg) WH1ELINE WORK WFL ran on 1/ STIMULATIONS Aeidized w/5% HCL & 12-3 Mud acid 8/12/73 ~. 13,364' 7/31/97 ~ 10,266' 11/19/S8 ~ 13,270' 6/10/95 @ 12,507' 8/1/97 ~ 11,350' 8/18/87 West Foreland "G" Zone .................... PZR1/'i~'RATiO~ DATA ....... ,~ i~,, ............ Zone Top BIm ~ SM: L.~t Opr, .~~ondlflorl ._O.d.. 11,cr~ al,ilo ... 4~ "t~, ..... ~!,e? OF~.n0lnle~on G-2 a 1,12~ ,3.1.,!~ 8Z .. !.2 ..... 8/14/87 OOon f/tnJ~on .... 0.3 t t,21~' 11,26~ 53' 12 8/~4/e7 Opon ~t 0-4 11,20Z 1.!,3~. 1~ ,, !2 0/1~87 _qpe~on G-5 11,492' 11 ,$~5' 8? 12 8/14/87 Open f/lnl~-qion G-O 11.848 11,077 29' 12 ,,, e/,lq/e,7.., WF.1 12,~ .. 12.7aZ ..... ~ ' [ 12 a/s87 WF.2 ~!2,793' ... 12,920 127 12 8/5'87 Open f/ WF.3 ....._~12,96/' 13,096' 129' .. . ~ 2_.~. , 815187 Ot~n fl WF..4 1.3,1~.50'' 1322g .......... 71Y 16 815187 ;Ooen fl InJ .et~lon .... WF-5 13.2.P$ 13.330' 55' ._ 4 8/.1~7 OOen f/Inl~tlon ............... REVISED: 8/4/97 DRAWN BY: SLT FEB-03-98 TUE 16' O1 ,,, "' UNOOAL ~SSET GAS GRP .. FAX NO. 907?637874 P, 07/18 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHE ET DATE'. February 2, 1998 TO: Hal Martin/Chris Ruff UNOCAL FROM: Rob North GeoQuest ICS RE: CC: TIME: PHONE: FAX= PHONE: FAX: G-#36DPN WFL Results 2:29 PM 907-2...63-7675 907-263-787& (907) 563-1597 (g07) 562-6521 Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a log presentation of the WFL results for G- 36DPN. Below is a brief discussion: With the tubing to 9 5/8" annulus open durtng Injection the well was returning 940 13bls to the surface. A rate of 256 bpd is shown to be leaking past the dual packer at 10249 feet, This rate increases at the station at 10205 feet Indicating a significant leak In the short string sliding sleeve at 10215 feet. An additional small leak was indicated in the long string sliding sleeve at 10178 allhough this increase ie near the resolution of the WFL measurements. With the tubing to 9 5/8" annulus closed no flow was seen leaking up past the dual packer at 10249 however at rate of about 200 bpd appears to originate at the LS sliding sleeve at 10178, Ti'lis up-flow continues up the tubing x 9 5/8" annulus until between 5000 to 3000 feet where It exits the 9 5/8" casing. An additional up-flow was measured at 10500 ft which may be flowing up the 7" x 9 5/8" annulus. Down-flow possibly in the tubing x 9 5/8" annulus is seen at 500 and 9.000 feet. This flow appears to exit the 9 5/8" casing between 1000 and 2500 feet ~nd continues down outside the 9 5/8" casing past the lowest WFL slatlon at 10550 feet.. I plan on delivering color copies tomorrow afternoon, Regards, Rob... FEB-03-98 TUE 16:02 I LU r gU 1 Igll I g ' ~,~-' UNOOaL aSSET GaS GRP FaX IlO, 907263787,1 P, 08/18 UNOCAL, TBU G-36DPN, TRADING BAY UNIT, W~L, 25.Jan.~a, (YB~]I 1) '.,,',', _ ]_ I:'~, I , FEB-OS-98 TUE 16:02 UNOCAL ASSET GAS GRP RKB to TBG Hngr = 48.63' Tree connection: Dual 3" 5,000# 06S7' lO ITla'-ff3 t' -- 9554' g715' FAX I,lO, 9072637874 i i i CASING ~ND TUBIlNG DETAIL. GRADE CONN ID TOP P, 09/i8 Trading Bay Unit Well # G--5 Re-Completed 9/16/87 BTM, CMT 9119' 16' 75 $-55 Butt 13-3/8" 545 K-55 Butt 9-$;$" 47 P-! l0 5cai Lock 9-5/8" 47 N-S0 Seal Lock 9-5/8- 43.5 N-80 Seal Lock 9-5/6" 40 N-80 Seal Lock 9-5/8" 47 N-10 5eat Lock T' 29 1'4-80 8rd LT&C 9-5/8" DV Collar ................................................. Y' Scab 18 N-g0 Butt TublnK: L,~ 3-1/2" 9.3 N-80 S.L. 33 3-1/2" 9.3 N-S0 S.L. -- 6~2~/95 @ 917.5' WI.M w/23'18 ~/9/97 (~ 9175' W1. M w/1.9" OR 0-2 0-3 0-4 0.5 Mill thru w/ 3.75" rrdll on 9/2/87 / .., Surf. $91'[ 1330~m 12.615 Surf. 5307' 2400 wn S.681 8519' 9657' 3000 an 8.681 6925' 8519' 8.755 5187 6925' 11.135 79' 5187 8.681 St=f. 79' 6.114 4J76' 4378' 9719' 9803' 2.992 0' 12,586' 2.992 0' 10.26 I' I I I Ill ~Y DET~ ~ ,. ~ De~ . ~ l~e~ 48.8Y C~ i0" X 5~ ~l 3-1/2" 33 Tub~ h~er. SHORT ~ ii i i i i i i iiill , , A ~5~' 2.75 3-1~" ~iI "~" 31id~ Slccve B 9119' 9-5/r B~ ~1 P~k~ C 91~' g~ H~Tfip D 9162' 2.635 3-1t2" ~b "~' Nixie, 2,75 ~MG .... ~s , I 90~2~ , 1.1/2" ~is 3 9550' 2.75 3.1~" ~is "~" 81id~ Sle~e 4 95~4' L~or Seal ~. 5 9587' 4.~ ~er T' ~-I P~ 6 9591' 4.~ B~ S~l B~ Ext., 9' long. S 961 I' 2.75 ~is "~ ~o~ln Ni~l~ 9 ~2' b~ ~33' 10 9715 4.~ B~ "~.1" 1 ! 9619' 4,276 5" ISS, N-80 12 98~ 4.~ ~chot La~ 3eal ~. 13 9S05' 4.75 X 4.~ ~ "FA-I" ~, size 85~7 ~ 9808' KB ELEV" 110.6' TQ" 10,312' ETD · 9,965' MAX HOLE ANGLE '" 20.13° ~ 2500' MID PERF ANGLE "$.5° FIStl 2 Junked Retainer 9/16/71 ~ 10,244' Junked Retah~er 8/I 2/72 ~ { 0,240' Wire linetools, 16,5' length 6/6/95 ~ 9274' SLICKLINE TAGS LS Tagged obstruction, metal protruding f/side oftbg, w/2.5" IB 6/26/95 ~ 9175' WLM Tagged obstruction w/1,9" OR 8/9/97 ~ 918 I' WLM WIRELINE WORK WFL ran on 1/22/98 indi~te a c,g leak (~ or near DV collar @ 4376'. Indications ofmultiple tbg leaks in one or both sting from 2400' Io 2650', STIMULATIONS Acidized w/2-t/2% }ICL A 12-I0 Mud a=id I Il18/71 B-I, B-2, B,3 & B4 G-5.DOC " 1,l~t~FoRn?io,~ fiATA, Zone Top, ~~t{, ~ ~. ~t~ndl~on O-1 S,2~ g~40 ~ 4 .... W!~7 ~n'fll~bn .. 0.2, { 0,2~ ~ 9~ le 4 1~el 0mn fl i~ G4 9,~ g,~ 1~ 4 1~81 ~fl~l~n Q~ g,~ 9,~ ~ 4 1~81 ~nfll~n O~ 9,4~ 9,~0 ~ 4 1~81 ~nfl~n .. ~ ~,~ e,~ ~ e 1~7;81, ~d ,, , · 2 9,?~ 6,~ ?E 6 1~1~81 ~d ' _~3 g,~ 9,87~ ~ 4 1~61 ,~d , B4 9,871' 9,~ ~4 9,9~ 9~ 23 4 ~1E87 ~nf/l~i0n ~~. ~.~.::,= ~ d. " ~ ~.t/~.~ .~._~ "¢5 %' "~ C ' REVISED: 8/11/97 DRAWN BY: SLT FEB-03-98 TUE 16:03 UNOCAL ASSET GAS GAP FAX NO. 9072637874 ?, 10/18 r, UI ~ GEOQUEST '[ 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHE ET DATE: January 30, lgg8 TIME: TO: Hal Martin/Chris Ruff PHONE: UNOCAL FROM; Rob North PHOHE: GeoQuest ICS FAX: RE= G-5 WFL Results cc,. Number of pages including cover sheet: 2 Message 12:18 PM 907-263-7675 907-263-78'74 (907) 663-1597 (907) 562-6521 Hal & Chris, Attached to tills cover letter is a Icg presentation of the WFL results for G-5. Below is a brief discussion: With the tubing to g 5/8" annulus open during injection the well was returning 1043 bbls to the surface. This flow appears to be coming in small part from the L$ sliding sleeve at 9082 and mainly from the SS slldlng sleeve at 9051, No flow Is seen coming up past the packer at 9119 fee[. ,. With the tubing to 9 §/8" annulus closed no up-flow was seen in the well, Instead down-flow begins between 2400 and 2500 feet Indicating at least one of the tubing strings ia leaking in this interval, Increases in the down-flow rate between 2400 and 2650 Indicate the possibility of multiple leaks, This flow continues down the tubing x 9 5/8" annulus to around 4000 ft wt~ere changes in velocity Indicate it possibly exits into the 9 5/8" x 13 3/8" annulus and continues down. Between 6500 and 7000 feet the down-flow stops indicating flow has exited Into the formation, I hope to have the G-40 and G-36DPN interpretations out shortly. Regards, Rob,.. FEB-03-98 TUE 16'03 FED- d_.-UO IIUll !O,U~' UN00AL ASSET GAS GRP FAX It0, 9072R37874 P, 11/18 ,I · , j, · , i UNOCAL, TEIU G-5, TRADING BAY UNIT, o.o ~.o o.~ ~.e o.~ ~.o 10~ :~ ~: ~ ' H ~, . , ~ ,,~ l~,', B~ ',. [:"~; ~000 ,, ~,mi~i:;,~4,,m¢~ ~,,.,,..: i~, FEB-03-98 TUE 16'04 UNOCPiL UNOCAL RKB to TBG Hngr = 45.$' Tree connection: Dual 3" $,000# 1112~1$ , RI' to MSL ELEV" TD" 11,336' ETO= 11,2tI4' MAX HOLE ANGLE = 34.$I~ 4200' Obstruction in -- tbg @ 1o,055 G-22 dwg.doc RSSET GfiS GRP FAX ILO,, 9072637874 SIZE CASING AND TUBING DETAIL ~ .... GIL,kDE CONN ID TOP P, 12/18 Trading Bay Unit Well # G-22 Completed 5/6/90 MT} Tt,'I) I~TM BTM. 26" I" wail 20" 13 ~3/8" 61 &. 68 9-.~/g" 47 9-5tT' 47 9-5/8" 47 Tublns: f,S 3-1/2" 9 2 SS 3-1/2" 9.2 24.0 Surf. Butt 19.124 Surf. 629' H-40 Butt 12 415 Surf, 5548' N.80 Butt 8.681 Surf 7016' P-110 Butt 8.681 7016 10,087' 5.~5 Butt 8.681 10,087' 11,335' N'.80 Burr 2.992 0' I 0,5g3' N.S0 Butt 2.992 0' 10,037' 6231' $915' 9984' 9330' G-1 G-2 G-3 G-4 ,-1 ~ 10,,180' NO. D~pth 46 60' A B 9994' C 10.030' D 10,036,67' btm 10,037.35' 1 6 ''='' 2 9994' 3 10,031' 4 10,478' ~ !o,51o' 6 DP MI) 10,507' 7 DPMD 10,512' 8 10,550' 9 10.582' btm I0.$S3' 10 DP MD 10,968' 11 DP ~ 10,973' 12 DP MD 1 13 DP MD 10,981,55' btm 10,982,30 JEWELRY DETAIL rD Item Cameron DCB l:~al 3.112' Tu~ing SHORT STRING ] _ ~,][[ [ [[ J, 2.72 3-1/2~ Otis "XA" $lidm8 81eev¢ 2.90 9-518" Otis "RI)IT' Dual Packer, 2.635 3.1t2" Otis 'XN" Nipple. 2.75 2.99 'Cf LEO IX}NO STRING 2.7~ 3.1/2" Oti~ "XA" ShdJl~ Sleeve 2.~ 9.5/8" ~is "~" ~1 P~ktr 2.75 3-1/2" ~s "~" Slid~s 2.75 3-l/Z" ~is ~ 8~ai~t 8lot Loc~r w/~.~' ors~ls ~ mule ~oe 4.0o ~$ Seal Bore EM. 2.75 3-1/2" ~is "~' Nipple 2,95 40 ~is "B~t' 2.99 Crosser ~EO _= T~ of Jur~ SLICKLINE TAGS SS Tagged fill w/2.343" OR 1219/97 ~ 10,480' L8 Taggcd Obstruction ia tbg w/2.125" LIB 12110/97 @ 10,055' Tagged Obstruction ia tbg w/2.25" Swedge 12/10/97 @ 10,490' WIRELINE WORK WFL ran on 12/18/97 indicated a :t:500 BPD csg leak between 4750' & 4800' originating from ~ pla' le~, STIMULATIONS 3 ~lage divert~r acid job: 138 bbb of 7.1/2% HCL, 200 bbl$ of 6 1/2% X 1-I/2% mud ] 1/21/89 G.Zone acid PERFORATION DATA ................ ' ............................. l ........................... ~ ............................ r'~::'='"i ......... i:ii~ ........ ; ..................................................... Zonei Top I,,am, }...,~n.t j $1~:,Ii~.,st,,.Ol~r,.i.~.esent,Condlt[o~ i ..... .... G i 1: ?~' 1~2 .~ 4 · '1~'~ : ~','1 :,'1~' 3~ , G.J ~ ~'~ T. 2R .L' ~ q P'B:~ L~t.,.~l :n ........................... , ............................ ' ............... . .............. ~ .................................. ~ ................. ¢.: ..... i..'...: ....... ,f :., ,T, ................. ~',~ ' ' l'.~:'~ ' ' T:. r'~ ...... ~t .~ 9&4 4~.'~9 , , .' ....................... , ',. ~"¢. '~'~"3~.~.'.'~...~s~7.'~ .... ."~"' ; .. :~ ........ ~v~... :~47~.~o~. . . . i . . ............................... . . . t ............... ,.v...,,~ -;,., .... ~...' ................ , ~, [,', r .,,, ,...%~ ....... ~ .............. ~-.h..[., , r ...... ~ ~SED: ~/3/98 D~ BY: SLT .... . FEB-03-98 TUE 16'05 UNOORL {~$SET GP~$ GRP FflX NO, I I I i i 9q7?a3787d GEOQUEST 500 W. International Airport Rd. Anchorage, AJaska 99,518 FAX COVER SH 0ATE: January 14, 1998 TIME: TO: Hal Martin PHONE; UNOCAL FAX: Fr~OM: Rob North PHONE~ GeoQuest ICS FAX: RE: G-22 WFL Results cc: EET 6:18 AM 907-263-7874 (907) S63-1S97 (907) 562-6521 Number of pages including cover sheet: 3 Message Hal0 Attached to this cover letter ia a log presentation of the WFL ,results for (3,22. ·, Below is a bdef discuss[on: ' :', The WFL Up Flow rates were calculated for the tubing x 9 5/8" annular area,.,, This flow appears to originate from a leak In the packer at 999~ and-continues' up until it exits the g 518" casing between 4800' and 4760', An additional'small, · '" leak out of the 9 5/8" may be Indicated by' the drop in Up Flow rate between .' 6000' and 5500'. The WFL Down Flow rates were calculated for the 9 5/8" x 13,3/8" annular area .. from surface to the bottom of the 13 3/8" at §548'. Below this point the area was assumed to be the f~ll g 5/8" x 12.25" OH annulu;. Increase or decreases In this annular area would have a corresponding effect on the calculated flow rates, The data lndlcates Down Flow starting between 1800' and 2000' and continuing down beyond the last station at 9500'. The possibility exists that the Indicated Down Flow may be in the tubing x 9 5/8" annulus from 2000' to 4750' at which point it converges wilh the Up Flow and exits the 9 5/8" through the same point and continue8 down outside the 9 $/8', The tubing spinner surveys both show an unexplained drop in Injection rate below -1000' which may best be explained by a ID reduction above this point (scale?), The Long String survey shows an additional sllght drop just below 1500' which could account for the start of the WFL Down Flow Indication mentioned above. It should be noted that the splnn_er Injection r.a? m?~"'"~d .~n the Short FEB-03-98 TUE 16'05 UNOCAL ,ASSET GaS GaP FaX NO. 9077a37874 P, 14/I8 String (-6000 BPD) is greater than that of the Long String (-5000 BPD) which Is In opposition to the surface reported Injection rates (SS ,-- 3570 BPD, L$ = 5118 BPD). The spinner data appears to be verified by the temperature data which shows cooler temperatures In the Short String wl~ich would be expected at a higher injection rate. Hops this gives you some more food for thought, I am Interested In any ~tdditional Information or ideas you may have. Give me a call when you've had a chance to look It over. Regards, Rob... FEB-03-98 TUE 16:0~ JflN-lfl-~JB NEY FEB-03-98 TUE 16'06 UNOORL RSSET GAS GRP - ..UNOCAL ," FC~X N~. 907¢;378741i i · iii RKB to TBQ Hngr ~ 41k8' Tree connection: Duel 3" 16" 75 l S-.1/'6' 68 9-5/8" 47 9-5/8" 47 9-5/8" 47 9-5/8" 47 Tubing: L~ 3-1/2" 9.2 SS 3-1/2" 9.2 CASING A~D TtrBING bETAIL' GILA.DE CONN []:) TOP P, 16/18 Trading Bay Unit Well # G-40 Completed 4/26/90 I I I I MD TVD BTSd K-55 Butt 15.124 Surf. t 926' 5-80 & K-SS Butt 12.415 Surf'. .qt2l' K-55 Butt 8.681 Surf 47' N-80 Butt 8.681 47' 976S' 9Z20' $-95 BuR 1.6ll 976S' 10,929' 10~O0' N-10 Butt 1.611 10~929 11,146' 5.95' BuR 8.681 l 1,146' 11~32' 10~606' H-80 BuR 2.992 ~' I 0,4~' N-66 BUR 2.9~ O' 9827' ~90' 2.72" LIB ran on 816/97 shows tbs to bc oblongcd 2,72" X 2.es" @ ~,o 1 7 6 RT to MLLW ELEV= 103' TD = 41,267' ETD" 11,143' B-1 8-4 -= WF-3 -= WF-6 ---_ =' MAX HOLE ANOLE = 27.2° ~ 8900' G-40,DOC NO. , Deptl~ 40,00' A 9760' 2.75 B 9796' 2.90 C 9g13' 2.6JS D 9826' 2.99 btm 9827' _ nl Il I ag[ _ ~ 979S' 2.~0 3 10,148' 2.76 4 10,3eS' 6 DF MD 10,17g' 4.00 6 DP MD 10~~ 4,00 bbs 7 10,428 2.75 g 10,58~' 2.95 btm 10,~83' JEWELRY DETAIL ID Ite~ Cameron DCB Dual 3-1/2" Tubing hanger. SltORT STRING IllI Illll I Illll Ill J-l/2" Otb "XA" SIIdln[ Sleeve 9-5/~" Otb "RDH" Dull Pacer, 3-1~" Otis "~ NIppIe~ 2.7~ Ball Catcher Sub ~NO I I I _1 Il ~llll[ l[Il II 3.1~" Otb "XA" Sliding Sleeve 9-~" Otb "~" Dull J-l~' O~ "~" Sliding Sleeve Otb ~l~hl Slot ~citor WI l.l' of,fill Offs Seal Bore EzL 3-1~" OOs "X" ~lpple ~G SLICKLI:NE TAGS 8S Tag "XN" w/2.72" GR 8/5/97 (~ 9813' LS Tagged obstruction w/2.72" GR & 2.72" LIB 816197 ~ 5,012' Tag fill w/2.25" LIB 8/7/97 ~ 11,086' WIREL~ WORK LS · Spinner ran on 1/22/98 Indicate6 tbs leaks ~ 9812' & I0,125' · WFL ran on 1/23/98 indicatu rag leak between 3250' & 3350'. · WFL Indicated multiple SS tbs leah, sldg siva ~ 9760', tbs Jt between $1dg siva & pkr and between 1200' to 3400'. STIMULATIONS 2 stag acid Job wt dlverter, 50 bbb of tICL & 75 bbb of 6-1/21/~ X 1-1/2" mud acid 2 stag acid Job, 40 bbb of IICL & 135 bbb of 6-1/2°,4 X 1-1/2" mud acid 3/29/90 West Forland 3/29/90 H.B-I & 2 Accum. Date Zone ,T?p Btm Arm SPF Last Opr, Present cq,ndi, t.!.nn 9 680'. ..... ~,662' 2' 4 .,. 3/2..0!00.Cmt 5qz ,,, :a. il e,e_s_2'._ ,,126' 34' e 3/~_e!eo.. Opln f/injection '" S,g34' ....... .,113S' 2. 4 3/19(90 .. -: Cm_t ant . 101111' .1.0,!!_3' 2' 4 . .3/16/90 ,Cmt S~ ~4 .10J. 28' ,I0,20e' eo'. .. e. .3/2e/90 open fl Injection 10,218' 10,220' 2' 4 .... ,3118190 Cmt ~lqz ....... 10,455' 10,457' 2' 4 3/1/IlO Cml 8qz_ .......... iF-2 10,622.' .... 10,666' 40' 8 3/26/90 OPen fl Injection WF4 10,!60' 10,770' 90' B . 3/25/90 Open fl InJec. tlon WF .~ I0,633' t0~8~8_.__'... 52~ II ..... .3/26/10 Open fl Inl~=L~n . ,WF, .~ lO,e.!S' 10,17~2' . 67' 6 , ..3/26/a0 Open fl Injection ..... WF -7 .10~993' !!,040' 47' 8 3/26/90 Open fl Injection . .... ~1,;042: .... ~1.044: 2' . ......... 4 =. ,~117/"Q- Cmtllat ' ' .... "' ..... REV/SED: 2/2/98 DRAWN BY: SLT ... ¢,; ,? "~7C. '' .;,: FEB-03-98 TUE 16:07 JflN-30-98 FRI 1 .o · UNOOflL RSSET GRS GRP FhX NO, 9072637874 P. iT/t8 P, O1 GEOQUEST 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER S HE ET DATE: January 30, 1998 TO: Hal Martin/Chris Ruff UNOCAL FROM; RE: CC~ Rob North GeoQuest lOS G-40 WFL Results TIME: PHONE: FAX= PHONE; FAX: 3:44 PM .907-263-'7675 907-263-787~ (907) 663-1597 (907) 562-6521 Number of pages Including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a log presentation of the WFL results for (3-40, Below is a brief discussion; With the tubing to 9 5/8" annulus open during Injection the well was returning 1040 bbls to the surface, This flow appears to originate from the sliding sleeves at 9762 and 9760 in the long and short strings, No flow Is seen coming up past the packer at 9789 feet. With the tubing to 9 5/8" annulus closed up-flow continues at a reduced rate. This flow travels up the tubing x 9 6/8" ~nnulus until between 3380 and 3250 ft where It exits the 9 5/8" casing, An addltlonal up-flow la measured across the lower packer at 10378. Down-flow In the tubing x 9 8/8" casing Is seen starting between 900 and 1200 feet. This flow continues down and appears to exit the 9 5/8" casing In the same Interval as the up flow mentioned above (~3300 It), This combined flow then travels down the 9 5/8" x 13 3/8"/OH annulus to the reservoir at or below 10000 f~et. Working on GI-3ODPN now. Regards, Rob,.. FEB-03-98 TUE 16'07 · JI~N-30-9B FRI 17(~ UNOCAL RSSET GRS GRP FAX NO. 90~,7637874 P, 18/18 {'"' Seh,l,'.,.b~rtt~r F~ . ~ '?q,3300 P. 02 I , , i _ , ii ' ! UNOCAL, TBI) eur.40, TRADING BAY UNIT, 'WFL~ 23-Jan-g8, (98011) ~'"'"""~"'" I~"~"'~ It''''''~'''r~ I w,~:,. ~;il~ ,~, i ,,,, ! ~,~ ( :':'" LliLII ~.l ' :I..,]!1' - i. i llli lli,',b' -IT --~-[~.?il,',','I- , I ~ :ii l]ltl',tit!i:l...-",,I -I f!:;;'l,'~i-: Iii' ' ' ,.!' ~:}.:.'sj ,." .,: ' ~:',...":il:,;'~:-i -- ' f " ]lti'l~l'::,: t, lti-, ~11 60IX) I ! ,I l~ I~lI I ! ' L - ,t i ~! ~'~ili ~ [:iili _ 1_ ! t '1,1: ' ~,!,"~tl- , -I I l,Jd, ~L~,i, tl.. ill _I',1' ,/_:: ,'.,' !,:,,,~ II ,,, . !~ . . ., II"" ' ' Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) December 28,2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Request time extension of variance for Grayling Platform Well #G-40 Dear Tom: Unocal requests permission to continue injection and a time extension until 7/31/2002. Our plan is to get the survey run as soon as possible, probably in January. The well is currently inaccessible due to drilling equipment on leg, but the plan is to move the equipment and get the survey run before the drilling operations begin for the 2002 Grayling Rig Program. History: G-40 has communication between the tubing and the 9 5/8" casing. A jug test was attempted on 11/20/98 with inconclusive results. However, the results of two temperature surveys, one ran on 7/20/99 after a 18 month shut-in time (following years of injection) and the second one ran on 8/5/99 after a 12 hr shut-in time (following 7 days of injection), depict no injection water exiting the wellbore above the packer. Based on the above information/data a variance was granted on 10/5/99 which was good for 2 years. Since injection was restarted in this well in Jan 2000, the tubing pressure has been held at 70% of the casing burst strength and the injection rate has slowly declined (see attached chart/data). G-40 is currently injecting. It is an off structure well that poses minimal risk to the shallow gas reservoirs, due to its location in the acquifers and there is no evidence of further mechanical failure since the variance was granted on 10/5/99. Attached is a 10-403 for your approval. If you have any questions regarding this, please contact me at 263- 7830. RECEIVED DEC 2 1 2001 Alaska Oil & Gas Cons. ~ Chris/6phdr A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management Aogcc Grayling G-40 Variance 12-31-0 l.doc 9/18/99 STATE OF ALASKA :i ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon: Suspend: Operation shutdown Re-enter suspended well Alter casing: Repair well Plugging: Time extension X Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: 2. Name of Operato 5. Type of well 6. Datum elevation (DF or KB UN(J(.;AL Development X 103' RT above MLLW feet 3. Address Exploratory 7. Unit or Property nam~ Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well numbel Leg #1, Conductor#25, 1900' NSL & 1459' WEL f/SEcomer, Sec. 29, T9N, R13W, S.IV G-40 At top of productive interv~ 9. Permit numbel Top of Hemlock-9887' MD, 663' SNL & 2417' WEL f/SE corner, Sec. 32, T9N, R13W, S.IV 90-3 At effective deptl' 10. APl numbe~ " 50-733-20412-0C At total deptl' 11. Field/Pon 11,267' MD, 1155' SNL & 2653' WEL f/SE corner, Sec. 32, T9N, R13W, S.M McAurthur River / Hemlock & West Forland 12. Present well condition summar Total depth: measured 11,267' feel Plugs (measured', true vertica 10,638'. feet Effective depth: measured 11,143' feel Junk (measured~ true vertica 10,499' feel Casing Length Size Cementec Measu red deptl' True vertical depff Structural 421' 20" Driven 421' 421' Conductm 1,926' 16" 3,400 sx 1,926' 1,926' Surface 5,128' 13 3/8" 4,950 sx 5,128' 4,973' Intermediate Production 11,232' 9 5/8" 2,710 sx 11,232' 10,606' Liner Perforation depth measu red See Attchment true vertica Tubing (size, grade, and measured deptl' LS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl Clr Cplg w/TK-99 Internal Coating @ 10,46: SS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl Clr Cplg w/TK-99 Internal Coating @ 9,82' Packers and SSSV (type and measured deptl' Otis "RDH" Dual Pkr @.9796'~ otis "BWH" Perm Pkr @ 10,382' DPM 110,375' DILi 13. Attachement.~ Description summary of proposal Detailed operations prograrr BOP sketch: ,. 14. Estimated date for commencing operatio 15. Status of well classification as 16. If proposal well verbally approvec Oil: Gas: Suspended: Name of approve Date approve( Service: Water Injection 17. I hereby certify that,.t,he fore,,qoi~g~ true and correct to the best of my knowled.~ Ch r~~ Si~lned: Title: Senior Reservoir En~linee Date: 12/20/01 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneIIAppr°val No Plug integrit~ BOP Test Location clearance ' Mechanical Integrity Tes Subsequent form required 10 Original Signed By Approved by order of the Commissione Cammy 0echsli _._, _,_ Commissioner Date 3 i- ECEIVED DEC 2 1 2001 A~aska 0il & Gas Coos. C0mr~issi0n Anchorage Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-40 Injection History since 9/98 6OOO ® o ~ ~ CD Z ~~. ~ O0 O0 C7) O~ C~ O) 0') 0') 0 0 0 0 0 0 ~ ~ 't'- ',ti C'q 04 o~ o~ o~ c? o'), o') o) o o, o, o, o, o o, ~ o ~ o o, c? o~ CD Z ~ ~ CD Z ~ 2~ CD Z 03/01/2002 15:48 FAX 9077766635 IJNOCAI~ GRAYI~I NG _ {'¸ Monthly Injection Report ~ oo4/oo4 Page 1 .R_et_t~. t o Ma!n ._-q_e_n~_ WATERFLOOD INJECTOR MONTHLY REPORT GRAYLING PLATFOR1M: G-40SH - 507332041200S01 Hfs volume Tbg 13.375 Csg 16 Csg Well Date On Injected Press Press Press G-40SH 2/1/02 24 2355 2200 660 260 ~ i ii Illll ' I ......................... G-40SH 2/2/02 24 2277 2200 660 315 G-40SH 2/3/02 :24 2203 2200 670 260 11! ill i ii iiiii G-40SI 1 2/,;/02 24 2243 2350 680 250 I~ I III I (}- 40 SH 2/5/02 24 2262 2300 640 2 70 G,40SH 2/6/02 24 ' 2358 2200 ...... 640 2/0 iiiii ii iiii ii ti G-40SIt 2/7/02 24 2369 2250 670 260 G-40 SH 2/8/02 24 2366 2350 660 2(;0 G-40 SH :2/9/02 24 2346 2300 650 '260 G-40SH 2/10/02 24 2366 2300 650 2.60 Co'-40SH 2/11/02 24 2362 2250 630 G-40SH 2/12/02 24 2371 2300 650 2 G-40SH 2/13/02 24 2375 2300 640 265 G-40SH 2/14/02 24 2342 2200 660 15 . ,i J,, i .... ' .............................. G-40SH 2/15/02 24 233.9 2250 685 270 O-40SH 2/16/02 9.5 1561 2200 680 270 i ii II 11 G-40SH 2/17/02 14.5 1358 2200 740 2 75 'G'~-~0SH 2/18/02 24 729 2200 740 275 -40SH 2/19/02 0 0 650 745 280 G-40SH 2/20/02 24 0 600 740 280 i Hill II I G-40SH 2/21/02 24 0 600 740 285 il 1, ....... .u.,. · ..... .,~......~ ......... G-40 SH 2/22/02 0 0 600 720 285 i l,itlll i i G-40 SH 2/23/02 24 0 600 720 285 Hill ,llllllll ,, iii l O-40sIt 2/24/02 0 0 600 721) 285 G-40SH 2/25/02 24 0 600 700 290 G-40SH 2/26/02 24 0' 540 700 299 ..... !G-40SH 2/27/02 24 0 540 700 290 :G-40SH 2/28/02 24 0 600 660 290 ....... I I ,m ~ III IIIII '- I ii You are user number 236 o. this websffe and this page has been hit 11 limes since 10/27/2000. ht tp ://kodiak. anchortown, uno cal. c om/S urveillanc e/I nj e c tor__V ad anc eReport, asp "311/02 02/01/2002 0l:0l FAX 907776663,5 · UNOCAl, GRAYI,I NG Montl.~ly Injectio~'~ Report [~] 004/004 t"age 1 W A T E RFLO OD.. 'I"N J. E:,(..-'" 1 ' OR M O NT ,H LY R E P ( ,')'R T (;RAYLING I>I_,AIFORNI ' G-.40S}! · 50733204120(]S()1 Hrs Volu m e l' bg .I 3.3 75 Csg 16 Well Date On Injected Press Press Press G-40SI I I ," I ,'02 24 2()91 '~ ~. (')() 680 25 5 : II~ I II IIIII G-4t)SH I/2;02 24 "'~ 22~' () ~0. I 675 255 G-40S}.t I .."3..:02 24 2143 2250 660 G-40SI-I I/4,,02 24 2056 22(}() 670 260 G-40ST 1. t/'5:02 7 640 2 .I 00 700 260 ................ O-40SH I/6/02 24 I 2 I!' I . 2200 685 260 G-40SH 1/7.'02 2,1 ~ ' · = III 220(I 670 260 G-40SH I/'8/()2 24 2127 2200 660 260 G-40SH I./.'9'.,( y'_, 24 ,_'~ 103 '~'~- ',..4)I) ' ................................... 650 260. G-40SH I / 1 ()/02 24 2104 22()0 650 260 G-40SH I/I 1/02 20.5 I843 2200 650 250 . , ................... .................. , L., ,,, ~,~ G-40SH I/12/()2 24 2148 2200 ,420 26() G-40SH .I/I 3/02 24 2109 22 (')() 640 260 G-40SH .... ] ........... .I,"I 4/02 19 1670 2200 66'5 "' 26(:) :. ::, ;:, G-40SH I/I 5/02 24 19(:)3 2250 670 260 G-,10Slq I/I 6,;02 () 0 500 695 3 ) 0 O-40SIJ I/17/()2 24 1455 1900 710 - .... · ,c 22U1 G-40 S}.I I / 18/()2 24 _2,-)7 695 ?60 :7 :::::.::::::~ ,.;tUll, ~ ............ = ............... G-40SH ' (' * 24 I, 1:),, O~ '~q45 '~ '4' ....... >,. {.) 670 260 , , ........................ - G-40SFI I ,;20.,"02 24 2522 2300 670 26() G-40SH I/21/'02 24 2514. 230() 660 26(i} ......................... G.-.40SH 1/22./02 24 2515 2300 660 260 G 40 Skl. I/23//)2 .~a" ' 2365 2300 640 255 ..Q.7.'.I:0.S H I/24/02 24 24. 41 23 (2)0 630 i ................... ' ' ' ..................... ;.,.--.. G-40SH 1/25..'02 24 2505 2250 630 255 Q.:!~!)SH 1/26./'02 10.5 t076 2250 630 2.55 G-,40SH 1/27,/02 9.5 988 "" ,:.~ ~ t)700 265 :-: : ....... 1, .......G-40SH' t/28/02 24 26,54 2350 (,8() 26 : :.. ::::::::::::::::::::::: G-40SH J,/29/"()2 2,4 2673 23()() 66() 265 .......... ill G740SH ] ,,'"30.,"02 24 2668 230(.) 66(i) ?6 .) ...... ~).-4()SH 1/31/02 24 2665 2300 660 260 http://kodiak anchortown.unocal.com/Surveillance/h:~jector_VarimaceReport, asp 2,/1/02 01/01/2002 {11226 FAX 9077766635 IJNOCAL GRAYI,ING I~..j 002 / I:) 04 Page 1 of I IG-40SH -_j' iDecember: i200'~:' e~l WATERFLOOD I~JECTOR MONTHLY REPORT GRAYLING PLATFORM · G-40SH: 50733204120OS01 ..... Hfs "~Z'olume ~'~- ....... 1;.37:3 Csg 16 Csg Well Date On Injected Press Press ['ross O-40SH 12iI/'01 24 2377 2300 680 250 G-40SI-I 12!2/01 24 2363 __ 00 590 250 - __ : : .. , O-40Slt 12/3/01 24 2367 2250 600 25O o.4O~H .......................... l":~-i~.)~: ......... 24 2389 2250 "' 585 250 G-40SI-I 1215/01 24 2360 225(1 600 250 ~.,40SH 12/6,'~i 2.1 ........... 2i7~-' :' :: ....... 2250 ........... 6'10 ..... G'40SH 12/7t6i 24 2388 ................... ~:':~7 ........ 610 .................... ~'5"~; ............ _,uul~ : .............. ~ ............. . ....................................... .-..1 ~,,... G-40S[I 12/8/01 24 2411 2250 630 250 G-40SH 12/9,/01 24 2370 2250 630 250 G-40SIt 12/10/01 24 2321 2300 640 250 O-40SH 12111/01 24 2317 2200 640 250 -~ ;_-,..,. ~.~. .................................. .~,-,,. ,.~,.,,_ .. _ ..................................... O40SH ....... 12/12101 2-1 2314 230t'~ 650 250 . c&.40SH 12/'13/() 1 24 2368 23(.1(~ 650 250 G-40SH 12/14/01 14 1210 2250 640 250 ~G-40SH 12/15/01 t'} 0 2250 640 250 'G-40SH 12/l 6/01 0 0 2250 640 250 i G-40SH 12/17101 24 466 200~ 620 190 G-40SH 12/18/01 24 2144 2200 670 260 II _ _ ,.lUl.,ll.l. ~£ i / j~ll ~ , G-40SH 12,/19/01 24 2173 22(1(I 650 260 G-40SH 12/'20f01 24 2131 2250 650 255 i G-40SH 12/21/01 2.1- 2 ! 00, 220(1 650 255 ! O-40SI-I 12/22101 24 2 I, 55 2250 650 255 G-40SH 12/'23;'01 24 2222 2200 635 255 · .~ ,..} G-40SH 12/24101 24 2163 _.~00 630 250 G-40SH 12125/01 24 2116 2250 630 255 G,-40SH 12,t26/(11 24 2088 2301.) 650 2!55 G-40S[t 12i27/0 l 24 2060 2300 655 255 ................. G-40SH 12/28/01 11.5 I 159 2300 655 250 G-40SH 12/29/01 24 2138 2300 655 250 G-,:I.0SH 12/30/0 l 24 2101 2200 700 255 (3-405I-[ 1213 l/01 24 2074 2200 680 255 Yt2u are user num['cr 552 on this wcbsRe and Ihis p~,ge ha.,. b~'~':~ hit 43 limQs .~mce 1!~, 27.2(1~.m http://kodiak.anchortown.unocal.corrffSurveillance/Injector_VarianceReport.asp 1/1102 )077766635 UNOCAl, GRAYI,ING [~003/O04 II 1B~UNOCAL~I~ Monthly Injection Report Wt~tTERFLOOD INJECTOR MONTHLY REPORT G~' ~G P~O~: G-~SH: 507332~12~S01 .... _ - ...... WeU Date H~ ' 'Volume T~g 13.37S ~g On ~jec~d ~e~ ~e~ 0-4¢ ~H 1 ]/l/01 24 ~ ~ 610 260 G 40 ;H 1112/01 ~ 2321 2300- 620 265 G-40 :H 11/3/01 ~ 2308 2300 620 [G-40 ',H 1 l/4/01 24 2321 ~00 620 34 ,i i i , _ .... ~ ,q .., G-~ ;H 11/5/0I ~ ~87 23~ 620 265 G-~.H ~/6/0~ ~ ' ~30 ~00 620 260 G'40: H 11~/01 24 2421 ~ 620 260 .. G40t H 11/8/01 ~ ~S3 ~ - - -050 ................ ... 040: H 1 l~ml 24 -~ ~01 ~00 640 ................ ~5 " I I Il I I Off~ H I 1/10ml ~ 2272 23~ 640 255 0-~5 a 11/11/01 ~ 2283 ~ 630 255 _ O-~5 H I I/I~01 D~ 2211 ~ 620 260 .... O-*)~ H 1 t/13/01 24 1176 23~ 620 .... ~'} ...... G-~S t .I 11114/01 0 0 7~ 670 ..~ , ,, , ,___. ~ ~ . I ., , ~ ~, ........... O-40S 5 11115/01 ~ 1583 2i~ 620 260 G-~S ~ 11/16/01 24 2365 23~ 620 260 . . G-40S H 11/17/01 ~.5 2312 2250 670 264, O-~S t 11/i 8/01 ~ 2323 ~ 640 260 .... , ~, ... .... , ,, .__~, , ....... I G-~S t 11/19/0I 24 2305 22~ 650 260 G-4.0S t 11/20;01 ~ 2304 22~ 670 260 I I I III I c~-4°s { ~ rtz]tot 24 2331 2~0 675 ~1 ~1~,, ii - i i, i .. ... G.~S ~ 11/22/01 ~ 2324 22~ 650 260 I ....................................................................................................... : ................ IIII hi ...................... I ............... II'"ql['A KIllr'rll,l~l,tln iiirl , G-40S] [ I 1/23/0I 24 2319 2~0 650 260 . il.il ..il ii u i i I . OLds] [ 11/24ml 24 2324 22® 615 260 O-~S~ [ 11/25/01 24 2354 2250 630 260 I ~l ' I I I , ,i I Ill I I III G~S~ I 11/26/0I ~ 2370 2250 6~ ~5 G-,40SI 1U27/01 24 ~60 2250 6~ '] 250 I I II II l Oi40Sl 11/28/01 24 2361 2~0 600 G-~Sl .... 11/29[~1 ~ ~83 2250 .... 590 G-40S1 11/30/01 24 2391 23~ 680 Yon ~ t ~,r amir 263 on ~ westin ~d ~ pag, ~ ~u ~t 30 ~o~ ,~co 10/27/2~. hup://~ odiak_~cho~own.unocM.co~S~eHl~ce~njecto~V~ceRepo~.asp 12/3/~ 1 11/01/2001 15:04 FAX 9077766635 ., UNOCAL GRAYLING ~ 0o4/o04 t*age 1 ............... "'"-'"""> ...... Menthly ]Injection Report ................. .................................................................. ....................................... . .................... ............... -40SH '~'~: Odober . ,, . .[ .... ,,., .................................................. ............................................................ , .................................................................. ....... WATERFLOOD INJECTOR MONTHLY REPORT GRAYLING PLATFORM' G-40SH ' 50?33204 I20()S01 Well Date tits Volume Tb.~ 1~'.~75 Csg "i~' Csg On, Injected Pmss Press Press G40SH 10/1/01 24 2370 235(1 555 - - - 28U , .~, .... G40SIt 10~/01 24 2315 2450 570 - ~80 GMOSH 10/3/01 2,1 22 q 9 24 ~0' 570 27 ~ G40S.[t 10)t/01 24 2240 2400 56~' - 280 GMOSH lO/SlO 1 24 2257 2350 590 280 --,, ~ G40SH 10/6/01 -24 2245 j ~350~ ..... " 640 280 ......................... m_, ........... G~0S}I 10/7/01 24 2254 2350 645 280 O408}.t 10/8/01 24 2271 2300 640 275 O~0SH I.~(9/(H ..... J 2.~ 2246 2300 600 280 G4()SH 10/10/01,i24 22.57 J 2300 650 285 G40$II 10/11/01~ 24 2294 ,1 _.~0~ .... 660 280 ......... %% ..:%% ~ ~,, (;4OSll 10/12/01 :.24 2~0o ..... 1--'23'~{~ 620 . 275 ...... 640811 10/13/01 24 23i 5 2300 60~ 270 G~,OSII 10/14/01 24 2308 2300 600 270 ................ - ....................... ' i, ~.0SlI 10/15/01 24 2286 2200 600 275 osH o/'i,/ot 24 ......... ........ 2 0o '" soO' 27( .... m ..)~..-.. ..... ................ O-,~OSt I 10/I 7/0 [ 24 2297 2300 620 270 .......... 0-40811 I0/18/01 24 ~'22g~- 2300 6,{ 0 270 ........ G~{)SH I 0/19/01 24 2310 2300 64'6 27o G~0SH 10/20/0I 24 2310 2300 630 270 .......... ~":~ ............ .......,.~. i O40SH 10/21/01 24 2290 2300 ' '~;'~7- 2~~ ............... m'"'--'$"=r.c* ............ ~..~'~, ~- ~ ............... L G-40SH 10122t01. 24 230.1I 2300 600 270 O~0SH 10/2310I 24 2302' ~ ................ 5}00 600 ..... 270 ...:~2~''' ."X~Z.~.~......:...: .~ : ~. ~ G~0S}.t 10/24/(11 24 2307 2300 600 320 O40SH 10/25/01 24 2312 2300 600 320 ~.~..., ................... ~,--u;.:.:t.:...::=. =: G~0SH 10/26/01 24 2304 2300 600 265 G.~I.0St{ 10/27/01 24 2300 2300 600 265 G-t.0StI I0/28/01 24 2406 2300 .............. ' 600 275 (;~0g[ I 10/2 9/0 ! 2,1 2315 230(} 625 265 .............................. , O~.0SH 10/30/01 24 2323 2300 620 265 ...................................... , , ~. ~ ~ You ar* u,¢t muu~,:t' l I l off tki. o web, itc and tl~is pot-c hay l,~ca ha 12 tmmu nin~.u 10.27 '200,.). I 1/1/01 10/01/2001 01'$7 FAX 9077766635 UNOCAL GRAYLING ~004/'004 , ti' Monthly Injection .Report Return to M..fin WATERFLOOD INJECTOR MONTHLY REPORT GRAYLING PLATFORM' G-4()St'J - 5o7332041200S01 Hfs Volume Tbg 13.375 Csg 16 Csg Well Date On Injected P tess Press Pres (}-4 0$H 9/1 [01 24 24.23 2300 520 295 ,oa ...... - ...... z _ 6-40SH 912101 24 2419 2300 560 295 G,40SH 9/3/'01 24 2416 2300 ' 540 295 C-~0$H 9/4/01 24. 2425 2300 540 295 G-40SIt 9/5/01 24 2432 23011 540 290 O-408t. t 9/6/01 : 24 2448 '~"' ' ~.,~'00 '5311 290 G'40SH 9/7IOI .......... 24 2437 ................ ~'.'. 00 525 ........... 'l 285 (]4081I 9/8f01 24 2435 2300 535 290 G-4OSH 9/9/01 24 2401 2300 535 290 G-40SH 9110/IH 24 2-398 2S00 ' 5511 290 G-40SH 9/1 t I01 2'I 2387 2300 5~10 290 (¢408I i 9112101 24 2395 2300 660 ..... 2911 ' ' S, 2100 G-40, H 13701 I6 1844 620 290 t21-4 0SH 9/l 410 ! t 4 1455 21 O0 620 29 O-408t't 91I 510'! 24 2432 23110 630 ................... 290 .......... ;:-_ ......................... ,,,,,:,,:,,:....:;.:..._.:.:;;:=_ ........ 10-408H 9/16/01 24 2471 2300 ~2~ - 620 'O-40SH 9117101 2.; 2469 2250 600 285 [6-40SH 9tl 8/01 24 2482 2300 600 285 G-40siI............................... i)/19101 24 2482 2300 6011 285 Oq0,qH 9120101 24 2,105 2300 580 290 :O40St..I 9/21/01 24 '2~05 [ 2300 570 2.80 (i'-40 SH 9122/01 24 24119 2300 570 280 C~-405'H ~/2,3/0I 24 2404 23(R1 560 285 (340 SH 9125101 24 24 :SO 2300 510 285 G-40St't 9116101 I' 24 2455 230[3 560 285 C.,--40$I I 9t27/01 24 2453 2~00 5')~0~- .......... 2 G,40sH" 9/28/01 24 2460 2.~0(1 525 280 ........ ;.:;~.:.r_-;;:;;:.. ....... ....: ....~_.... -_~... G-40St I 9129101 24 2473 2300 560 2 8[) ' -- --,---.~;e v:-;, .- - ,.,~.,,~,,.~;,.- ;,,,.-w::;:::rwv:,.,.:,v;::.;:..:.:z.;.,.,~..:;:_-.:_::_ ..... - ..... , ................ .:_ ........................... (.,-4 18I'f tF30/01 24 24(;7 2t0fl 550 You ~¢ us¢~ number 95 m this wcbfite and thi.~ pa.~c ha.~ been hit 5 time.q ,inca 10,27."200(). http;//ko diak, anchortown, unocal, c om/Surveillance/lnj ect or_Varia~ ce,Rep orr, asp 10/1/01 09/01/2001 03: 42 FAX 9077766635 I. rNOCAL GRAYLING ~004/0o4 Page I of 1 Ro~lm lo Main mtmu WATERlrLOOD INJE(.'TOR MONTHLY REPORT GRAYLING PI,ATF'OI{M · G-408H - 507332f~41200801 'Ers Volume Tbg 1~.375 Csg 16 Csg Well D~te On L. jected Press Press Press G40SH 8/1/01 24 I 2618 2300 500 290 (?-40 SH' 8/2/01 24 2598 2300 670 670 G-40Stt ' S13/01 24 0 235{I 690 30~ .................... G,.40SH 8/4/01 24 26.35 2300 690 300 G-40SH $/5/01 24 2712 2300 690 300 (}40SFI $/6101 24 2710 2350 690 300 ................................................................ .................... : ........... . G-40811 8/7/0 ] 24 2697 2350 690 300 (i'-408H g/g/01 24I 2701 2350 690 300 G.-40SH 8[9/01 24 2705 [ 2.,.'50 690 300 (}40SH ....... i/10/01 24 2703 2350 600 280 (35i05tl g/1 V01 24 2686 2350 600 290 G40SII 81-i'~01 ..... ' .... 24 2679 2350 590 295 !G40Stt ~/I 3/01 24 2679 2350 590 300 G-40SH g/l 4/01 24 0 ,.., ~ 0 580 300 G-40SH $/15/01 24 0 2,'; ;50 554 300 O-405H 8/16/01 24 0 . 2...3:5..0. ............... ........................ _550 298 G--40SII 8II7/01 212 0 ' 600 550 298 O.-4 USH 8t 18101 24 2433 2300 6O0 3OO --. Gd0$.t't 8/I 9/01 24 2488 2300 600 300 ...... :.::.;:=.:=.....~,, · ~, ~ .....:::.t~.=:.:.........:.--- 24 225O 29.,~ G.q 0S! t 8120101 24 2471 fi-40SII 8/21/01 24 2473 [ 2250 56'5 G-408H 8/22/01 24 2470 2250 55o 3oo G-40SI I 8/23/01 24 2444 2250 550 300 .............. , ...... .' ' ".:,:..:,::,:272":---': ......................... . ' {G-d0SH 8/24/01 ........ 2'i 2488 220o 54o 300 :(3-40SH 8/25/01 24 2430 2250 500 295 G.,40SH 8/26/01 24 2423 2250 520 295 G-40SH 8/27/0 ! 2 4 0 2250 520 300 J 40'si, ' ?ii3iin"' 24 24t4 '2250 540 2 0405I:'I ........ 8-~50/0'1 24 24.19 2250 540 295 6-40811 8/5i'26i .... 24 24.09 23{1o 530 295 ....... _ ~,,.~,~,,;:....._~--. i m i ......... '-~ You am u.~cr manb~r lr~7. O~ tht:: uol~ite anti tbi.~ p.L-_v h,~.q hr:an h~t 14 tmm~ sint;e 10, '2'~ 2ocJU. http ://kodiak. anchortown.unocal.com/Surveiltancedlnjector_VafianceReport, asp 9/1/01 05/01./2001 00:$2 FAX. 9077766635 UNOCAL GRAYLING [~002/004 i. u NO _aL . - ~ ,, .~ r~,_Y Monthly Injection Report ................. ,.. ...................... ... "'l ......... i WATI ;~LOOD iNJECTOR MON~LY ~PORT O~~ ~O~ · G~0SH ' 507332~ 1200S01 iiii ii ii i ..... .. ~: ~ Volume ~ 1~,375 Csg 16 Csg W~ :! Da~ ~ ~ ~je~ed P~ss .... ~s ~s G~0SH [~: ~/1/01 24 2634 23~ 7~ 250 G~0SH il 4/~01 24 3207 2300 640 259 O40SIt~"l::, 4/4/01 24 2774 2 I!0 670 260 G40SH l~i 4/5101 24 ..... i~'5 ' 2150 670 .... 257 ~om'~] ........... ~/~ol ............... :_~ 2~ .... .'. :~o ~ :~ .......... ..... ~os~ L:,] 4mo~ 24 2~3 2150 685 ....... 257 O~SH I! 4/~/01 24 3~'" ~ 6g0 25'7 '~6~ii-'[~ ...................... ~)~i61 -- 24 3291 2250 670 g58 ..... ~0SH [~ 4110101 24 3282 23~ 665 25d ................ ,,,,,.,,,,,,, .~ i ~ G~0SH ~t'J 4/11/01 24 3270 23~ ~ 256 ': ~1 ............................ ,, , ......... G~0SH :,' 4/13/01 lg.5 ~76 2075 6g0 .... 2~6 ,,,,, ,.,. G40SH i~ 4/14/01 ~ 24 33~ ~S0 68~ '" 258 G~0SH : 4/15/01 24 3471 23~ 6% .... 260 G40SH ?] 4/17/01 24 3270 23~ 665 ............ ~-~- ~ i i i ,~ , i ~osa ~:;' 4ft~o~ 24 326~ ~3oo 670 2~s' ........ 0SH [',. 4/19/01 ~ 3254 23~ 670 25'8 040SH [.) 4a0/01 ~ 3235 2300 670 ..... 258 .... ~OSlt ['~ 4121/0I 24 3228 23~ ~6-'-- 260 ~40SH [~ 4~/01 24 3217 23~ 650 ..... 258 C~0SH [~:j 4~3/01 24 3215 23~ 650 258 O~SH ~? 4124101 24 3213 23~ 650 ..... 260 ............... O~SH ~ 4a6101 24 3215 23~ 630 ...... 260 .,. ,.J O~OSH J~[ 4~7101 24 3217 23~ 630 260 °4osU ~j . 4a~/ot 24 3214 23~ 625 ................... ' -- ' .......... IIlII I I ~0SH ['~ 4/29/01 2n 3203 23~ 625 260 ,,,, You ~e ~ t~ 414 ~ d~ ~ite and ~is ~8e h~ ~ ~t 20 I~ since 10~7/~0. ' http://ko ,~ak.anchortownunocal. com/gurveillance~j ector_ VarianceReport. asp 5/1/2001 03/01/2001 00:$$ FAX 9077766635 UNOCAL GRAYLING .... q: ,. '!7'iii::':;';?':7~i:-0'~,~.~ Monthly Injection Report ...................... :':' ........................... ~ ................ . ........................ , ....... -'-' ........................... . ,._:,:c~ .................... ... ~.i:i~:. ..... .... ?t I~.~,~, ~...~"'"i' [~oo~ ~"~ ~ ~,~"" Or 2001 · : :. WATiERFLOOD INJECIOR MONTHLY REPORT GRAYI.I}jG PLATFORM · G-40SH . 507332041200SOl ell Date ....... hfs Volume Tbg i3,375 Cs~ I`6 On Injected Press Press Press 2/1/111 24 3371 2250 600 240 2/2/0 l 24 3372 2250 600 240 ................ , ............ 2~/01 24 3364 2250 600 2.40 2/4/01 24 3401 2250 600 240 ............. 2/5/01 24 3390 2200 S 90 244 216/0I 24 3398 2200 590 243 2/7101 24 3392 2200 585 2,13 2/8/01 24 3401 2200 585 244 2/9/01 24 3385 2200 585 24,1 2/10/01 24 3360 2200 575 244 2/11/~ [. 24 3009 2275 575 242 i 2.(~¢m 1 24 ,., 2794 2200 575 240 ~ 2/13/01 24 3134 .... 2250 770 ,~ ...... 2/14101 2:1 3414 2250 770 250 ": 2/t 5/01 24 3407 2300" -- 770 265 ~_.. 2/16/01 24 5-3~o 2306 ...... 770..... 270 '3 2f17/01 24 34 78 2300 770 270 ~ 2/z8/6~ 24 3563 2300 760 270 ~~;( 2119(01 24 3562 '-~300 " 750 270 ~: 2/20/0~ 24 3573 '"~"~}'~0 -"900 ~ 270 ;' 2/21/01 24 3025 2200 700 270 ,.. ~ 2~2[01 2~ 3061 ' 2300 700 270 ;. 2/23/01 24 31 O1 2300 680 270 :'::~' 2124/0i ' 24 3t02 2300 680 270 ,.:: ........ . ..................... ...... ,,,, ~,:, 2/25/01 24 3536 2300 650 266 :', 2/26/01 24 3241 2300 650 266 2/27/01 24 3627 2300 65 o 266 .~ 2128/01 24 3822 2.300 65(1 266 ~[..'. G-4t)SH~,i G.a0m ;i G-40SH ii:i: G40SH ,,, G-40SH G-40SIt ,,. ~]004/004 Page I of l You are numb~ 184 on flfi.u websitu and thi~ paff~ lu.~ been hit g tim~'a u~;~ 10/27'200~. ',,,?, ,,: h~p://kodika~su~eillanceA nj ector V~mceRep o a, asp 3/1/01 02/01/2001 00 51 F~ 9077766635 UNOCAL GRAYLING Monthly Injection Report ~002/004 Page I of 1 RECEIVED .._ _0.1.._.i ............ 2001 ~' --,---. ............................................... ~.... ...... ER_FLOOD INJECTOR MONTHLY REPORT YoB iG PLATFOKM : C-40SH: 50733204 I200S01 Volume Tbg Date Injected Press 1/I/01 0 600 1/2/01 0 600 1/3/0I 0 600 1/4/0I 0 600 115/01 0 5O0 1/6/01 786 2200 1/7/0I 3328 2200 1/8/01 3523 2050 1/9/01 3427 2050 1/10/01 3561 2100 1/11/01 3513 2100 1/12/0I 3397 2100 1/13/01 3389 2100 1/14/01 3371 2100 1/1 $/01 3369 21:50 1/16/01 3375 2I $0 II17/01 3354 2200 1/18/01 3346 2100 1/19/0 ! 3025 2100 1/20/01 3016 2075 1/21/01 3007 2100 1/22/01 29S8 2100 1/23/01 2963 2100 1/24/01 2816 2100 1/2:5/01 2869 2100 1/26/01 3176 2200 1/27/01 3294 2200 1/28/01 3390 2200 1/29/01 3392 2200 l/~0/0l 3381 2250 1/31/01 3374 2250 177 on this xveb~it~ and this pag~ has been hit 7 flm~ $i~¢e 10/27/2000, 13.375 Csg Press 685 685 685 685 400 400 670 750 660 635 635 635 635 635 660 650 640 620 620 615 600 600 600 610 610 610 6]0 610 600 600 600 16 Csg Press 235 235 235 235 240 240 240 250 248 248 248 248 248 248 246 245 244 244 244 242 240 240 24O 240 240 240 240 240 240 240 240 http://kod ak.anchortown,unocal, com/surveillance/Inj ector_VarianceReport, asp 211/01 01/01/2001 01213 FAX 9077766635 -- I]NOCAI, GRAYI,I NG I~ 004 / 00 4 Page ! of ! Monthly Injection 'Report [G-do..SH ..... WATE} FLOOD INJECTOR MONTHLY REPORT GILa,.YLll',IG }.' ,ATFORM' G-40SH- 507332041200S01 Iq/rs "' Volume Tbg 13.375 Csg 1'6 Csg Date On Injected Press Pres,~ Press "12/1/00 24 3842 ' 2350 " 550 '- 215 12/2/00 24 3817 2350 550 214 12/3/00 24 3899 2350 555 212 .... 12-~t00 "54 ....... 3'$5~1 -2-~50 "' 575 ..... 212 12/5/00 24 3891 2300 580 215 12/6/00 24 3886 2300 580 215 12/7/00 3 781 2300 580 215 12/8/00 12 2243 2300 680 220 1219/00 24 4125 2300 660 220 12/10/00 24 4449 2300 660 220 12/11/00 24 4759 2350 690 223 12/12/00 24 4.711 2350 680 223 12/13/00 24 3283 2250 680 228 12/14/00 24 3542 2250 680 228 12f15/00 24 409;~ .... 2200 665 216 12/16/00 24 4080 2200 665 2!6 '12/17/I){1 24 4077 2200 665 226 12}i'8/00 24 [ 4072 2200 ....... '6'g} ' 225 12/19/00 24 4032 2300 640 225 12t20/00-"'-~3.5 3109 2300 "' 640 225 12/~-'i/00 24 3'b55 '-2200 650 230 ,, 12/22/00 .......... _2_i!_ ..... 3670 2200 650 . 230 12/23/00 24 3686 2200 635 225 12124/00 24 3739 2200 630 225 .... !..2/25/00 f . ¢4. 3709 2200 630 t 225 ..... ! 1.2/26/00 22.5 3530 2150 625 __ 22'7 12/27/00 16,5 .... 2404 ..... 2150 625 i 227 __ ' ....................... 12/28/00 --'2'~ ....2;~'5~ 1900'' 660I 226 ~ 1~/29/00 9 123'~ ................ 1900 660 226 12/30/00 0 0 600 675 232 '12/31/00 24 0 600 685 237 Well G-40SH G-40SH G-40SIt G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-40SH G-408H G-40SH G-40SH G-40SH G-40SH ¢-40SH G40SH G-~0SH G-40SH G-40SH G-40SH G-40$H G-40SH G-40SH G-40SH G40SH You am us~r hUm'l: '.r 199 on fl,.;s webslt~ and t~,s page has been hit 6 times since 10/27/2000. http ://kodiak 'tnchortown. unocal, com/Surveillance/Inj ector_VadanceReport, asp l / 1/0 ! 12/01/200(I 02:10 FAX 9077766635 UNOCAl, GEAYI,ING ~ OO2/0O4 Page I or' 1 Report Name Injector!Data Chart Selected Tbg String G-40SH m i ! Selected Line X Axis Field Graph Style Date Created Time Period Size Last Month X Axis Field 3 Lines & Symbols 12/1/00 G-40SH Injector Data UNOCAL, Cook Inlet, Alaska 12/1/00 2600 4500 ... . ~?.,~, . uti __ ii i 4000 1500 I I o~ 0 ~z zz~zzzzzzzz~zz~ ~ Tbg Press e CsB Press A O~er Csg Press F csg Pressure ~ Outer osg Pressure r*' Hfs Orl http://ko d iak,';?,i!ii~nchort own. unocal, congd a/template s/graphic, asp 12/1/00 11/01/2000 02'41 FAX 9077766635 UNOCAL GRAYLING WATERI'!'iLOOD INJECTOR MONTHLY REPORT . Page 1 of 1 ~002/004 GRAYLING PL,,.i,TFORM ' O-40SH: 507332041200S01 }Irg .... {/olume Tbg /.3.375 c~'g' - 16 On Injected Press Press Press 10/1100 0 0 500 480 400 ' . 10/2100 24 0 500 480 190 10/3/00 24 0 520 470 200 l 0/4/00 24 0 510 460 198 1015/00 0 0 510 455 196 . 1016100 24 0 500 460 190 1017/00 9 1387 2200 470 202 1(~/-8'/00 24 4394 2300 .... 45~0 194."--.- --___ 1019/00 24 4393 2300 ,180 197 '" t0il0/00 24 4391 230'0 ..... 480 197 10/11/00 24 [332 2300 530 207 10112/00 24 4.382 2300 560 t98 -- 10/13/60-' 24 4376 2300 560 208 i0/14/00 ..... 24 4452 2200 '"580 .... 2~7 ~ . 10/15/00 24 4284 2300 540 198 l 0/l 6/00 24 4284 2250 530 205 ........ 10tl 7/00 22 3763 2250 515 203 " 10/18/00 24 3'~09 22(~0 :550 '~' 205 10tl 9/00 24 3842 2200 545 205 ' 10/20/00 " 24 3896 ' 2250 .... ~35 .... 2---~{ ........... IO/2UO0 .... 24 387~ ...... ';~'~'~0 530 208 ........ 10/22/00 24 3816 2250 520 208 10/23/00 24 4031 2250 530 210 10t24/00 23,5 379.t 2250 530 210 .... 10/25i00 ~'24 ~ ~861 ........ 2250 " 5--~- 210 ....... -i0)26100 -- 24 3898 .... 2306 ...... 540 210 ......... -- 10t27/00 24 3879 2300 540 210 ~ ,, 10/28/00 24 3860 2300 540 210 '" 10729/00 24 4010 '"2~00 ....... 540 ...... 210 ..... 10/3'~71~0 24 3847 2300 540 -- 2ll tor3~too 24 3965 23~0 540 203 Well G-40SH G-t0SH 'G40SH ~G.-408H G-40SH G-40S[--I O-40SH G-40SH G-40SH G-40SH G-40SH O-40SH G-40SH G-40SH G-4OSH G-40SH ...... ........ O-40SH G40SH ' -... G,40SH ..... ~4OSH G-408H You are tu~r numbi.i::rl', 2711 on thi, web*itc and this pago tins b~.~n bit 12 limes ~i:tcm 10:'27/20110. ,"ii http://kodiak.~.(inchortown.unocal.com/Surveillance/Injector_VadanceReport.asp 11/1/00 09/01/2000 06 1l FAX 9077766635 UNOCAl, GRAYI,I NG It-U-iiOCALe [~.] oo I/oo4 -- Page 1 of 1 Monthly Injection Report WA] iERFLOOD INJECTOR MONTHLY REPORT GRAYLI;tiO PLATFORM' TBU G-40SH · 507332041200S01 Return to Main menu 9/1/00 i' Hrs' VolUme Tbg" 13.375 C'sg 16'"Csg Well Date On Injected Pres,~ Press Press . 'I~BU G~SH 8/l/0(~ 24 4342 2300 530 24 TBU 0.~]}SH 8/2/00 24 4275 2300 530 "' 205 TBU ~-4t~,)SH ' ..~ . ' , . 8/3/00 ~4 ~i'270 2300 520 ~)6 '- TBU G-~}!iSH 8/4/00 24 4265 2300' ' 500 '" 207 TBU 0~ sH 8/5/00 24 4268 '-- 2300 5'6'0 ..... 205 TBU G-~ SH 8/6/00 24 4263 2300 490 .... TBU G-4:i}~H 8~7/'00 24 3827 ' ' 2300 480 .... 20[~ TBUO4 EH 8/8~°0 24 ....361~i- 2300 4'~0 209 TBU G4 SH 8/9/00 24 3608 2300 470 -' ']~0--~ TBUOqi SH 81101'00 " 24-'" 3599 2300 460' 2(.)8 IBt3(}~ SH "2/11/~)0 ~4'-- 359~'- - 2300 450 209 :TBU G4i St{ _. 8/12-/00 ' ' 2_? 3589 23¢0 - 450 209 8/13/00 24 3579 2300 445 20-~-' - .TBU G-4[': Sift ............. ]TBU (.;4~ SH 8/14/00 13 "i008 2300 445 .... 2~09-- TBU O-4i! SH 8115/00. 24 34il 2300 56t) 200 TBU O-4i ~H "' 8/16/00 24" 3402' 2300 ..... 560 200 w3v o-4~k-h 8/17/b0 .... 24 .... 3392 2300 460 ..... 200 --' IBU O-4--~,.' .~I-I .... 8/18/00 i~ ~ 3387--' 2300 455 ....... 7}1 - TB0 G~4~i ¢H 8/I 9/00 24 _ 3388 ,,.2B0 455 :~00 ..... TBU G4, .[..'..' gH 8/20/00 24 3389 2300 455 200 !:tm: c;.-4,:~ ;~-r 8/21/00 24 ~' 3394-" 2300 4'70 - 210 L T~U ~'-4,0'i riI'I ..... 8/2 ~-/~)0 24 3708 220-~) 425 ' 2'10 ~ ~r-'~'4~'..{, Hi 8/23/00.1,, 2]4- 3928 230i1 460 2i0 [TBU'G]4t~i., iH ' 8/24/00 24 3925 2306 430 .... 210 ...... ~ ¢ ............ ~ ............... [TBU G-401 II-t 8/25/00 24 3926 230'~" 405' 210 TBU O]4~, IH 8/26/00 24 3922 2300 I ' 400 2'10 TBU (}-4~ II-I 8/27/00 24 3898 2300 ' " 400 210 TBU G'4~ H 8/2~/00 24 3'86'3 23})0 365 TBi)-~? ._ 8129100 23i ....... ~879 2300 350 --21"-3-4 TBU G-4Q!fH 8/30/00 24 3878 2300 400 208 'I~UO-4OJ~H 8/3'1166,, ~ , , "24 ] 3886 '2300 - 410 " 208 You are user ,~2 (tuber i858 on this webs/to and this pago has been hit 87 times since 7/1412000 8:2'3 AM. 06/01/2000 05:46 FAX 9077766635 UNOCAl, GRAYI,ING 002/003 UNOCAL OIL & GAS GRAYLING PLATFORM G40 Injector May.2000 511/00 2300 490 192 4644 · , 512/00 2300 480 192 4641 ,,, 5/3/00 2300 480 192 4630 . . 514/00 2300 480 192 4625 ,,, 5/5/00 2300 470 190 4559 5/6/Q0 2300 470 190 4556 5/7/00 2300 450 190 4539 518100 2300 450 190 4534 ....... 5/9/00 2300 450 190 4517 5110i00 2300 450 190 3316 Vacuum tower problems 5/11/00 2225 540 195 2683 !Vacuum tower problems 5/12/00 2200 510 195 4282 # 5 Sand filter ,, , 5113100 2200 500 195 4282 # 5 Sand filter 5/14/00 2200 490 195 4271 5/15/00 2300 480 192 4249 5/16/00 2300i 480 192 3816 Bing. Down 2.5 HR, to R&R pfpe spool .... 5I 17~00 2250I. 490 192 4313 5/18/00 2250~ 475 194 4301 5/19/00 2250, 475 193 4317 5/20/00 2250 450 192 4319 5/21/00 2250 450 192 4310 .... 5/22-J00 2250 480 195 4290 5/23/00 2250 480J 195 4263 5/24/00 2250 425, 194 4241 5/25/00 2250 425 194 4235 5/26~00 2250 425 194 4217 5/27/00 2300 420 194 42-02 5/28/00 2300 420 194 4179 5/29100 2300 420 194 4173~ 5130/00 2300 420 195 4167 5/31/00 2250 420 196 4162; , ,,,, , 05/01/2000 00'47 FAX. 9077766635 UNOCAL GRAYLING [~ 003/003 UNOCAL OIL & GAS GRAYLING PLATFORM G40 Injector Apr.2000 4./0o moo 4~0 190 45~e 4/2J00.. , 2~00 410 190 372~. daylight saving time 23hrs. 4~3~00 2300 440 192 4484 414/00 2300 420 190 4460 4/6(~.0_.._ 2800 420 190 1004 8ingham down for repairs 17.5Hrs 4/6/00 2300 510 190 3729 4/7/00 2300 510 190 3308 Bingham dovm for repairs 1,5Hfs 4/8100 2,300 510 190 4495 4t9/00 2300: 480 1:95 4518 4/10100 2300 460 195 4508 ,, 4/11100 2~00 450 195 4469 4112/00 2300 445 195 4408 4113/00 2300 450 195 4495 4/14f00 2300 440 195 4513 4/15~00 2300 440 195 4638 4/I 6/00 2300 440 195 4634 4117100 2300 440: , ,192 4596 4/18/00 2300 z130', 192 4586 4/19/00 2300 4301 194 4603 4120100 _i 2300 460 192 4505 S/I 1 HR. 4121t00 2~00 450 19[:) 4675 4/22/00 2300 460 192 4581 4~23~00 2300 450' 193 4571 4/24/00 250,0 .......... 450 195 4668 4/25/00 2300 450 192 465: 4126100 2300 420 193 4684 4127100 2300 460 195 4638 4/28/00 2300 520 193 4666 4/29/00 2~300 500 193 4663 4/30/00 2300 490 193 4628 5 !VED 2000 UHOCAL GRAYLIFtG PLAT ,l FIO. 988 P. 2 UNOCAL OIL & GAS GRAYLING PLATFORM G40 Injector Mar.2000 311/00 2300 450 190 4498 ~2f00 2300 450 190 4482 ..... _3/3/00 2300 450 190 4474 ............ 3/4/00 2300 450 , 190 3182 Bingham down 8hrs. Elect. Malfunction 3/5t00 2300 450 190 4619 , , , 316100 2300 450 190 4605 ,,, , ,, __317100 2300 450 190 4605 ,, ..... 3/8/00 2300 450 187 460' .......... ~,, 3/9/00 2300 450 187 4575 3/10/00 2300 450 190 4596 .. 3/11/00 2300 450 185 4557 3/12/00 2300 450 190 4607 , , , , : . 3/1 3/00 2300 450 '194 4608 3/14/00 2300 500 195 4593 . _ 3/15/00 2300 475 192 4548 , 3/16/00 2300 460 192 4529 .......... 3/17/00 2300 ...... 450 195. ..... 4527 ,,, 3118100 2300 440 195 4'569 3/19/00 2300 440 195 4580 3~20~00 2300 .... 440 195 ...... 4542 ' ,3/21100 ,,, 2300 43,0' ,, 195 4547 3/22/00 2300 430 195 4517 3!23/00 ,., 2300 , 410 .....195 4494 3/24/0Q 2300 ............410 195 4477 3/25/00 2300 , ,42,0 195' 4526 , ,, .3!26!00 ........ 2300 420 195 ..... 4572 3127100 2300 420 195 4559 3128/00 2300 420 190 4571 , , 3/29/00 2300 460 190 4510 3/30/00 2300 ..... 440 190 4552 · 3/31/00 .... 2300, 420 190 4532 - ,, . REC APR i Alasl(a Oil & Gas EIVED 0 J ; 000 Cons. MAR. 1.2000 z~: BSAM UNOCAL OIL & GAS GRAYLING PLATFORM G40 Injector F~b,2000 470 19 O 4,907 100 5212 46O 190 5262 45O 190 5219 ~ 190 5258 460 190 5075 4~ 190 5162 460 450 190 5189 190 5247 190 5032 t90 4827 190 4623 410 190 430 190 4499 4SO 190 4468 450 190 422.2 560 190 560 ~90 ~70 5Ol,3 4990 4762 450 190 4668 445 ~eO 4614 445 190 4571 460 390 4567 460 ~ 90' 450 4,..~05 190 4462 #5s/f MO. 095 P. Unocal Corporation Agricultural Products 909 West 9'h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) 9/20/99 Blair Wondzel State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Request variance for injection into Grayling Platform Well #G-40 Dear Blair: This letter is to document your approval to put G-40 on injection with a variance. G-40 has communication between the tubing and the 9 5/8" casing. A jug test was attempted on 11/20/98 with inconclusive results. However, the results of two temperature surveys, one ran on 7/20/99 after a 18 month shut-in time (following years of injection) and the second one ran on 8/5/99 after a 12 hr shut-in time (following 7 days of injection), depict no injection water exiting the wellbore above the packer. It is Unocal's opinion the well can be operated safely with no risk to shallow fresh water aquifers or gas zones due to casing integrity and the direction of the wellbore. Please grant us permission to continue injection into this well under the assumption that we will monitor the various annuli daily and report this data monthly, and we will run a temp survey every two years for comparison with the base survey which was submitted on 9/14/98. Attached is a 10-403 for your approval. If you have any questions regarding this, please contact myself at 263-7830 or Steve Tyler at 263-7649. Senior Reservoir Engineer Cook Inlet Waterflood Management Attached: 10-403 requesting variance Temp survey results Simplified overview of temp survey procedures Well-bore diagram Map showing directional path and extent of GGS accumulation Aogcc Grayling G-40 Variance 9-20-99.doc 9/18/99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request Abandon: __ Suspend: Operation shutdown Re-enter suspended well Alter casing: Repair well Plugging: Time extension Stimulate: Change approved prograrr Pull tubing: Variance: X Perforate: Other: 2. Name of Operate UNOCAL 3. Address P.O. Box 196247 Anchorage, AK 99519 - 6247 5. Type of well Development X Exploratory Stratigraphic: Service: 4. Location of well at surface Leg #1, Conductor#25, 1900' NSL & 1459' WEL f/ SE corner, Sec. 29, T9N, R13W, s.rv At top of productive interv~ Top of Hemlock-9887' MD, 663' SNL & 2417' WEL f/SE corner, Sec. 32, T9N, R13W, s.rv At effective deptt' At total deptl' 11,267' MD, 1155' SNL & 2653' WEL f/SE corner, Sec. 32, T9N, R13W, S.M 6. Datum elevation (DF or KB 103' RT above MLLW feel 7. Unit or Property nam( Trading Bay Unit 8. Well number G-40 9. Permit numbe~ 90-3 10. APl numbe~ 50-733-20412-0C 11. Field/Poe McAurthur R~l~rl~ I~r~l;I~ ~ ~"~ Forland 12. Present well condition summer Total depth: measured 11,267' feel truevertica 10,638' feel Plugs (measured~, Effective depth: measured 11,143' feel Junk (measured~, truevertica 10,499' feel Casing Length Size Cementec Structural 421' 20" Driven Conducto~ 1,926' 16" 3,400 sx Surface 5,128' 13 3/8" 4,950 sx Intermediate Production 11,232' 9 5/8" 2,710 sx Liner Perforation depth measured See Attchment true vertioa t99,9 .Alaska 0il & 6as Cons. C0rnmi, ssi0t', Anchorage Measu red deptl' /rue vertical dept~ 421' 421' 1,926' 1,926' 5,128' 4,973' 11,232' 10,606' ORIGINAL Tubing (size, grade, and measured depth LS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl Clr Cplg w/TK-99 Internal Coating @ 10,46: SS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl Clr Cplg w/TK-99 Internal Coating @ 9,82' Packers and SSSV (type and measured deptl' Otis "RDH" Dual Pkr @ 9796' Otis "BWH" Perm Pkr @ 10,382' DPM (10,375' DIL'. 13. Attachement., Description summa ry of proposal..~ Detailed operations prog rarr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve( Oil: Gas: Suspended: Name of approve Date approve( Service: Water Injection 17' I hereby ceF~~~e and c°rrect t° the best °f mY kn°wlcd! '"' '~ ~¢r~,~ ~/ Signed: ~....,~, ~,. ,' -v Title: ~¢'~'l//-~f"~YtY ./' ~-LC~'"Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneplug ,ntegrit~ BOP Test Location clearanc~ / Mechanical Integrity Tes Subsequent form required~ 10 ~~('~'\~1, ~'"'°~'~lC3~"t ~"(;~O~"t Robe~ N Chdstenson ~ ~proved by order of the Commi~ion6 ' Commissioner Date Temperature surveys ran on 7/20/99 (after a 18 month SI) and on 8/5/99 (following 7 days of inj w/12 hr SI) depict no injection water exiting the wellbore above the packer. Unocal requests permission to continue injection into this well. We will monitor the various annuli daily & report this data monthly, we will run a temp survey every two years for comparison with the base survey which was submitted on 9/14/98. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL September 24, 1999 Blair Wondzel State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Trading Bay Field GRAYLING G-40 Temperature Survey Procedure Dear Blair: The following procedure was utilized in running the temperature surveys on G-40. G-40 had been on injection for 8 years prior to being Shut-In on 1/98 due to MIT failure and tbg/csg communication. · A Gage Ring run was made to tag fill. · The Temperature Survey tool was run @ 60 fpm, data points were set to record every second. · The well was then placed on injection for 7 days. · After a 12 hr shut-in period, a Temperature Survey tool was run @ 60 fpm, data points were set to record every second. Sincerely, Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management Aogcc Grayling G-40 Temp procedure.doc 9/24/99 RKB to TBG Hngr = 40.8' Tree connection: Dual 3" $,000# RT to MLLW ELEV = '103' TD = 11,267' ETD = 11,143' MAX HOLE ANGLE = 27 2 @ 8900' CASING AND TUBING DETAIl. Tubing: SS 3-i/2" 75 68 47 47 47 47 47 9.2 9.2 Trading Bay Unit Well # Completed 4/26/98 NO, K-S5 BuU 8.681 Sari 47' N-80 Butt 2.992 0' 10,463' 9870' N-gO Butt 2,992 0' 9827' 9290' JEWELRY DETAIL ID item 2.90 9-5/8" Otis "RDII' Dual Packer. SS set 9796' 9g13~ 9825' b~m 9827' 9762 9798' SLICKIANE TAGS SS Tag "XN' w/2.72' GR 8/5/97 (~) 9813' LS Tagged obstrnction w/2.72" GR & 2.72" LIB 8/6/97 O~ 5,812' Tag fill w/2.25" LlB 8/7/97 (~ 11,086' W[RELINE WORK LS * Spilmer ran on 1/22/98 indicates tbg leaks O 9812' & 10,125' · WFL ran on 1/23/98 indicates csg leak between 3250' & 3350L · WFL indicated multiple SS tbg leaks, sldg sire (¢ 976lP~ tbg jt between sldg sh,e & pM' and between 1200~ to 3400L STIMULATIONS 2 stag ac~d j~gb w/diverter, 50 bbls of FICL & 75 bbls of 3/29/90 West Forlat~d 64/2% X 1-1/2" mud acid 2 stag acid job~ 41) bbls of HCL & t35 bbls of 6-1/2% X t-112" 3/29/90 HB-1 & 2 mud acid PERFORATION DATA Btm ' Amt G-40SchiD4~26-90,doc REVISED: 2/2/98 DRAWN BY: SLT Grayling G-40 Comparison Tamp survey 18 month S~ 7/20,99 vs 7 day inj w112 hr~ S~ 8/5/99 30 40 50 60 70 80 90 100 110 120 130 140 150 160 I70 ~7/2o/99 Ta ~p Survey ~8/5/99 Tamp Survay UNOCAL~ JUN-29-98 MON 13:41 UMOOAL ~SS~T G~S GRP NO, 9072637874 P, 01/01 Unocal Corporation 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29,1998 Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocai's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our March 27, 1998 letter which you signed granting time extensions for various wells. Testing, or work was completed on the following wells and the results of this work is listed: Anna 46-42 · SI MIT approved on 4/17/98. King 4RD : SI MIT approved on 4/17/98, King 15RD : SI MIT approved on 4/17/98. Dolly D- 16RD : SI MIT approved on 4/17/98. Dolly D-22 : SI MIT approved on 4/17/98. Grayling 22 : Workover completed on 4/19/98. Grayling 36DPN : Workover completed on 4/28/98. Monopod A-12RD2 : SI MIT approved on 6/03/98. Monopod A-29 : SI MIT approved on 6/03/98. Baker 9 : SI MIT approved on workover scheduled. Jug test proved communication, workover scheduled. 6/03/98, planning acid treatment to clean tubing for lesting, King 22RD : Variance granted on 6/09/98, Jug test proved casing integrity. Anna 27-42 :Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove easing integrity, Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrill in progress. Testing or work was attempted on the following shut-in wells and a time extension until Septembe. r 30,. 1998. is requested to complete further work and testing, Anna 19-42' Coil Tubing clean out completed on 6/27/98, furtl~er testing scheduled to prove casing integrity. · els Anna 27-42: Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. o--t Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. ~.Grayling 40' Workover schedule in current rig schedule. -:t3-a4z. King 4RD · SI MIT granted on 4/17/98, workover soheduled. t~%~[ King 15RD · SI MIT granted on 4/17/98. Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal respectfully requests a time-extension until September 30, 1998 to complete the work on the above listed Anna wells, The Grayling and King work will be executed per our current drilling schedule. Please call me if you have any questions or clarification on these issues. Cook Inlet Waterflood Management Wendy"'l~Iahan AOGCC Please acknowledge the approval of the time extension and your receipt of this letter by faxinff back a signed c, nll.¥ of this letter to Christopher Ruff at 263-7874 (fax). ~CG ~-----~ V ~ ' JUN 2 9 1998 STATE OF ALASKA '( ALASKA ,_ AND GAS CONSERVATION C ,MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 103' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 1459' FEL & 1900' FSL of Sec. 29, T9N, R13W, SEWARD Grayling G-40 At top of productive interval- Top of Hemlock @ 9887' MD 9. Permit number 2417' FEL & 663' FNL of Sec. 32, T9N, R13W, SEWARD 90-3 At effective depth (11,143' MD) 10. APl number 2636' FEL & 1114' FNL of Sec.32, T9N, R13W, SEWARD 50- 733-20412-00 At total depth 11. Field/Pool 2653' FEL & 1155' FNL of Sec.32, T9N, R13W, SEWARD McArthur River/Hemlock& W. Forelands 12. Present well condition summary Total depth: measured 11,267' feet Plugs (measured) true vertical 10,611' feetORIGINAL Effective depth: measured 11,143' feet Junk (measured) true vertical 10,499' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 391' 20" Grouted 340 sx 421' 406' Surface 1896' 16" 2100 sx 1926' 1926' Intermediate 5098' 13-3/8" 4950 sx 5128' 4973' Production 11,202' 9-5/8" 2710 sx 11,232' 10,579' Liner .' ...... Perforation depth: measured 9892'-11,040' See Attached :' ':' ;?~'"' true vertical 9345'-10,400' Tubing (size, grade, and measured depth) Long String - 3-1/2", 9.2#, N-80 @ 10,463' """ ''J' Short String - 3-1/2", 9.2#, N-80 @ 9827' .,.; Packers and SSSV (type and measured depth) Otis 9-5/8" RDH dual pkr @ 9796' ;::~:g,,¢¢,,,;~ .~.,~, ~.~ Otis 9-5/8" BWH packer @ 10,382' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 8/1/98 16. If proposal well verbally approved: Oil: Gas: Suspended: , , Name of approver Date approved Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ¢J~ ~ ¢~1 c~,,~ Dale Haines Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission.. so representative may witness IAppro~.~N¢~ Plug integrity.._~ .' B~.OP Test ~,~ Location clearance '- Mechanical Integrity Test~ Subsequent form required 10- /,4 ~ .0o¢ xo~e6 ~^ Original Signed David W. Johnston Approved by order of the Commissioner Commissioner UNOCAL ) Grayling Well', -40 Rig Workover Workover Procedure Objective: The objective of the workover on G-40 is to repair tubing leaks so this well can pass a MIT and return to injection. In addition, G-zone perforations will be added during the workover The well is currently a shut-in water injector dually completed in the Hemlock and West Forelands formations. The proposed workover will remove the dual tubing strings. A lower single packer between the Hemlock and West Forelands will be left in place during the workover. A test packer will be run to evaluate the integrity of the 9-5/8" casing. If any leaks are found, repair options will be evaluated and performed as needed. The G-zone will be perforated with tubing conveyed guns during the workover. The well will be completed with a new single packer and 4-1/2" injection tubing. Reservoir Pressure and Workover Fluid Density: Expected reservoir pressure is 4680 psi at 9892' MD/9345' TVD. Workover fluid will be 9.8 ppg brine. Workover Procedure: 1. Pump kill weight brine down both tubing strings and circulate kill weight brine in annulus. Check dual tubing strings and annulus for pressure. Ensure annulus is full of liquid. 2. Install dual back pressure valves. ND tree. 3. NU BOPE, pull BPV and install 2-way checks. Test BOPE with 24 hr notice given to AOGCC for witness. 4. Pull 2-way check valves. Remove short tubing string, long tubing string and dual packer at 9796'. 5. RIH with 9-5/8" test packer and bridge plug. Test integrity of 9-5/8" casing above 9280'. Repair casing as necessary. 6. Fish remaining long string down to single packer at 10,382'. 7. Perforate G-zone with TCP guns: G-1 9403'-9425' G-2 9440'-9468' G-3 9516'-9550' G-4 9563'-9620' G-5 9690'-9750' 8. Run 4-1/2" completion with permanent injection packer at 9280' MD/8790' TVD. 9. Set BPV, ND BOPE. NU tree, test annulus to 2200 psi with AOGCC witness for injection well MIT. 10. Release rig. Start water injection. Tim Billingsley, Unocal Drilling Engineer 263-7659 AOGCCproG40.DOC 6/25/98 UNOCAL ) Trading Bay Unit Well # G-40 Completed 4/26/90 RKB to TBG Hngr = 40.8' Tree connection: Dual 3" 5,000~ SIZE 16" 13-3/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" Tubing: LS 3-1/2" SS 3-I/2" 75 68 47 47 47 47 47 9.2 9.2 CASING AND TUBING DETAIL MD MD TVD GRADE CONN ID TOP BTM. BTM K-55 Butt 15.124 Surf. 1926' S-80 & K-55 Butt 12.415 Surf. 5128' K-55 Butt 8.681 Surf 47' N-80 Butt 8.681 47' 9765' 9220' S-95 Butt 8.681 9765' 10,929' 10,300' N-80 Butt 8.681 10,929 11,146' 10,500 ' S-95 Butt 8.681 11,146' 11,232' 10,606' N-80. IPC Butt 2.992 0' 10,463' 9870' N-80, IPC Butt 2.992 0' 9827' 9290' n SS @ sldg stv (o B 2 2.72" LIB ran on 8/6/97 shows tbg to be oblonged 2.72" 2.68" ~ 5,012' T=g leaks 9012' & 10,125' B-1 B-4 7 WF-2 =_ WF-3 = WF-5 __= WE-6 -- WF-7 'i--: ?"-~--?-'"?':F:~' ?::~i:~ : ~ i ::ii:. !i i :,' ':. i~'i' '::" ¥':'ii:'i) ill ir'? ~ RT to MLLW ELEV [] 103' TD = 11,267' ETD = 11,143' MAX HOLE ANGLE = 27.20 @ 8900' G-40schAOGCC.doc JEWELRY DETAIL ID Item NO. Del~th . 40.80' Cameron DCB Dual 3-1/2" Tubing hanger. SHORT STRING A 9760' 2.75 3-1/2" Otis "XA" Sliding Sleeve B 9796' 2.90 9-5/8" Otis "RDH" Dual Packer, SS set C 9813' 2.635 3-1/2" Otis "XN" Nipple, 2.75 D 9825' 2.99 Bali Catcher Sub btm 9827' LONG STRING 1 9762' 2.75 3-1/2" Otis "XA" Sliding Sleeve 2 9798' 2.90 9-5/8" Otis "RHD" Dual Packer 3 10,348' 2.75 3-1/2" Otis "XA" Sliding Sleeve 4 10,385' 2.95 Otis Straight Slot Locator w/8.8' of seals 5 DP MD 10,382' 4.00 Otis "BWH" Perm Pkr (10,375' DIL) 6 DP MD 10,386' 4.00 Otis Seal Bore Ext. btm 10,395' 7 10,428 2.75 3-I/2" Otis "X" Nipple (stab thru packer) 8 10,462' 2.95 WLEG btm 10,463' SLICKLINE TAGS SS Tag "XN" w/2.72" GR 8/5/97 ~ 9813' LS Tagged obstruction w/2.72" GR & 2.72" LIB 8/6/97 ~ 5,012' Tag fill w/2.25" LIB 8/7/97 ~ 11,086' WIRELINE WORK LS * Spinner ran on 1/22/98 indicates tbg leaks ~ 9812' & 10,125' · WFL ran on 1/23/98 indicates csg leak between 3250' & 3350'. · WFL indicated multiple SS tbg leaks, sldg slve ~ 9760', tbg jt between sldg slve & pkr and between 1200' to 3400'. STIMULATIONS 2 stag acid job w/diverter, 50 bbls of HCL & 75 bbls of 3/29/90 West Forland 6-1/2% X 1-1/2" mud acid 2 stag acid job, 40 bbls of HCL & 135 bbls of 6-1/2% X 1-1/2" 3/29/90 HB-1 & 2 m;;~ PERFORATION DATA Zone Top 9,880' 9,934' 10,111' B-4 10,128' 10,218' 10,455' WF-2 10,525' I WF'3/ 10,680' I WF-5[ 10,833' I WF .6/ 10,915' IWF'7/ t0,993' 11,042' Btm 9,882' 9,926' 9,936' 10,113' 10,208' 10,220' 10,457' 10,565' t0,770' 10,888' 10,972' 1 t ,040' 11,044' Accum. I Amt I SPF 2' 4 2' 4 ' I 2' 4 40' I 8 90' I 8 55' I 8 57' 8 47' I 8 2' I 4 Date Last Opr. 3~2o~9o 3/28/90 3/19/90 3/18/90 3/28/90 3/18/90 3/t7/90 3~25~90 3~25~90 3/25/90 3~25~9o 3/25190 3/17/90 Present Condition Cmt Sqz Open f/Injection Cmt Sqz Cmt Sqz Open f/Injection Cmt Sqz Cmt Sqz Open f/Injection Open f/Injection Open f/Injection Open fl Injection Open f/Injection Cmt Sqz KEVI:SP_.;D! DRAWN BY: TAB UNOCAL ) RKB to TBG Hngr = 40.8' Tree connection: 4" 5,000~ G 1-G-5 Proposed RT to MLLW ELEV = 103' = B-1 _E B-4 6 _~ WF-2 -- WF-3 --__ WF-5 _= WF-6 -- -- WF-7 TD = 11,267' ETD = 11,143' MAX HOLE ANGLE = 27.2 @ 8900' SIZE 16" 13-3/8' 9-5/8" 9-5/8" 9-5/8" 9-5/8" 9-5/8" Tubing: 4-1/2" Trading Bay Unit Well # G-40 Proposed Workover 8/98 CASING AND TUBING DETAIL MD MD TVD GRADE CONN ID TOP BTM. BTM 75 68 47 47 47 47 47 K-55 Butt 15.124 Surf. 1926' S-80 & K-55 Butt 12.415 Surf. 5128' K-55 Butt 8.681 Surf 47' N-80 Butt 8.681 47' 9765' S-95 Butt 8.681 9765' 10,929' N-80 Butt 8.681 10,929 11,146' S-95 Butt 8.681 11,146' 1 !,232' 9220' 10,300' 10,500' 10,606' 912.6 L-80 Butt Mod 3.958 0' 9350' 8852' NO~ Depth 40.80' 9350' 1 9280' 2 9310' 3 9350' JEWELRY DETAIL ID Item Cameron DCB Dual 3-I/2" Tubing hanger. SINGLE TUBING STRING 3.958 4-1/2" 12.6#, L-80, butt mod tubing 4.75" Perm Packer w/tubing anchor 3.813" 4-I/2" X nipple, 3.813" profile 3.958" 4-1/2" WLEG 6 DP MD 10,382' 7 DP MD 10,386' btm 10,395' 4.00 Otis "BWH" Perm Pkr (10,375' DIL) 4.00 Otis Seal Bore Ext. SLICKLINE TAGS Tag fill w/2.25" LIB STIMULATIONS 2 stag acid job w/diverter, 50 bbls of HCL & 75 bbls of 6-1/2% X 1-1/2" mud acid 2 stag acid job, 40 bbls ofHCL & 135 bbls of 6-1/2°,4, X 1-1/2" mud acid 8/7/97 ~ 1 1,086' 3/29/90 West Forland 3/29/90 HB-1 & 2 Zone G-1 G-2 G-3 G-4 G-5 B-1 I WF-2 I WF-3 I WF-5 I WF-6 IWF-7 Top 9403' 9440' 9516' 9563' 9690' Btm 9425' 9468' 9550' 9620' 9750' PERFORATION DATA i Accum. Amt SPF 22' t~ 28' ~ :34' 57' 60' 2' 34' 2' 2' 80' 2' 2' 40' 90' 55' 5'/' 47' 2' 9,880' 9,892' 9,934' 10,111' t0,128' 10,218' t 0,455' t 0,525" t0,680' 10,833' 10,915' 10,993' t 1,042' 9,882' 9,926' 9,936' 10,113' 10,208' 10,220' 10,457' 10,565' t0,770' 10,888' 10,972' 11,040' 11,044' Date Last Opr. 3/20~90 3/28/90 3/19/90 3/t8/90 3/28/90 3/18/90 3/17/90 3/25/90 3/25/90 3/25/90 3125/90 3/25/90 3/17/90 Present Condition Proposed TCP Proposed TCP Proposed TCP Proposed TCP Proposed TCP Cmt Sqz Open fl Injection Cmt Sqz ICmt Sqz Open f/Injection Cmt Sqz Cmt Sqz Open f/Injection Open f/Injection Open fl Injection Open f/Injection Open f/Injection Cmt Sqz G-40propschAOGCC.doc REVISED: 06/24/98 DRAWN BY: TAB '}OR 23'-9":~ DRIP PAN AIR 5'-8':1: Ir 6'm RISER 1, HYORIL ,~NNULUR PR~NTI~R I I SHAFFER 0OUBLt gATE' 8OP BOOT ~]OTTOM OF' ~-~'AL HOUCJING1 / 4'-I0~'+ CELLAR FLOOR ' 0RIU.. DECK ) .... .. ~JF NTS 1/30/98 ALASKA 98002 GRAYLING PLATFORPl SHAFFER BLOW OUT PREVENTER STACK ELEVATION UNOCALI~ ~-~-o33 COOK INLET, GRAYLING PLATFORM MIXIN~ PIT 40 HI3LS i MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM TRIP 4-5 TANK BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS 67 BBLS DESILTER 24-0 BBLS SHAKER RESERVE PIT SI-IAi<ER tc£NTRIFUCE:I 4-75 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLINO PIT LEVEL INDICATOR WITH AUDIO &:: VISUAL WARNINQ DEVICES. EQUIPMENT LISI' 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VJSLIAL &:: AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK '7) PIT AClTATORS a) DESILTER 9) CENTRIFUCE 10) MIXING PIT UNOCAL GRAYLING MUD PIT SCIJEMATiC DRAWN 13Y: DAC APP'D: CSEI SCALE: NONE DATE: 11-30-89 TO OE~RICK VENT · TO WElL CLEAN TANX ~_ ~/~,,.LLil ' 3-'~/,~,. - Is" : ~,_ 3- TO ~ATI C A UT0 ~AT[ C CHOKE CHOKE FROM CHOKE LINE VALVES UPSTR~M OF' CHOKES ARE 10,000 PSt CATE TYPE VALVES 00WNSTR~ OF' CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD ORA'fl..ING PLAT'F'OR t'vf UNION OIL COMPANY 0F CALIFORNIA (dba UNOCAL) ORAWN: OAC APP'O: GS8 SCALE: NONE OAT'E: 1 '~/:z~l~ MAR-27-98 FRI 13:52 UNOCAL ASSET GAS GRP FAX NO. -,, P, 01/01 Unocal Corporation 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL March 27,1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our .[anua.qF 23, 1998 letter which Blair signed granting time extensions for,~'arious wells. Testing or ~vork was completed on the follo~.'ng wells and the results of this work is listed: Anna. 29-42: Well head inspection completed (no leaks), Variance granted on 3/3/98. Baker 4: MIT passed on 2/15/98 by Lou Grimaldi Bruce 31-42: Coil Tubing operation completed to repair leaking camera plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/17/98, MIT completed on 12/15/97. Grayling 16: Workover completed on 3/26/98. MIT Passed. Monopod A-SRD2: MIT passed on 1/28/98 by Lou Gfimaldi Tcsting.0r work was attempted on the following, shutqn wells .tad a time extensign3lx3tfl J..une 30, 1998 is recluested to complete further work and testing, Anna 19-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 27.42: Scale eleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 4642: Tamp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MIT attempted on 2/15/98, further wireline testing scheduled to prove casing integrity. Monopod A-12RD2: SI MIT attempted, Tamp Survey scheduled to prove no flow. Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : WFL indicates possible casing leak, well shut.in, further testing and workover scheduled. King 15RD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : Workover/Redrill scheduled in current drilling schedule. Grayling 22 : Workover/Redrill scheduled in current drilling schedule. Grayling 28 : Workover/Redfill scheduled in current drilling schedule. Grayling 36DPN : Workover/Redfill scheduled in current drilling schedule. Grayling 40 : Workover/Redfill scheduled in current drilling schedule. Unocal respectfully requests a time-extension until June 30, 1998 to complete the work on the above listed Anna, Baker and Monopod wells. The Grayling and King work will be executed per our current drilling schedule. !?lease call me if you have any questions or clarification on these issues. R Senior Reservoir Engineer Cook Inlet Wateffiood Mana~ Anchorage Please acknowledge the approval of the time extension and >'our receipt of this letter by faxing back a signed copy of this letter to Cttristopher Ruff at 263-7874 (fax). '~Vendy~d~hm~' Dat~ ..... AOGCC Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL March 20, 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Temporary Injection Well G-40 Waterflood Injector Grayling Platform Trading Bay Unit Wendy: Per our conversation this morning regarding Well G-40, I am requesting permission to temporarily inject into the well, if necessary. A Water Flow Log, run on the well in January 1998, revealed a casing leak at +/- 3300' MD, which is within the Grayling Gas Sands Formation boundaries. The interpretation is that the water travels down the outside of the casing, past the surface casing shoe at 5128' MD, and continues downward to the Hemlock Formation at approximately 10000' MD. The well has been shut in, awaiting workover repair. The rig schedule for the active rig program on the Grayling Platform calls for the workover of another injection well, G-12RD2, which is currently an active injector. Prior to the workover of this well, diagnostic work is needed using slickline. The shut down of the G-12RD2, which would be for an estimated maximum time period of 36 hours, may result in the loss of waterflood injection in other wells during that time if injection rates and pressures drop below the operating threshold of the injection pumps. Unocal would like to maintain injection operations. Therefore, Unocal requests permission to inject in to Well G-40 for a maximum of 36 hours while diagnostic work is performed on G-12RD2. Initially, an attempt will be made to continue operating the waterflood injection system without using G-40. If G-40 is needed, it is estimated that approximately 1000 barrels of water will go through the casing leak. The work is expected to take place this weekend. If you approve, please acknowledge by faxing back a signed copy of this letter for our records (fax # 263- 7884). If you have any questions please call me at 263-7675. Sincerely, Hal Martin Reservoir Engineer Approval Acknowledgment Wendy Wfahan AOGCC Date ~FEB-O~-98 TUE 15:59 UNOORL RSSET Gfl$ GRP FflX NO, 9072637874 . ,'ii, P, 02/18 Unocal Corporation Agricultural Products 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) Sanuary 29, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Grayling G-5, G-16, G-22, G-36DPN an~9-~/8 casing leaks, Dear Blair: Water-flow logs were run on G-5, O-16, G-22, G-36DPN and O-40. Thc results from these logs indicate possible leaks in thc 9-5/8" casing strings. Thc wells have boca shut-in, Copies of the WFL interpretations with updated wellbore diagrams arc attached for your files, Senior Reservoir Engineer Cook Inlet Watcrglood Management Please return a signed and dated copy of this letter to document notification for our records. Blair Wondzc[l Petroleum Engineer AOGCC Date FEB-03-98 TUE 16:06 UNOOAL "UNOCAL RKB to TBG Hngr = 40.8' Tree connection: Duel 3" ~,000# ASSET GAS GRP ,; FAX NO, 9072637874 P, 16/18 Trading Bay Unit Well # G-40 Completed 4/26/90 II I Illllll I I! I MD TVD BTM WT GRADE CONN ~ TOP BTM. K-SS Butt 15.124 Surf. 1926' $-~0 & K-SS Butt 12.415 Surf. SI?~' K-55 Butt 8.681 Surf 47' N-SO Bu~ 8.681 47' 97~' ~9~ Bu~ L6~ 1 976S' I 0,929' N~0 Bu~ 1.681 10,929 11,146' S-~ BuR $.681 N-80 BuR 2.992 N-80 BuR 2.9~ 0' 9827' 9220' t0J00' ]0J00' 10,606' 9S?0' 9290' LIB ran off 816/97 show~ tbg to be oblongM 2,72" X 2.6F' ~ ~,012' B-1 B-4 ,. NO. Demh ,, 4020' JEWELRY DETAIL IIII1[111 IIIIIII Ill] _Il I III I. U A 9760' B 9?96' 2.90 C 9$13' 2.635 D 982S' 2,99 btm 9827' I I I . .JIU IIIII II I 9762 235 2 9798' 2.90 3 10,348' 2,75 ~ DP MD 10,37S' 4.00 6 DP MD 10,383' 4,00 btm 10,390' ? 10,428 2.75 8 10,S82' 2,9S btm lg,.q 83' Cameron DCB Dual 3-1t2" Tubing hanger. SItORT STRia 3-1/2" Otb "XA" SIidinI Sleeve 9-S/~" Offs "~' Dual Pacer, SS 3-l~' Otis "X~ Nipple, 2.7f Ball Catcher Sub ~NO I ~ . ' IIIII II I II 3-1~" Otb "~" Sliding Sleeve 9-~" Otis "~" Dural 3-t~' O~ ~. 8tldlnt Otis ~lBht Slat ~cator W/ O~ ~eal Bore gzt 3-1~" O~8 "X" Nipple 4 6 6 ~, WF-3 --- WF-~ _--' WP.6 RT to MLLW ELEV= 103' TD" 11,267' ETD= 11,143' MAX HOLE ANGLE" 27.2' G-40,DOC SLICKLI~ TAGS SS Tag "XN" w/2.72" GR 815/97 ~ 9813' LS Tagged obstruction wi 2,72" GR & 2,72" LIB 8/6/97 ~ S,012' Tag fill w/2,25" LIB 8/7197 ~ 11,086' WIRELINE WORK LS· Spinner ran on 1/2208 indicates tbg lealts ~ 9812' & 10,125' ·WFL ran on 1/23/98 indicates csg leak between 3250' & 3350'. · WFL indicated multiple SS tbg leaks, sldg sive ~ 9760', tbg Jt between $1dg sire & pkr and between 1200' to 3400'. STIMULATIONS 2 stag acid Job wt dlverter, 50 bbb ofHCL & 7S bbb of 6.1/2% X 1-I/2" mud acid 2 stag acid Job, 40 bbb ofHCL & 135 bbb of 6-1/2% X 1-1/2" mud acid 3/29/90 West Forland 3/29/90 HB.I & 2 Accum, Date Zone T?P Btm Ami .... SPF ....... L..ast Opr, , P.re.l..ent Condition ...... 0,880' 0,882' ., 2' 4 3/20190 Cmt 5qz B;! e,892_'._. U28'. 34' .8 3126/90 Open f/[nlacti0. ' e,934' 9,836' 2' 4 3/1~/~0 .. Cmt Oqz ...... t0,111' .,,.1,0J 13' 2' 4 ..... 3116/90 Cmt. Sqz B-4 I 0J28' ......10,208' eh,:' ' e 3/2B/g0 Open fl Inlectlon ..... 1%218' 10,220', 2. ~... 4 3/16/oo cmt elqL I%456' ,, 1 ~0,467' 2.. ........... 4 ....... 3/i?/9~. cml sqz_~i. WP-2 10,~26' 10,666' 40' . ..... 8 ...... 3/26/90 Open f/Injection ...... WP4 10,680' 10,770' 90' 8 3/211/90. opefifl inje .ctlon _ WF ~... ¶ 01935' 10,8~8' . 56' ' O ~/26/B0 OPen f! Inl~L WP -6 10,9!6' 10,072' ......... . 6T 8 .... 3/26/00 Open fl Injection WF -? 10,993' 11,040' 47, 8 3/26/90 Open fl Injection FEB 0 $ DRAWN BY: ~LT 1998 FEB-03-98 TUE 16:07 ,, ,,~N-30-98.FRI 17:03 UNOCRL RSSET GRS GRP ~.!. I.,.~ "~rger FRX NO. 9072637874 FAX NO. 1907[~ P. 17/18 P, OI 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHE ET OA?E: January 30, 1998 TO; Hal Martln/Ohds Ruff UNOCAL FROM: RE: Rob North GeoQuest ICS G-40 WFL Results TIME; 3:44 PM PHONE: 907-263-76'75 PAX: 907-263 FHONE; (907) 563-1597 FAX; (907) 562-6521 Number of pages Including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a log presentation of the WFL results for G-40, Below is a brief disouselon: With the tubing to 9 5/8" annulus open during Injection the well was returning 1040 bbls to the surface. This flow appears to originate from the sliding sleeves at 9762 and 976o In the long allcl shod strings. No flow is seen comlllg up past the packer at 9789 feet. With the tubing to 9 5/8" annulus closed up-flow continues at a reduced rate. This flow travels up the tubing x 9 5/8" annulus until between 3350 and 3250 ft where It exits the 9 5/8" casing, An additional up-flow Is measured across the lower packer at 10378. Down-flow In the tubing x 9 5/8' casing Is seen starting between 900 and 1200 feet. Thls flow continues down and appeam to exit the 9 5/8" casing In the same Interval as the up flow mentioned above (~3300 ft). This combined flow then travels down the 9 5/8" x 13 3/8"/OH annulus to the reservoir at or below 10000 feet. Working on GI-38DPN now. Regards, Rob... FEB-OS'-08 TUE 16:07 · :' :JBN-30,-98 FRI 17:03 , UNOCAL R$SET GRS GRP F~X NO, 9072637874 P. 18/18 ~1,~ 'horror FAX' NO, lgO~Rq~q9 P, 02 IJNOCAL, TBU ~v40, TRADING BAY UNIT, Wl~k ~.34an-98, (9B011) I.......... ! ° !x ...... ° ~ (~ i '~ ,~'~ (.:,,.' ~ ~,,,,~ ',:~ . ~ _ . I~!',~~I~.1 I,~t~5~'~:~[tli~ ~ ,~ .,':t ', ~';. ; ~ , ,; ,, , ,, ~ , , , [ t, ,~. ~ , ,~, " ' '" I" ' · ~ ~ ~ , i I ~ _ . ~ ~i' ,~ I~, ~ I , ~ ' ,, ', ~ v,:i~, , ~ I ~ ,' 7~';~__ i I _. I II .' ...... ' ',,,, :. ~ [[.: t, I ~r, ,,...~ ...... , : - ~ . ~ , ~, , , : ~' ,,'.,, , i ~ ~ .... ',- ' -, -, I .... JAN-27-98 TUE 18:44 UNOOAL ASSET GAS GRP FAX NO. 9072637874 ,,,,,,..,...~ ~ Unocal Corporation Agricultural Products 909 West 9® Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telepfione (907) 263-7830 UNOCALe January 27, 1998 Blair Wonctzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 P, 01/01 'z o Re: Grayling Cr$6DPN and Ct40 possible 9-$/8 casing leaks. Dear Blair: Water-flow logs were nm on G-36DPN and 0,40 on January 25 and January 23, respectively. The initial results from these logs indicated that there are leaks in the 9-5/8" casing strings. Each well was shut-in following the analysis of thc logs. Copies of the WFL interpretations will be sent this Friday for these wells and G-5. Attached is a copy of the G-22 WFL interpretation by Rob North of Geosource. These wells are preliminarily scheduled to be repaired for late 1998 and early 1999, A detailed plan for the repairs is expected within thc next three months. $C~" Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document notification for our records. Blair W°ndzell Petroleum Engineer AOGCC Date ,~aska 0~1 & Gas Cons. Commiss)on Ancho~ge t' STATE OF ALASKA ALASKA AND GAS CONSERVATION' ,,.)MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon: Suspend: Operation shutdown Re-enter suspended well Alter casing: Repair well Plugging: Time extension Stimulate: Change approved prograrr Pull tul~ing: Variance: Perforate: Other: '[]l'C WAIVER --, 2. Name of Operate 5. Type of well ~. 6. Datum elevation (DF or KB UNOCAL Development ~ 103' RT above MLLW feet "§. Address Exploratory ~. 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service:~,~¢,., Trading Bay Unit 4. Location of well at surface 8. Well number Leg #1, Conductor #25, 1900' NSL & 1459' WEL f/SE corner, Sec. 29, T9N, R13W, s.rv G-40 At top of productive interv~ 9. Permit numbe~ Top of Hemlock-9887' MD, 663' SNL & 2417' WEL f/SE corner, Sec. 32, T9N, R13W, S.lV 90-3 At effective deptl' 10. APl number 50-733-20412-00 At total deptl' 11. Field/Poe 11,267' MD, 1155' SNL & 2653' WEL f/SE corner, Sec. 32, TgN, R13W, S.M McAurthur River / HemLo,ck,~,vV,,Est Forland 12. Present well condition summar R~LblVbDi Total depth: measurec 11,267' feel Plugs (measured', truevertica 10,638' feel 2 Effective depth: measurec 11,143' feel Junk (measured: true vertica 10,499' feel Naska 0il & Gas Cons. C0maiSsi0tt Casing Length Size Cementec Measured depti' ARC~{~ertical dept~ Structural 421' 20" Driven 421' 421' Conductor 1,926' 16" 3,400 sx 1,926' 1,926' Surface 5,128' 13 3/8" 4,950 sx 5,128' 4,973' Intermediate Production 11,232' 9 5/8" 2,710 sx 11,232' 10,606' PerfoLirnat~'ron depth measurecORI61NAL See Attchment true vertica Tubing (size, grade, and measured deptl' LS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl ~r Cplg w/TK-99 Internal Coating @ 10,46: SS: 3-1/2", 9.2#, N-80, Imp. Butt. w/TKO MMS Spcl CIr Cplg w/TK-99 Internal Coating @ 9,82' Packers and SSSV (type and measured deptl' Otis "RDH" Dual Pkr @ 9796' Otis "BWH" Perm Pkr @ 10,382' DPM (10,375' DIL'. 13. Attachement., Description summary of proposal Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve~ Oil: Gas: Suspended: Name of approve Date approve( Service: Water Injection 17' I hereby certify"tl~at"t~e fore~oir~ is trce¢'~;I c'¢frect t° the best °f mY knowled{' ',~.¢~ FOR COI~IMISSION USE ONLY Conditions of approval: Notify Commission so representative may witne I Approval N_o~ ¢,~ Plug integrit~ BOP Test Location clearanc4 - ~ ..~ Mechanical Integrity Tes Subsequent form required 10 ~ ¢-Q.~"/-,~ -- ' - Approved by order of the CommissionE ~-'~ Commissioner Datec~/~/) ~ (~ Well G-40 Failed its MIT on 8/5/97. The well will be repaired during the '98~'99 Grayling Workover Program. Unocal requests a UIC Waive~until 1999 summer end to complete repairs to the well. Form 10-403 Rev 06/15/88 ~'~ ~~tcte. ~'~¢._¢z~ /~ppr.ove~ OoP'~ SUBMIT IN TRIPLICATE G-40 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-40 PERFORATIONS MD MD TVD Zone Top Btm Btm B-1 B-4 WF-2 WF-3 WF -5 WF -6 WF -7 9 880' 9 892' 9 934' 10111' 10 128' 10218' 10 455' 10 525' 10 680' 10 833' 10915' 10 993' 11 O42' 9 882' 9 926' 9 936' 10113' 10.208' 10 220' 10.457' 10 565' 10 770' 10.888' 10 972' 11 040' 11 044' TVD Top 9 338' 9 349' 9 388' 9 552' 9 568' 9 652' 9 871' 9 936' 10,079' 10,218' 10,293' 10,363' 10,407' Amount Present Condition 9 340' 9.380' 9.390' 9 554' 9 642' 9.654' 9.873' 9 973' 10 161' 10 268' 10 344' 10 406' 10 409' 2' Cmt Sqz 34' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 80' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 40' Open f/Injection 90' Open f/Injection 55' Open f/Injection 57' Open f/Injection 47' Open f/Injection 2' Cmt Sqz RECEIVED 25 !998 Alaska 0ii & Gas Cons. Commission Anchorage Page 1 STATE OF ALASKA ALASKA OI' GAS CONSERVATION uMMISSION APPLICATION FOR SUNDRY APPROVALS ~ Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pulltubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 103' RT above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519- 6247 Service:-~- Trading Bay Unit '4.' Location of well at surface 8. Well number Leg#l, Conductor#25, 1900' NSL & 1459'WEL f/ SE corner, Sec. 29, T9N, R13W, S.M. G-40 At top of productive interval 9"~'. Permit number Top of Hemlock-9887' MD, 663' SNL & 2417' WEL f/SE corner, Sec. 32, T9N, R13W, S.M. 90-3 At effective depth 10. APl number 50-733-20412-00 ~ ~" ~ ~'~. At total depth 11. Field/Pool '" '~ ~ ~; ii-, ~ ' ~'~" 11,267' MD, 1155' SNL & 2653' WEL f/SE corner, Sec. 32, T9N, R13W, a.M. McAurthur River / Hemlock & West FOrl~nd 12. Present well condition summary i::' ~ Total depth: measured 11,267' feet Plugs (measured) 8 ]997' true vertical 10,638' feet ~/aS~ 0ii & Gas :Cons, Effective depth: measured 11,143' feet Junk (measured) ~ilo~i'o.J~ag{~....~,~ . true vertical 10,499' feet ' ' Casing Length Size Cemented Measured depth True vertical depth Structural 421' 20" Driven 421' 421' Conductor 1,926' 16" 3,400 sx 1,926' 1,926' Surface 5,128' 13 3/8" 4,950 sx 5,128' 4,973' Intermediate Production 11,232' 9 5/8" 2,710 sx 11,232' 10,606' Liner Perforation depth: measured See Attchment true vertical Tubing (size, grade, and measured depth) La: 3-1/2", 9.28, N-80, Imp. Butt. w/TKO MMS Spcl CIr Cplg w/TK-99 Internal Coating @ 10,463' SS: 3-1/2", 9.28, N-80, Imp. Butt. w/TKO MMS Spcl CIr Cplg w/TK-99 Internal Coating {~ 9,827' Packers and SSSV (type and measured depth) Otis "RDH" Dual Pkr @ 9796' Otis "BWH" Perm Pkr @ 10,382' DPM (10,375' DIL) "'i 3. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: (~~, Title: ~" ~;~%.,. O~'~ , ~ ~.,/ Date: ~' ~ ~ FOR COMMISSION USE Conditions of approval: Notify Commission so representative may witnessI --~2~' / ~~'' Plug integrity BOP Test Location clearance Mechanical Integrity Test ubsequent form required 10- ~,o ~ unglnal Signed By Approved by order of the Commissioner David W. Johnston Commissioner Date /~' '"' Well G-40 Failed its MIT on 8/5/97. Unocal requests a continuation of injection while the well is being evaluated for either ~----~. workover to replace the existing completion or a WFL to insure csg integrity. ,,.., Form 10-403 Rev 06/15/88 · - ,¥:.. ,.,,,;,\~i1~/.~ ~,4.~ SUBMIT IN TRIPLICATE G-40 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-40 PERFORATIONS MD MD TVD TVD Zone Top Btm Top Btm B-1 B-4 WF-2 WF-3 WF -5 WF -6 WF -7 9,880' 9,892' 9,934' 10,111' 10,128' 10,218' 10 455' 10 525' 10 680' 10 833' 10 915' 10 993' 11 042' 9,882' 9,926' 9,936' 10,113' 10,208' 10,220' 10,457' 10,565' 10,770' 10,888' 10,972' 11,040' 11,044' Amount Present Condition 9 338' 9 349' 9 388' 9 552' 9 568' 9 652' 9 871' 9,936' 10,079' 10 218' 10,293' 10,363' 10,407' 9,340' 9,380' 9,390' 9,554' 9,642' 9,654' 9,873' 9,973' 10,161' 10,268' 10,344' 10,406' 10,409' 2' Cmt Sqz 34' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 80' Open f/Injection 2' Cmt Sqz 2' Cmt Sqz 40' Open f/Injection 90' Open f/Injection 55' Open f/Injection 57' Open f/Injection 47' Open f/Injection 2' Cmt Sqz Page 1 Memorandum UNOCAL )" TO: BLAIR WONDZELL FROM' KIRK KILOH Transmitting one (1) Blueline and Sepia copy of Cement Bond/Evaluation Logs of each of the following wells: G-22 6-22-75 r~c~? ,,/ ,.. G-40 r~ 7' 3-16-90~ 3-24-90 $ -- t b-,~ o /~C& ~ K- 15RD ~uB-6-79;' 10-8-89 D-45 5-28-89 v..~,~l" 5-2.~- ~ (.,~ 7' ~ RECEIVED DEC 1 B 1990 Alaska 0Il & Gas Cons. Commission Ancbo~e FORM 1.0C03 (REV, 8-85) PRINTED IN U.S.A. ( , STATE OF ALASKA ALASK¢~ .... AND GAS CONSERVATION C,. ,dMISSION WELL COMPLETION OR RECOMPLETIO,N REPORT AND LOG , b_ Classification of Service Well 1. Status of Well .' .~..,., .~-- ;~ "'~' ~ii Water Injection OIL ~ GAS L-~ SUSPENDED [] ABANDONED [] SERVICE [~ ........ . .. 3. Address ' : 8. APl Number .... . 4[ Location of well at surface ....... ' ~¢ 9. Unit or Lease ~ame Leg ~1, Conductor ~25, 1900' NSL & 1459' WEL F/SE corner, Sec. 29, T9N, R13W, S.M. T~ading .Bgy Unit A~ Top Producing Interval 10. Well Number Top Hemlock-988?' MD, 663' SNL & 2417' WEL, F/SE corner, Sec. 32, TgN, R13W, S.M. ~.S~O A~ Total Depth ~267' MD, 1155' SNL & 2653' WEL 11. Field and Pool ..¢~/~-~ C~~SOO. 22, Tg~ --~,,,~" ~--:.-¢, Mc~rthur River Fiel~ 5. Elevation ~n feel (indicate KB, DF, e~c.) ~. Lease Designation and Serial No. 12, Date Spudded 13. Date T.D. Reached 14, Date Comp., Susp. or Aband. 15. Water Depth, if offshore 6. No. of Completions I / feet MSL 01~3~ ~-*~ ~ ~* ~ 90 ' ' *~= ' ' .... ~7. Total Depth (M~+IVD) 18.~lu~ack~ep~(M~D) 1~ ~irectional~urveV 20. De0th~hereSS~set 21.1htckness of Permafrost YES ~ NO ~ feet MD 22. Type E~t~r O~r %~%n' '~ 23. '--~-~~ ..................................... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... 20 ' -- l" walt--' Su~ f 42 l' Dr ~ven Grouted w/314 ~x~ ' ' 16' 75~ K-55 - Su::f' i~6' 22" i~00 sx P~im~:~y/1500 sx To~ jo "13.-3/~-68~ K-55, ~-ou ou. f 51~8' 17-1/2" 4300 sx~ Pri,,:Ly/650 'ex Top jo 9-5/8" ~ .... , S-95 Su~f ......... ....... "'~4'] ~e,'fo,'a~o.~ open ~o ~,'oduc~io. (MD+~VD of Top ~.d 8o.o~ ~.d 2~. TU8~NO RECORD interval, sizeand number) SIZE DEPTH SET (MD) PACKER SET (MD) ' ' ................... SS 3-i 2" 9827' 9 96' See attached perforation record LS 3-1 2" 10463' 10 86' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ., DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USE© ...... See attache.d: ACid Sugary . Ce,ment Soueeze Sugary .... 27. PRODUCTION TEST Sa~e Fi.-s~ Production ~ Me~hod 0f opera~ion '(Flowing, gas lift, etc.) N/A I , . Dateof Test Hours Tested PRoDuctION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD ~ ............. Flow Tubing Casing Pressure cALCu~A7ED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co/r) ~ - ' Press. ' 24-HOUR RATE ~ 28. -- .... CORE UATA , Brief description of lithology, porosiW, fractures, apparent dips and presence of oil, gas or water. Submit core chips. :.. RECEIVED JUN - AJ~8~.Oii & Gas Cons. Com~i~Jo~ AnchomgO -- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME 31. LIST OF ATTACHMENTS GEOLOGIC MARKERS 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 32. I hereby certify that the foregoing is true and correct to the best of rny knowledge Signed .... C. ........ ~ . L..~4~,~ Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ,, , ,, ,, Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- in§ and the location of the cementing tool. Item .27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jecti0n,'Gas Injec'tiOn;' Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE DATE 03/17/90 03/17/90 03/18/90 03/18/90 03/19/90 03/20/90 03/24/90 03/24/90 03/24/90 03/24/90 03/24/90 03/28/90 03/28/90 E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS TBUS G-40 PERFORATION RECORD DEPTH 11,042-11,044' DIL 10,407'-10,409' TVD 10,455-10,457' DIL 9,871'-9,873' TVD 10,218-10,220' DIL 9,652'-9,654' TVD 10,111-10,113' DIL 9,552'-9,554' TVD 9,934-9,936' DIL 9,388'-9,390' TVD 9,880-9,882' DIL 9,338'-9,340' TVD 10,993-11,040' DIL 10,363'-10,406' TVD 10,915-10,972' DIL 10,293'-10,344' TVD 10,833-10,888' DIL 10,218'-10,268' TVD 10,680-10,770' DIL 10,079'-10,161' TVD 10,525-10,565' DIL 9,936'-9,973' TVD 10,128-10,208' DIL 9,568'-9,642' TVD 9,892-9,926' DIL 9,349'-9,380' TVD INTERVAL REMARKS BASE WF-7 ISOLATION SQUEEZE TOP WF BASE HB-4 TOP HB-4 BASE HB-1 TOP HB-1 ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE W.F.-7 INJECTION-L.S. W.F.-6 INJECTION-L.S. W.F.-5 INJECTION-L.S. W.F.-3 INJECTION-L.S. W.F.-2 INJECTION-L.S. H.B.-4 INJECTION-S.S. H.B.-1 INJECTION-S.S. ECEIVED Alasl(a OiJ & Gas Cons. u mmJssion Anchorage LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS CEMENT SQUEEZE SUMMARY TBUS G-40 NEW WELL 1990 3/17/90 SET RET @ 11070' BOTTOM TO SQUEEZE AGAINST PERF 11042'-44' SQZ HOLES AT BASE OF THE WEST FORELAND (4 HPF) SET RET @ 10973' SQZ W/l16 SXS CMT TO ISOLATE BASE OF WEST FORELAND SET RET @ 10480' BOTTOM TO SQUEEZE AGAINST PERF 10455'-57' SQZ HOLES AT TOP OF THE WEST FORELAND (4 HPF) 3/18/90 SET RET @ 10415' SQZ W/104 SXS CMT TO ISOLATE TOP OF WEST FORELAND PERF 10218'-20' SQZ HOLES AT BASE OF HEMLOCK BENCH 4 (4 HPF) SET RET @ 10190' SQZ W/63 SXS CMT TO ISOLATE BASE OF HEMLOCK BENCH 4 PERF 10111'-13~ SQZ HOLES AT TOP OF HEMLOCK BENCH 4 (4 HPF) 3/19/90 SET RET @ 10055' sQz W/78 SXS CMT TO ISOLATE TOP OF HEMLOCK BENCH 4 PERF 9934'-36' SET RET @ 9900' SQZ HOLES AT BASE OF HEMLOCK BENCH 1 (4 HPF) SQZ W/133 SXS CMT TO ISOLATE BASE OF HEMLOCK BENCH 1 3/20/90 PERF 9880'-82' SET RET @ 9860' SQZ HOLES AT TOP OF HEMLOCK BENCH 1 (4 HPF) SQZ W/37 SXS CMT TO ISOLATE TOP OF HEMLOCK BENCH 1 LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS ACID STIMULATION SUMMARY TBUS G-40 NEW WELL 1990 ACID STIMULATED WEST FORELAND BY PUMPING TWO STAGES AS FOLLOWS: FIRST STAGE: 25.0 BBL, 7-1/2% HCL 37.5 BBL, 6% HCL/ 1-1/2% HF 100.0 BBL, FIW W/SURFACTANT SECOND STAGE: 25.0 BBL, 7-1/2% HCL W/0.1% SODIUM BENZOATE DIVERTER 37.5 BBL. 6% HCL/ 1-1/2% HF 100.0 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT ACID STIMULATED HEMLOCK BENCH 4 AS FOLLOWS: 28.6 BBL, 7-1/2% HCL 95.2 BBL. 6% HCL/ 1-1/2% HF 142.9 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT ACID STIMULATED HEMLOCK BENCH 1 AS FOLLOWS: 12.1 BBL, 7-1/2% HCL 40.5 BBL. 6% HCL/ 1-1/2% HF 81.0 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT UNOCAL WELL RECORD PAGE NO. 1 of 2 LEASE TRADING BAY WELL NO. TBUS G-40 FIELD MCARTHUR RIVER LOCATION: CONDUCTOR ~25, LEG ~1, !900'NSL & 1459' WEL F/SE CORNER, SECTION 29, T9N, R13W, S.M. PERMIT NO. 90-3 SERIAL NO. ADL 17594 TD 11,267' TVD 10638' DEVIATION (BHL) 3055'S & 1195'W OF SURF. LOC COMPANY ENGINEER CPIUDANOV., GRAHAM, HARNESS SPUD DATE 01-13-90 COMP. DATE 04-02-9( CONTRACTOR POOL ARCTIC AK RIG NO. 55 TYPE UNIT NATIONAL 1320 DRILL PIPE DESCRIPTION 5". 19.5~, E&S ELEVATIONS: WATER DEPTH . 125' RT TO OCEAN FLOOR 228' RT TO MLLW 103' RT TO DRILL DECK 23.3' RT TO PRODUCTION DECK 46.6' APPROVED CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 1" Wall Driven 421' Grouted W/314 sxs 16" 75~ Buttress K-55 1926' Cmt'd w/2100 sxs 13-3/8" 68~ Buttress K-55 & S-80 5128' Cmt'd w/4950 sxs 9-5/8" 47~ Buttress N-80 & S-95 11232' Cmt'd w/2710 sxs PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 03-17-90 11042'-11044' 11143' Sqz.-Base WF-7 Sqzd. w/l16 sxs 03-17-90 10455'-10457' 10480' Sqz...rTop WF . Sqzd. w/104 sxs 03-18-90 10218'-10220' 10270' Sqz.-Base HB-4 Sqzd..w/ 63 sxs 03-18-90 10111'-10113' 10160' Sqz.-Top HB-4 sqzd. w/78 03-19-90 9934'-9936' 10055' Sqz.-Base HB-1 Sqzd. w/133 sxs 03-20-90 9880'-9882' 9914' Sqz.-Top HB-1 Sqzd. w/ 37 sxs 03-24-90 10525'-10565' 11143' Injection WF-2 open 03-24-90 10680'-10770' 11143' Injection WF-3 open 03-24-90 10833'-10888' 11143' Injection WF-5 open 03-24-90 10915'-10972' 11143' Injection WF-6 open 03-24-90 10993'-11040' 11143' Injection WF-7 open 03-28-90 9349'-9380' 11143' Injection HB-1 open 03-28-90 9892'-9926' 11143' Injection HB-4 open INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 4-30 Hemlock (Short strinq) 1500psi 3250psi .4611 BWPD Injection 4-30 West Foreland (Lonq stri~) 1500psi 3250psi 7542 BWPD Injection WELL HEAD ASSEMBLY TYPE: Cameron' CASING HEAD: Cameron 16" 3M x 16" SOW Type WF casinq head w/2 ea 2-1/16" 5M outlets CASING HANGER: 16" x 13-3/8" Type AW slip & seal assy CASING SPOOL: Cameron 16-3/4" 3M x 13-5/8" 3M Type WF casinq spool W/2 ea 2-1/16" 5M outlets CASING HANGER: Cameron. 13-5/8" x 9-5/8" Type CA slip & seal ass¥ TUBING HEAD: Cameron 13-5/8" 3M x 11" 5M DCB-S spool w/2 ea 2-1/16" 5 M outlets TUBING HANGER: pual DCB-S 11" 5M x 3-1/2" EUE top x 3-!/2'~. MMS bottom (410 SS) TUBING HEAD TOP: 11" 5M MASTER VALVES: Cameron Dual Solid Block (salt water trim) w/2 ea 3-1/8" bore maeter valves & 2 ea 3-1/8" bore swab valves CHRISTMAS TREE TOP CONN: 3T1/2" EUE 8RD LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS TBUS G-40 PERFORATION RECORD DATE 03/17/90 03/17/90 03/18/90 03/18/90 03/19/90 03/20/90 03/24/90 03/24/90 03/24/90 03/24/90 03/24/90 03/28/90 03/28/90 DEPTH 11,042-11,044' DIL 10,407'-10,409' TVD 10,455-10,457' DIL 9,871'-9,873' TVD 10,218-10,220' DIL 9,652'-9,654' TVD 10,111-10,113' DIL 9,552'-9,554' TVD 9,934-9,936' DIL 9,388'-9,390' TVD 9,880-9,882' DIL 9,338'-9,340' TVD 10,993-11,040' DIL 10,363'-10,406' TVD 10,915-10,972' DIL 10,293'-10,344' TVD 10,833-10,888' DIL 10,218'-10,268' TVD 10,680-10,770' DIL 10,079'-10,161' TVD 10,525-10,565' DIL 9,936'-9,973' TVD 10,128-10,208' DIL 9,568'-9,642' TVD 9,892-9,926' DIL 9,349'-9,380' TVD INTERVAL REMARKS BASE WF-7 ISOLATION SQUEEZE TOP WF BASE HB-4 TOP HB-4 BASE HB-1 TOP HB-1 ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE H.B.-4 INJECTION-S.S. H.B.-1 INJECTION-S.S. W.F.-2 INJECTION-L.S. W. F. -3 INJECTION-L. S. W.F.-5 INJECTION-LoS. W.F.-6 INJECTION-L.S. W.F.-7 INJECTION-L.S. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS CEMENT SQUEEZE SUMMARY TBUS G-40 NEW WELL 1990 3/17/90 3/18/90 3/19/90 SET RET @ 11070' PERF 11042'-44' SET RET @ 10973' SET RET @ 10480' PERF 10455'-57' SET RET @ 10415' PERF 10218'-20' SET RET @ 10190' PERF 10111'-13' SET RET @ 10055'. PERF 9934'-36' SET RET @ 9900' 3/20/90 PERF 9880'-82' SET RET @ 9860' BOTTOM TO SQUEEZE AGAINST SQZ HOLES AT BASE OF THE WEST FORELAND (4 HPF) SQZ W/l16 SXS CMT TO ISOLATE BASE OF WEST FORELAND BOTTOM TO SQUEEZE AGAINST SQZ HOLES AT TOP OF THE WEST FORELAND (4 HPF) SQZ W/104 SXS CMT TO ISOLATE TOP OF WEST FORELAND SQZ HOLES AT BASE OF HEMLOCK BENCH 4 (4 HPF) SQZ W/63 SXS CMT TO ISOLATE BASE OF HEMLOCK BENCH 4 SQZ HOLES AT TOP OF HEMLOCK BENCH 4 (4 HPF) SQZ W/78 SXS CMT TO ISOLATE TOP OF HEMLOCK BENCH 4 SQZ HOLES AT BASE OF HEMLOCK BENCH 1 (4 HPF) SQZ W/133 SXS CMT TO ISOLATE BASE OF HEMLOCK BENCH 1 SQZ HOLES AT TOP OF HEMLOCK BENCH 1 (4 HPF) SQZ W/37 SXS CMT TO ISOLATE TOP OF HEMLOCK.BENCH 1 RECL IVED JUN - Alaska Oil & Gas Anchorage LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS ACID STIMULATION SUMMARY TBUS G-40 NEW WELL 1990 ACID STIMULATED WEST FORELAND BY PUMPING TWO STAGES AS FOLLOWS: FIRST STAGE: 25.0 BBL, 7-1/2% HCL 37.5 BBL, 6% HCL/ 1-1/2% HF 100.0 BBL, FIW W/SURFACTANT SECOND STAGE: 25.0 BBL, 7-1/2% HCL W/0.1% SODIUM BENZOATE DIVERTER 37.5 BBL. 6% HCL/ 1-1/2% HF 100.0 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT ACID STIMULATED HEMLOCK BENCH 4 AS FOLLOWS: 28.6 BBL, 7-1/2% HCL 95.2 BBL. 6% HCL/ 1-1/2% HF 142.9 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT ACID STIMULATED HEMLOCK BENCH 1 AS FOLLOWS: 12.1 BBL, 7-1/2% HCL 40.5 BBL. 6% HCL/ 1-1/2% HF 81.0 BBL, FIW W/SURFACTANT 300.0 BBL, FIW FINAL DISPLACEMENT LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 16" CASING DETAIL TBUS G-40 JANUARY 1990 JTS · 43 DESCRIPTION 16", K-55, TRICO FLOAT SHOE 16", 75#, K-55, BUTT CASING SAND BLASTED 16", K-55, TRICO STAB-IN 16", 75#, K-55, BUTT CASING CUT OFF 16", 75#, K-55, BUTT CASING CAMERON 16", 3M, WF WELLHEAD RKB LENGTH 2.20 5.72 2.38 1794.25 34.86 1.89 44.70 BOTTOM 1926.00 1923.80 1878.08 1875.70 81.45 46.59 44.70 TO__E~ 1923.80 1878.08 1875.70 81.45 46.59 44.70 0.00 0029d LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 13-3/8" CASING DETAIL TBUS G-40 JANUARY 1990 JTS · DESCRIPTION LENGTH BOTTOM TOP, 43 81 13-3/8", K-55, TRICO FLOAT SHOE 2.30 13-3/8", 68#, S-80, BUTT CASING SAND BLASTED 84.53 13-3/8", K-55, TRICO FLOAT COLLAR 2.20 13-3/8" 68~ S-80 BUTT CASING 1864.29 13-3/8" 68# K-55 BUTT CASING 3099.84 CUT OFF 13-3/8" 68# K-55 BUTT CASING 29.76 CAMERON 16-3/4" 3M X 13-5/8" 3M, WF CASING SPOOL 2.26 42.44 RKB 5127.62 5125.32 5040.79 5038.59 3174.30 74.46 44.70 42.44 5125.32 5040.79 5038.59 3174.30 74.46 44.70 42.44 0.00 0029d LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. O1 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 9-5/8" CASING DETAIL TBUS G-40 JANUARY 1990 JTS. DESCRIPTION LENGTH BOTTOM TOP 28 44 19]~ 9-5/8", N-80, TRICO FLOAT SHOE 1.84 9-5/8", 47#, S-80, BUTT CASING SAND BLASTED 83.87 9-5/8", N-80, TRICO FLOAT COLLAR 1.67 9-5/8", 47#, N-80, BUTT CASING, SAND BLASTED 9-5/8", 47~, S-95, BUTT CASING, SAND BLASTED 9-5/8", 47#, N-80, BUTT CASING, SAND BLASTED 9-5/8", 47#, N'80 BUTT CASING CUT OFF 13-3/8", 68#, K-55 BUTT CASING CAMERON 13-5/8" 3M X 11" 5M, DCB TUBING SPOOL RKB 215.11 1164.73 1833.40 7884.40 4.63 2.01 40.43 11232.09 11230.25 11146.38 11144.71 10929.60 9764.87 7931.41 47.07 42.44 40.43 11230.25 11146.38 11144.71 10929.60 9764.87 7931.47 47 · 07 42.44 40.43 0.00 0029d LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS DATE 25 APRIL 1990 TUBULAR DETAIL WELL ~G-40 TUBING X CASING PAGE ONE FACILITY GRAYLING STRING SHORT SIZE 3-1/2" WT. 9.2 GRADE N-80 NOTE: ALL TBG IS INTERNALLY PLASTIC COATED THD BUTT NO. DESCRIPTION LENGTH TOP BOTTOM 307 3-1/2 OTIS CCS BALL CATCHER 1.88 9824.70 4.52 x 2.95 3-1/2 9.2~ N-80 BUTT PUP JT 9.98 9814.72 3-1/2 BUTT OTIS XN NIPPLE 1.49 9813.23 3.94 X 2.635 3-1/2 9.2~ N-80 BUTT PUP JT 9.97 9803.26 OTIS 9-5/8 X 3-1/2 DUAL RDH 6.98 9796.28 PACKER 3-1/2 9.2~ N-80 BUTT TBG 31.68 9764.60 OTIS 3-1/2 BUTT XA SLEEVE 4.11 9760.49 4.28 X 2.75 3-1/2 9.2~ N-80 BUTT TBG 9718.44' 44.05 3-1/2 9.2# N-80 BUTT PUP JT 2.35 41.70 CIW DUAL HANGER .90 40.80 3-1/2 EUE BOX UP KB 0.00 40.80 9826.58 9824.70 9814.72 9813.23 9803.26 9796.28 9764.60 9760.49 44.05 41.70 40.80 308 TOTAL JOINTS ALLOWS FOR 2' OF COMPRESSION ABOVE DUAL PKR. RECEIVED ,Oil.& 6as Cons. 'Anchorage LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 01 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS DATE 25 APRIL 1990 TUBULAR DETAIL PAGE ONE WELL ~G-40 TUBING X CASING FACILITY GRAYLING STRING LONG SIZE 3-1/2!', WT. 9.2 GRADE N-80 NOTE: ALL TBG IS INTERNALLY PLASTIC COATED THD BUTT NO. DESCRIPTION LENGTH TOP BOTTOM 17 307 3-1/2 BUTT MULE SHOE 0.87 3-1/2 9.2# N-80 BUTT TBG 32.74 3-1/2 BUTT X NIPPLE 1.36 3.80 x 2.75 3-1/2 9.2~ N-80 BUTT TBG 32.56 OTIS SEAL ASSY 8.80 4.04 x 2.95 LOCATOR SUB 1.45 4.97 x 2.95 3-1/2 9.2# N-80 BUTT TBG 32.36 OTIS 3-1/2 BUTT XA SLEEVE 4.12 4.28 x 2.75 3-1/2 9.2# N-80 BUTT TBG 542.86* 9-5/8 x 3-1/2 DUAL OTIS RDH 8.39 PACKER 3-1/2 9.2# N-80 BUTT TBG 32.32 3-1/2 BUTT XA SLEEVE 4.10 4.28 x 2.75 3-1/2 9.2# N-80 BUTT TBG 9719.62'* 3-1/2 9.2# N-80 BUTT PUP JT 2.35 CIW DUAL HANGER .90 3-1/2 EUE BOX UP KB 40.80 10461.73 10462.60 10428.99 10461.73 10427.63 10428.99 10395.07 10427.63 10386.27 10395.07 10384.82 10386.27 10352.46 10384.82 10348.34 10352.46 9806.48 10348.34 9798.09 9806.48 9765.77 9798.09 9761.67 9765.77 44.05 9761.67 41,70 44.05 40.80 41.70 0.00 40.80 328 TOTAL JOINTS ALLOWING FOR 1' OF COMPRESSION BEFORE SETTING DUAL PKR AND 2 'AFTER PKR WAS SET. THIS PUTS THE PERM PKR AT 10386.27. * ALLOWS FOR 1' OF COMPRESSION ABOVE PERM PKR. ** ALLOWS FOR 2' OF COMPRESSION AOBVE PERM PKR. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 12/18/89 12/19/89 12/20/89 12/21/89 12/22/89 12/23/89 12/24/89 01/02/90 01/03/90 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS COMMENCE OPERATIONS ON TBUS G-40 AT 0000 HOURS 12/18/89. Make modifications to Rig #55 necessary to drill G-40 from Leg #1. Worked on rotary table bed. High pressure mud line to Leg #1 complete except for stress relieving. Began installing 8" vent line up the derrick. Continued to work on rotary table bed, vent lines, and gas buster. Drained fluid out of Waukesha #2 and #3. Emptied mud system. Drained drawworks on Rig #54. Freeze protected drawworks on Rig #55. Continued working on rotary table and floor supports. Continued installation of 8" vent line and hook up of gas buster. Changed oil in drawworks, rotary table, and table transmission. Installed lower brace for stabbing board. Changed out bolts on derrick legs. Fabricated landing for stabbing board ladder. Continued working on floor and rotary table supports. Set rotary table and built floor around same. Finish building floor around rotary table. Continued working on stabbing board. Removed old lockers and installed new in Rig #55 change room. Installed landing for stabbing board and put safety lines on same. Mounted clamps for 4" vent line up the derrick. Finished mounting clamps for 4" vent line. Finished running gyro survey in G-7 and returned well to production. Secured rig for holiday shutdown. Suspend operations on G-40 at 0330 hours on 12~24/89. RESUME OPERATIONS ON TBUS G-40 AT 0900 HOURS, 1/2/90. Prepare to clear drill deck for rig move to Leg #1. Offload to boat the welding shop, change room, one pipe rack section, and one cement pod. Worked second section of pipe rack into an open area for easy crane access. Center rig over skid beams. StaRted getting quite a bit of ash fallout on platform from volcanic eruption which occurred at 1800 hours. Production shut in platform. Halted all drilling operations at 2130 hours. Continued waiting on ash fallout to clear until 1100 hours. Resumed working with crane. Removed subbase skid rail extension. Offload to boat second piperack section, koomey unit, cement unit, and cement pod #2. Jacked rig half way to leg #1 and installed stairways and landing on back side of rig. Continued jacking rig and centered up over conductor #25 in the N-S direction. Need to modify crane run around due to interference with rig. Turned rotary table and started installing support beams. Unload and spot cement pods, cementing unit, air compressor package, koomey unit, and miscellaneous equipment. LEASE MCARTHUR RIVER UNOCAL DRIL~'NG RECORD ALASKA REGION PAGE NO. of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 01/04/90 01/05/90 01/06/90 01/07/90 01/08/90 01/09/90 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued unloading boat. Spotted accumulator and house. Set skid jacks for E-W skid. Hooked up accumulator lines and all service lines to rig #55. Installed rotary table supports. Installed V-door guides. Offload piperack section from boat. Set racks in position on drill deck. Had quite a bit of interference with crane and had to pull accumulator house to get racks in place. Turned rotary table and build floor. Centered rig over Conductor #25. Worked on crane walkway to eliminate interference. Installed rig tie downs. Start building hand rails for pipe rack. Finish tie down of rig. Built missing hand rail sections for pipe racks. Leveled derrick. Removed steps and landing from V-door opening and install pipe slide. Replumb rotary table blower duct. Installed rat and mouse holes. Finish landing on subbase stairs. Bolt down rotary table. Hang stairs off rig floor dog house. Start welding on 21-1/4" 2M casing head. Rehung wind walls around Howco unit. Finish welding casing head. Started rigging up mud ditch. Inspected weld on casing head. Had two small repairs. Spot survey wireline unit. Rig up Totco equipment. Heat treat casing head. Began setting in mud cleaning equipment. Continued rigging up mud cleaning equipment. Stacked in diverter risers. Set in mud cleaning equipment. Install piping.for mud cleaning equipment. Build stands and bracing for diverter lines. Hookup Howco cement pods. Set in 21-1/4" 2M annular preventer. Hook up direction selection valves. Continued setting in diverter line. Continued setting in diverter line. Hookup diverter line and annular preventer. Work on mud cleaning equipment piping. Install landing to survey equipment. Install 10" flow line to poor boy degasser. Hook up hydraulic system for annular preventer and diverter valve. Fabricate bell nipple. Build walkway for pipe rack. Offload drilling equipment, mud logging unit, WL unit, and MWD tools from boat. Continued offloading boat. Continued working on mud cleaning equipment. Ran 4" vent line up derrick. Build bell nipple and flowline. Offload mud material and miscellaneous drilling tools. Function test annular preventer, diverter valve, and both directional valves. Final test of diverter was good. Function test all mud cleaning equipment. Start filling pits to mix mud. Mixed mud and finish welding project on rig floor. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 3 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 01/10/90 416' 01/11/90 424' 01/12/90 421' 01/13/90 617'/196' 01/14/90 862'/245' DETAILS OF OPERATION, DESCRIPTIONS &. RESULTS Continued mixing spud mud, Thawed frozen mud lines. RIH with 17-1/2" bit and 8" DC's to restriction in 20" conductor at 416'. Displaced 20" conductor with spud mud. Function test diverter-OK, Test same to 200 psi-OK. Tripped for 17-3/4" taper mill with 12-1/4" pilot bit. Tagged and milled thru restriction at 416'. Made several passes thru same. CBU, POH. Found mill worn to 17" OD. RIH with 17-1/2" flat bottomed mill. Could not pass restriction at 416'. CBU. Circ at 416'. POH. Layed down 17-1/2" FB mill. RIH with redressed 17-3/4" tapered mill and 12-1/4" pilot bit to restriction at 416'. Weight indicator failed-repaired same. Milled restriction until mill would pass free. Worked tools past shoe of 20" at 421' to 424'. POH. Found 12-1/4" bit and bit sub left in hole (pin fatigue break). Mill worn to 17" OD. Made up fishing tools and RIH to 424' with 6-1/2" grapple and 15-1/2" guide. No recovery. Tripped to change grapple to 7-1/2". No recovery. Tripped to change 15-1/2" guide to a 10-5/8" guide. Appeared to have been making hole with the 15-1/2" guide. Engaged fish at 424' with the 7-1/2" grapple and 10-5/8" guide and recovered 100% of same. Layed down fishing tools. RIH with 17-3/4" tapered mill and milled at 20" shoe for 1-1/2" hrs. Tripped for 17-1/2" junk mill. (Tapered mill worn to 17" OD and sent in for redressing). 17-1/2" junk mill tagged up at 421'. Tripped,for string stab 30' above junk mill. Retagged at 421'. Leveled derrick. Tripped for 17-3/4" OD watermelon mill and worked same 419'-424'. Tripped for 17-1/2" junk mill and worked same from 419'-424'. Shoe in good shape. Drld 17-1/2" hole with junk mill 424' to 429'- POH for 17-1/2" drilling assembly. SpUdded G-40 at 0945 hours., Drld 17-1/2" hole 429'-436' Attempted LOT. Pumped 20 bbls mud ~ith no pressure increase. Drld 17-1/2" hole 436'-617' with major lost circulation problems. (Switched from mud to FIW at 466' due to losses exceeding 200 BPH. Had TLC at 505'. Regained 40% circ at 527' and pumped a 25 bbl gel sweep. Had TLC again at connection at 556'. Drld blind to 617'). Spotted gel pill across open hole. P0H to change out Teleco tool and jars. RIH. Bit hung up at 612' Ran gyro tool-tool would not pass jars. POH. Gyro surveyed hole. Drilled 17-1/2" hole 617'-862'. Spotted gel pill across open hole section. Tripped for OEDP. Spotted 200 bbls mud mixed with 30 PPB Bora Seal across open hole section. Fluid level remaining at 40-50' below rotary table. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 4 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 1/15/90 1/16/90 1/17/90 1/18/90 1/19/90 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 1377'/515' Continued trying to regain circulation. Pumped an additional 100 bbls mud mixed with 30 PPB LCM. Total of 300 bbls pumped. POH with OEDP. RIH with 17-1/2" BHA. Cleaned out 10' of fill. Drilled 17-1/2" hole blind with FIW from 862'-1377' with gyro surveys at 922' and 1200'. Pumped gel sweeps every 60' 1927'/550' Drilled 17-1/2" hole blind with FIW from 1377' to 1927' TD with gyro run at 1562' Pumped viscous sweep. Spotted viscous pill in open hole. POH-some ragged spots but nothing severe. Layed down Teleco and monels. Made up and RIH with 17" x 22" underreamer with 43" bull nose. 1927'/0' Continued running in with underreamer. Cut shoulder and located shoe at 424' DPM. Underreamed 17-1/2" hole to 22" from 424' to 1653' DPM. 1927'/0' Continued underreaming from 1653' to 1927' DPM, sweeping hole every 30' with gel. Circulated and swept hole with 100 bbl of 100 vis mud. Pulled to 20" shoe and waited 1 hour. Ran in and tagged bridge at 1770' DPM. Reamed and washed from 1770' to 1927' DPM. Swept hole with two 100 bbl sweeps of 220 vis gel. Pulled out of hole. Found crack in underreamer body. Changed underreamers and ran in to check for fill. Tagged fill at 1803' DPM. Cleaned out to 1927'. Circulated around 850 BBL of 60 vis gel. Pulled out to 20" shoe and waited 1 hour. Started rebuilding mud volume. Ran in and tagged fill at 1924' DPM. Worked pipe and continued to build mud volume. 1927'/0' Continued to build mud volume for final sweep and change over. Swept hole and changed over to 90 vis mud. Pulled out and laid down underreamer. Rigged up and ran 46 joints (1928.29') of 16", 75# K-55 Buttress casing. Landed with shoe at 1925' RKB and stab-in collar at 1876'. Tagged fill at 1917' and circulated casing down to 1927' with 200 bbl FIW. Ran in stab-in tool on 5" drill pipe and stabbed into collar at 1876' DPM. Rigged up and tested HOWCO cementing lines. Cemented 16" casing as follows: 50 bbl Dual spacer; 1520 sx "G" cement mixed to 97 pcf with 10#/bbl Thix-lite 373 and 1.55 cf/sx FIW, 378 sx "G" cement mixed to 118 pcf with 0.40% Halad 344, 0.25% CFR-3, 0.04% LWL, and .67 cf/sx FIW. Displaced with 24 BBL FIW. Reciprocated pipe 10' throughout cement job. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 5 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 1/20/90 1927'/0' Completed 16" cement job. CIP'at 0045 hours. Pulled out of float collar-floats held ok. Pulled out with drill pipe and stab-in tool. Picked up diverter and set slips on 16" casing. Ran temperature survey to find top of cement. Found top at 1140' WLM. Cut off 16" casing. Rigged down diverter system. Installed hold down flange on 20" casing head. Made final cut for 16" casing head. Weld on 16" 3M cameron "WF" casing head. Stress relieve welds and wrapped with insulation to control cooling. 1/21/90 1927'/0' Started mixing mud in active system. Attempted to pressure test 16" casing head welds-no good. Cut out and rewelded inside weld. Moved crown section and leveled derrick. Work on gas buster line. Retest 16" casing head welds to 800 psi with nitrogen-ok. Ran ultrasonic test on all welds-ok. Started stacking in 20", 3M Rams. 1/22/90 1927'/0' Prepared for top job on 16" casing. Pumped as follows: 56 cf FIW; 500 sx "G" cement mixed to 118 pcf with 3% CaCl2 and 0.67 cf/ax FIW; 200 cf FIW displacement. CIP at 0300 hours. Continued nippling up 20-3/4" 3M Ram preventers and 21-1/4" 2M annular preventer. Rig up HOWCO wireline and ran temperature log to 424'. Pumped top job ~2 on 16" casing. Pumped as follows: 1000 sx "G" cement mixed to 116 pcf (600 sx tail slurry from 16" casing and. 400 sx neat "G"). Could not see any pressure buildup while pumping cement. Did not displace. Washed out lines and well head valves. Ran temperature survey and could not see cement below 20" shoe. Finish hooking up hydraulic lines to BOPE. Set test plug. Attempt to test ceo rams against outside valves on choke manifold. Had leak in riser flange. Changed out API ring. Tested CSO rams and test plug-ok. Rig up test joint for BOPE test. Test BOPE. 1/23/90 1937'/10' Continued testing BOPE. Test witnessed and approved by Mike Minder of AOGCC. Reran temperature survey. Continued hooking up bell nipple and trip tank lines. Cleaned pump suctions. Laid down excess drill pipe from derrick. Made up drilling assembly and ran in to 1862' DPM. Pressure tested casing E~V~D to 2100 psi for 30 minutes; Cleaned out RE~ float collar and cement to 1916' DPM. Circulated clean and retested casing to 2100 psi for 15 minutes. Continued to clean out. JUN - ~ ~990 Drilled shoe at 1926' DPM. Drilled new hole to 1937' DPM. Circulated well clean and A~as~ 0~ & Gas Gone. '"~mm~$i0~sp°tted 100 bbl gel on bottom. Performed LOT uu,,, ..... at 1926' DPM. Pumped away at 680 psi surface A~ch0rag~ pressure (calculated to 0.86 psi/ft frac gradient). Trip for O.E.D.P. to squeeze shoe. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 6 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 1/24/90 1/25/90 1/26/90 1/27/90 1128/90 1/29/90 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 2276'/339' Continued running in with O.E.D.P. to 1926'. Braden head squeeze 16" shoe as follows: Mixed and pumped 302 sx "G" cement with 2% CaC12 to 118 pcf; pulled to 1203' and closed pipe rams; squeezed 268 cuft cement away. Maximum squeeze pressure was 1100 psi. CIP at 0400 hours. Held squeeze in place until 0700 hours. Trip for drilling assembly. Ran in to 1200' and waited on cement until 1200 hours. Continued in and tagged cement at 1929'. Cleaned out to 1937' and ran leakoff test. Leakoff occured at 770 psi surface pressure (1635 psi at shoe) which calculates to 0.963 psi/ft fracture gradient at the shoe. Drilled 14-3/4" hole from 1937' to 2276'. Circulated hole clean. Trip for mud motor. 2497'/221' Completed trip out from 2276' with 14-3/4" rotating assembly. Made up and ran in with mud motor. Rigged up and ran Gyro for kickoff. Directional drilled and surveyed 14-3/4" hole from 2276' to 2497'. Ran gyro surveys at 2468' and 2497' to 'confirm Teleco tool. Teleco tool failure at 2497' due to babbit pieces from high pressure mud line. Trip for new tool. Made up new Teleco tool and ran in hole. 2714'/217' Completed running in to 2497'. Drilled 14-3/4" directional hole from 2497' to 2528' with mud motor. Ran Gyro survey. Drilled 14-3/4" directional hole from 2528' to 2714'. Problem with Teleco directional tool. Changed out surface equipment. Trip for new TelecO tool. 2910'/196' Directionally drilled and surveyed 14-3/4" hole from 2714' to 2868'. Trip to change from 9-5/8" to 7-3/4" mud motor. 7-3/4" motor failed after making 8' of hole. Trip for new motor. Drilled 14-3/4" hole from 2875' to 2910'. 3159'/249' Directionally drilled and surveyed 14-3/4" hole from 2910' to 3154'. Trip for new bit. Perform weekly BOPE test to Unocal specifications. Drilled from 3154' to 3159' and mud motor failed. Trip for BHA change. 3315'/156' Completed trip out with mud motor. Picked up rotary drilling assembly. Ran in and wiped ' . Drilled motor run from 2276 to 3159' 14-3/4 hole from 3159 -3169' mud motor failed. Trip for new motor. Drilled 14-3/4" hole from 3169' to 3315'. Background gas climbing. Weighted up to 72 pcf from 69+ pcf while drilling. Trip for locked up rotary drilling assembly. LEASE MCARTHUR RIVER UNOCAL DRILL',NG RECORD ALASKA REGION PAGE NO. 7 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 1/30/90 4012'/697' 1/31/90 4552'/540' 2/01/90 5112'/560' 2/02/90 5135'/23' 2/03/90 5135'/0' 2/04/90 5135'/0' 2/05/90 5135'/0' 2/06/90 5135,/0, DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Completed trip for BHA change. Ran in with locked-up rotary assembly. Had to work through the motor run. Drilled 14-3/4" hole from 3315' to 3910'. Ran Gyro survey. Made 10 stand short trip. Drilled 14-3/4" hole from 3910' to 4012'. Drilled 14-3/4" hole from 4012' to 4374'. Circulated out gas at 4213' and 4315'. CBU, check for flow, and pump dry job. Trip for bit and BHA change-had some drag from 4374' to 3719'. Changed bit and stabilizer above lead collar to 12-1/4" blade. Function tested rams. Ran in and tested Teleco at 2030'. Continued in to 4374'-hung shoe with stabilizer. Drilled from 4374' to 4552'. Drilled 14-3/4" hole from 4552' to 4666'. Circulated bottoms up for trip. Trip for new bit and BHA change. Ran in with locked-up assembly to 4640'. Spot reamed from 4640' to 4666'. Drilled from 4666' to 4851'. Good drill break from 4808' to 4851'. Circulated bottoms up to confirm D-1 coal (top of coal @ 4808'). Drilled from 4851' to 5008'. Circulated sample up to confirm D-2 coal (Top of coal @ 4976'). Drilled from 5008' to 5112'. Drilled from 5112' to 5135' (13-3/8" csg shoe picked by Kirk Kiloh-Development Geologist). Wiped hole from 5135' to 4200'. Spot ream back to bottom. Circulated bottoms up and wiped hole from 5135' to 4200'. Ran back in with no problem and circulated well for wireline logs. Trip for wireline logs. Rigged up Haliburton Logging Services. Logging. Continued running wireline logs. Ran selective formation tester (37 sets). Made cleanout run to 5130' - 5' of fill. Cleaned out to 5135'. Circulated well. Mixed and pumped dry job. Trip for underreamer. Ran in with underreamer to 1926'. Underreamer 14-3/4" hole to 17-1/2" from 1926' to 2497' Continued underreaming 14-3/4" to 17-1/2" from 2497' to 3546'. POH. Test BOPE as per Unocal test procedure. RIH. Underreamed 14-3/4" to 17-1/2" hole 3546'-3976'. Continued underreaming 14-3/4" to 17-1/2" hole 3976'-5135'. Circ well clean. POH. Changed pipe rams to 13-3/8". Set test plug and test stack against annular-OK. Rigged and ran 13-3/8" casing. Began having trouble at 2500'. Working and circulating 13-3/8" casing at 2780' at 2400 hrs. Circulated and worked casing at 2780'. Ran casing to 5128'. Had to circulate last 3 joints down. Circulated and worked casing while rigging up and testing surface cementing equipment to 4000 psi-OK. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 8 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 02/07/90 5135'/0' 02/08/90 5135'/0' 02/09/90 5135'/0' 02/10/90 5135'/0' 02/11/90 5145'/10' 02/12/90 5463'/318' 02/13/90 5569'/106' DETAILS OF OPERATION, DESCRIPTIONS &. RE~UL~S Completed cementing 13 3/8" casing with no 0returns to surface. Bumped plug with 3000 psi. Cement in place at 0100 hours. Ordered out wireline unit for temperature survey. Unit and crew arrived at 1300 hours. HLS unit had water in fuel system. Presure tested 16" x 13 3/8" annulus while working on wireline unit. Pumped away at 4 BPM with 1025 psi. Shutdown pump and pressure bled to 840 psi and stabilized. Wait on repair of HLS unit until 0100 hours. Run temperature survey from 5006' to surface. Rigged down HLS. Wait on boat to bring cement. Boat delayed due to heavy ice conditions. Perform maintenance work. Unload cement. Completed unloading cement. Mixed and pumped 650 sxs "G" cement with 2% CaCI~ to a slurry weight of 15.8 ppg. CIP at 0706 hours. This cement job was to squeeze between 16" and 13-3/8" casing strings. Started top job at 3 BPM with 1050 psi. Final rate at 3 BPM with 750 psi. Lifted 20" stack and landed 13 3/8" casing on slips in 16" WF casing head with 125K tension. Made rough cut on 13 3/8" casing. Nippled down and removed 20" stack from under the rig. Installed 16" x 13 5/8" 3M Cameron WF spool. Test casing spool to 1300 psi. Set in and nipple up 13 5/8!' 5M BOPE. Test BOPE to Unocal. specifications. Test 13 3/8" casing to 2700 psi against the blind rams. Tested 13 3/8" x 16" annulus to 1500 psi - no leak off. Prep to pick up drilling assembly. RIH with a 12-1/4" bit. Drilled plugs and float collar at 5032' and cleaned out cement to 5115'. Tested the 13-3/8" casing to 2700 psi. Drilled the shoe at 5128' and new hole to 5145' Circulated the hole clean and ran a leak o~f test. Leak off occurred at 0.85 psi/ft. Cleaned the surface system. Completed cleaning the mud system. Built mud volume. Drilled 12-1/4" hole from 5145' to 5424'. Observed a 6 bbl gain. Shut down the pump to check for flow, the well was flowing. Shut in the well and observed no pressure increase. Circulated bottoms up holding 200 psi back pressure. Shut down the pump and checked for flow, still flowing. Weighted up from 65 PCF to 71 PCF. Displaced the well with 71 PCF mud. Drilled 12-1/4" hole from 5424' to 5463' DPM. Circulated. POOH. Completed the trip out. RIH with a 12-1/4" bit and a mud motor. Drilled from 5463' to 5569'. POOH. RIH with a 12-1/4" bit. Reamed the motor run from 5450' to 5530'. LEASE MCARTHUR RIVER UNOCAL DRILLING' RECORD ALASKA REGION PAGE NO. 9 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 02/14/90 6366'/797' 02/15/90 6743'/377' 02/16/90 7000'/257' 02/17/90 7323'/323' 02/18/90 7636'/313' 02/19/90 7822'/186' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Completed reaming the motor run from 5530' to 5569' Drilled and surveyed 12-1/4" hole from ~569' to 6366' DPM. Circulated for short trip. Wipe hole from 6366' to 5780' DPM. Tight hole from 5900' to 5780' DPM. Swabbed in 5 bbl through this section while pulling up to 150K overpull. Kelly up and circulated bottoms up while working pipe from 5750' to 5820' DPM. Continued pulling to 13-3/8" shoe. RIH to 6286' DPM. Spot reamed from 6286' to 6366' DPM. Drilled 12-1/4" hole from 6366' to 6536' DPM. Circulate bottoms up for bit trip. Had some tight spots from 6536' to 6250' DPM. Down two hours to work on Kommey electrical controls. Changed bit and ran in to 13-3/8" shoe. Down 1 1/2 hours to work on drawworks brake linkage. Continued in to 6486' DPM. Reamed from 6486' to 6536' DPM. Drilled 12-1/4" hole from 6536' to 6743' DPM. Drilled 12-1/4" hole from 6743' to 7000' DPM, Torque was very high and last 10' drilled very slow. Circulated for bit trip. Pumped dry job and pulled out of hole. Lay down BHA. Repair Koomey unit and work on rotary table back break. Made up new BHA with Unocal tools. Ran into 6766' DPM and laid down 9 joints of bent drill pipe. Spot reamed from 6766' to 6810' DPM. Reamed underguage hole from 6810' to 7000' DPM. Drilled from 7000' ~to 7181' DPM. Circulated for bit trip. Pumped dry job and pulled out of hole. Changed bit and blade on stabilizer above lead collar to !2-1/8" OD. Ran in hole and changed out 66 ~joints of "E" drill pipe for "S-135" drill pipe. Reamed from 7120' to 7181' DPM. Drilled from 7181' to 7323' DPM. Continued drilling 12-1/4" hole from 7323' to 7420' DPM. Tight spot at 7368' DPM. Drilled from 7420' to 7636' DPM. Drilling very rough with high torque. Cutting a lot of 1-2' coal stringers. Ran bit weight as low as 5 to 10 K. Bit started running with steady torque and hole angle had dropped to 20.9 degrees. Circulated bottoms up and checked for flow. Pump dry job and pulled out for new bit and bottomhole assembly. Laid down the balance of "E" drill pipe, changed Teleco tool due to run hours, and changed blade on stabilizer above lead collar to 11-1/2" OD. Pulled wear bushing and set test plug. Test BOPE to Unocal specifications. Continued testing BOPE. Made up bit and BHA. Ran in hole picking up "S-135" drill pipe. Filled pipe at shoe. Reamed from 7556' to 7636' DPM. Drilled 12-1/4" hole from 7636' to 7822' DPM. Very inconsistent slow drilling (8-10 ft/hr) with sections of high torque. Torque started running a steady 550 amps as compared to the normal 325 amp reading. Circulated bottoms up and checked well for flow. Pumped dry job and tripped for a new bit. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 10 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 02/20/90 8027'/205' 02/21/90 8300'/273' 02/22/90 8799'/499' 02/23/90 9076'/277' 02/24/90 9415'/339' 02/25/90 9566'/151' 02/26/90 9910'/344' 02/27/90 10,199/289' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued pulling out of hole. Made up new bit and jars. Ran in to shoe and filled pipe. Continued in to 7800' and reamed to 7822' DPM. Drilled 12-1/4" hole from 7822' to 8027' DPM. Started losing pump pressure. Checked surface equipment. Pulled out wet looking for a washout. Found washout 12" below box on joint #37. Continued out and changed out to 10-1/2" OD stabilizer above lead collar. Made up new bit. Ran in to shoe and filled pipe. Continued in hole. tight spot at 5712' DPM-worked through, same. Continued in to 7967' DPM. Reamed from 7967' to 8027' DPM. Drilled 12-1/4" hole from 8027' to 8223' DPM. Circulate bottoms up and check for flow. Trip for building assembly. Tight hole at 8149', 8122', 8070', 7808', and 7427'. Worked through at 75 to 100K over pickup weight. Made up BHA and ran in to 13-3/8" shoe. Filled pipe. Cut 90' off drilling line. Continued in to 8143' DPM-no tight hole. Reamed from 8143' to 8223' DPM. Drilled 12-1/4" hole from 8223' to 8300' DPM Drilled 12-1/4" hole from 8300' to 8799' DPM. Had very tight connections at 8410' and 8470'. Worked on mud properties and connections started to free up. Survey at 8763' MD showed 26.5~ of hole angle. Circulated bottoms up and tripped for BHA change. Trip out was smooth. Completed trip out for BHA change from 8799'. Made up BHA and new bit and ran in hole. Washed and reamed last 60' to bottom. Drilled 12-1/4!' hole from 7899' to 9076' DPM. Drilled and surveyed 12-1/4" hole from 9076' to 9175' DPM. Lost AC power - complete platform shutdown. Pulled bit 40' off bottom before losing DC power. Down one hour due to power failure. Drilled from 9175' to 9415' DPM. 'Drilled and surveyed 12-1/4" hole from 9415' to 9499' DPM. Pumped dry job and pulled out for bit change. Trip out had tight spots at 7516' DPM and 6545' DPM. Test BOPE to Unocal specifications. Made up bit and BHA and ran in hole. Drilled 12-1/4" hole from 9499' to 9566' DPM. Drilled and surveyed 12-1/4" hole from 9566' to 9910'. Drilled and surveyed 12-1/4" hole from 9910' to 10,199'. Circulated bottoms up. Pumped a dry job and POOH for a bit change. Saw a tight spot from 9641' - 9610'. The tight spot at 7516' was still there RIH with new BHA. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 11 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 02/28/90 10,199'/0' 03/01/90 10,199'/0' 03/02/90 10,199'/0' 03/03/90 10,199'/0' 03/04/90 10,349'/150' 03/05/90 10,470'/121' 03/06/90 10,664'/194' 03/07/90 10,917'/253' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued to trip in the hole. While laying the pipe down to ream to bottom stuck the string with the bit at 10,031'. Have free circulation. Have jar action. Jarred down and torqued in an attempt to get free. Spotted 50 bbl mineral oil and EZ-spot. Left 25 bbls in the drill pipe. Let the oil pill soak while working and jarring the pipe. Continued working the stuck pipe. Tripping jars with 120K up and 40K down. RIH with wireline and established the freepoint at 9937' RIH and fired a back off at 9906'. Backed off at 9906' Worked the pipe and circulated. Isolated the mineral oil contaminated mud. Continued to circulate and rebuild mud volume. POOH for fishing tools. Had a lot of trouble getting out of the hole. Tight spots at 8660'-7450'. Had to back ream to get through the spot at 7450'. Continued to POOH. RIH with a clean out assembly. RIH and spot reamed from 9785'-9848'. Continued spot reaming from 9848' to 9906' (TOF). The hole seemed to be underguaged from 9836' to 9906'. POOH for a fishing assembly. RIH with a fish assembly. Engaged the fish at 9906'. Jarred for 30 minutes. Some movement was seen and continued to work the fish. POOH with the fish. Continued POOH with the fishing assembly. Recovered all of the. fish. RIH with a drilling assembly. Reamed from 9879' to 10,199'. Saw some drag from 10,130' to 10,199'. Drilled 12-1/4" hole from 10,199' to 10,349'. Drilled 12-1/4" hole from 10,349' to 10,363'. Added 5.5#/bbl soltex to the mud system. POOH for a bit change. Pulled wear bushing. Set test plug. Test BOPE and choke manifold to Unocal specifications. Pulled test plug and set wear bushing. Ran in hole to 10,281'. Reamed from 10,281' to 10,366' DPM. Drilled from 10,366' to 10,470'. Drilling rate varied from 4' to 54'/hr. with quite a bit of intermittent torque. Drilled 12-1/4" hole from 10,470' to 10,476' DPM. Drilling rate slowed down with intermittent torque. Checked for flow and pumped dry job. Trip for bit. Bit in good condition with 2 inserts broken. Reran same bit and BHA to 10,476' DPM. Drilled from 10,476' to 10,664' DPM. Drilled 12-1/4" hole from 10,664' to 10,917' DPM. Circulated bottoms up and pumped dry job. Trip for bit. Hole in good shape. REC EiVED JUN -- 6 1990 oJJ & Gas Cons, (;ommission Anchorage LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 12 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/08/90 03/09/90 03/10/90 03/11/90 03/12/90 03/13/90 03/14/90 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 11,081'/164' Finished trip out of hole. Changed bit and one stabilizer blade. Twisted pin off Bowen down jars during make up. Changed out top stabilizer and laid down jars. Ran in to 10917' DPM with no problems. Drilled 12-1/4" hole from 10,917' to 11,081' DPM. 11,267'/186' Drilled 12-1/4" hole from 11,081' to 11,267' DPM. Connections getting progressively tighter. Hole closed in while making connection. Broke out single and attempted to clean up tight hole - no good. Decided to log well at this depth. Pulled to 13-3/8" shoe. First 8 singles were tight. Tight hole from 8368' to 8182' DPM. Balance of trip good. 11,267'/0' Ran in to 11,267' DPM from 13-3/8" shoe. Trip in was good except for last 20'. Hole tight and trying to pack off. Circulated well clean. Trip out for open hole logs. Rigged up HLS. Ran in with DIL/sonic/GR to 11,200'. Stopped off bottom due to bad hole at 11,244'. Logged out-hole in good shape. Geologist did not like the SP curve. Ran second run with Density Neutron/GR/ Caliper/DIL/SP. 11,267'/0' Continued in to 11,200' with second suite of logs. Logged out-hole in good shape. Decided not to run RFT tool due to over balance conditions and hole washouts. Rigged down HLS. RIH with clean out BHA to 11,225'. Worked to 11,232' would not go deeper due to excessive drag (60-70K overpull). Circulate hole clean. POH with minor tight spots at 9812' and 8513'. 11,267'/0 POH. Changed rams to 9-5/8". Rigged and ran 262 jts 9-5/8" 47# N-80 and S-95 buttress. LT & C csg. Landed shoe at 11,232' and FC at 11,145'. Could not reciprocate pipe in safe operating limits of equipment (10 lines strung) circulated casing. 11,267'/0 Pumped 50 bbls of 12 ppg dual spacer preflush. Dropped bottom plug. Began mixing lead cement slurry - 1710 sxs "G" mixed with 1.5% CFR-3L and 0.12% LWL. WT = 14.2 ppg. Howco could not maintain wt. Aborted job and circulated out 400 sxs of poorly mixed cement. Circulate while waiting on additional cement and additives. Repaired cement unit. Pumped 50 bbls dual spacer. Began pumping lead slurry. 11,267'/0 Pumped 1710 sxs "G" cement mixed with 1.5% prehydrated gel, 0.50% Halad 344L, 0.2% CFR-3L, and 0.20% LWL. Wt. = 14.2 ppg, 1.52 CF/sx. Followed lead with tail slurry - 1000 sxs "G" dry blended with 0.50% Halad 344, 0.25% CFR-3, 0.10% LWL and 0.2% Super CBL. 15.6 ppg wt, 1.18 CF/sx yield. CIP at 313 hrs. Bumped plugs. Plugs and floats held. WOC. Installed DCB spool and pressure tested secondary seal to 2600 psi for 30 minutes. Nipple up BOPE. Set test plug and test BOPE to Unocal specifications. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 13 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/15/90 ll,267'TD/ll,143'ETD 03/16/90 ll,267'TD/ll,143'ETD 03/17/90 ll,267'TD/ll,143'ETD 03/18/90 ll,267'TD/ll,143'ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Finishing testing BOPE. Pulled test plug and set wear bushing. Laid down 12-1/4" clean out assembly. Made up 8-1/2" clean out assembly and ran in to 11,143' DPM. Changed well over to FIW and cleaned pits. Rigged up HOWCO and pressure tested 9-5/8" casing against the pipe rams to 4800 psi. Slow leak on DCB spool-repaired same. 13-3/8" x 9-5/8" annulus on slight vacuum while testing casing. Held pressure on 9-5/8" casing for 30 minutes - held good. Circulated well with FIW. Trip for cement bond log. Rigged up wireline. Ran CBL from 11,137' to 4000' WLM. Ran PET from 11,137' to 7500' WLM. Ran gyro from 11130' to surface at 100' stations. Made up cement retainer on wireline and ran in hole. Tied in and set retainer at 11,070' CBL as a bottom to squeeze against. Perforated the base of West Foreland with 4 HPF from 11,042' to 11,044' CBL. Made up retainer on drill pipe and ran in to 10,973' DPM. Set retainer and pressure tested equipment. Establish 0.75 BPM at 4900 psi injection rate. Squeezed perforations with 116 sxs cement as per squeeze report #1. Cement in place at 1215 hrs. Reversed out excess cement and tripped for retainer. Rigged up wireline and ran in with retainer. Tie in and set retainer at 10,480' CBL as a bottom to squeeze against. Perforated the top of West Foreland with 4 HPF from 10,455' to 10,457' CBL. Made up retainer on drill pipe and ran in hole. Set retainer at 10,415' DpM and pressure tested equipment. Established 1 BPM at 4700 psi injection rate. Squeezed perforations with 104 sxs cement as per squeeze report #2. Cement in place at 0350 hrs. Pulled to 10,270' DPM and reversed clean. Rigged up wireline. Ran in and perforated the base of Hemlock HB-4 with 4 HPF from 10,218' to 10,220' CBL. Made up retainer on drill pipe and ran in to 10,190' DPM. Set retainer and pressure tested equipment. Established 1 BPM at 5150 psi injection rate. Squeezed perforations with 63 sxs cement as per squeeze report #3. Cement in place at 1450 hrs. Pulled up to 10,160' DPM and reversed drill pipe clean. Rigged up wireline. Ran in and perforated the top of Hemlock HB-4 with 4 HPF from 10,111' to 10,113' CBL. Made up retainer on drill pipe and ran in to 3000' DPM. Slipped and cut 89' off drilling line. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 14 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/19/90 Set ll,267'TD/ll,143'ETD 03/20/90 ll,267'TD/ll,143'ETD 03/21/90 ll,267'TD/ll,143'ETD 03/22/90 ll,267'TD/ll,143'ETD 03/23/90 ll,267'TD/ll,143'ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued in with retainer to 10,055' DPM. retainer and pressure tested equipment. Established 0.5 BPM at 5300 psi injection rate. Squeezed preforations with 78 sxs cement as per squeeze report #4. Cement in place at 0405 hrs. Pulled up and reversed drill pipe clean. Trip for perforating gun. Rigged up wireline. Ran in and perforated the base of Hemlock HB-1 with 4 HPF from 9934' to 9936' CBL. Made up retainer on drill pipe and ran in to 9900' DPM. Set retainer and pressure tested equipment. Established 1.5 BPM at 4600 psi injection rate. Squeeze perforations with 133 sxs cement as per squeeze report #5. Cement in place at 1715 hrs. Pulled out of retainer and reVersed out excess cement. Trip for perforating gun. Rigged up wireline. Ran in and gun stopped at 9871' CBL (11' high). Pulled out with wireline. Made up 8-1/2" clean out assembly and ran in hole. Continued in and taggDd up at 9892' DPM. Cleaned out from 9892' DPM to 9914' DPM. Circulated well clean. Trip for perforating gun. Rigged up wireline. Ran in and shot holes for top of Hemlock HB-1 isolation squeeze from 9880' to 9882' CBL. Made up EZSV retainer on 5" drill pipe and ran in to 9860' DPM. Set retainer and pressure tested equipment. Established a 0.75 BPM at 5200 psi injection rate. Squeezed perforations with 37 sxs cement as per squeeze report #6. Unstabbed and reversed out excess cement. Trip for clean out assembly. Laid down 28 joints drill pipe for clean out. Made up 8-1/2" drilling assembly and ran in hole. Continued in and tagged at 9857' DPM. Cleaned out firm cement to retainer at 9860' DPM. Drilled on retainer for three hours without making any hole. Trip for new bit. Drilled retainers at 9860' DPM, 10,054' DPM, and 10,190' DPM. First two retainers had good cement below. Retainer at 10,190' DPM had no cement to 10,275' DPM and firm cement to 10,416' DPM. Circulated well clean and trip for new bit. Completed trip out for a new bit. Changed bit and ran in to 10,416' DPM. Drilled retainer at 10,416' DPM. Had good cement below retainer. Drilled retainer at 10492' DPM. No cement below the retainer. Drilled 50% of retainer at 10,973' DPM and the bit quit. Trip for new bit. Ran in with new bit and completed drilling retainer at 10,973' DPM. Had good cement below retainer. Drilled retainer at 11,070' DPM. Pushed junk to ETD at 11,143' DPM. Circulated well clean. Trip for casing scraper. Ran in with scraper to 11,143' DPM. Changed well over to clean FIW (18 NTU). Trip for CBL log. Rigged up HLS and ran in with CBL/CCL/VDL/GR to 11,129' ETD. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 15 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/24/90 ll,267'TD/ll,143'ETD 03/25/90 ll,267'TD/ll,143'ETD 03/26/90 ll,267'TD/ll,143'ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Finish running cement bond log from 11,129' to 8100' WLM. Rigged down HLS. Made up TCP guns for the West Foreland and ran in hole. Left last 4780' of drill pipe dry for under balance. Spotted guns near depth and ran GR/Neutron/CCL correlation log. Set packer and ran confirmation log. Install and test surface lines to 5000 psi. Cycled "Omni" valve open and dropped firing bar. Guns did not fire. Rigged up HLS and ran in to recover drop bar. Found firing bar on top of "Omni" valve. "Omni" valve did not open. Recovered drop bar (left bottom 1' of bar and 5 wheels in the hole). Rigged down HLS. Cycled "Omni" valve open. Rigged up HLS and ran in hole to confirm "Omni" valve was open. Rigged down HLS. Shot fluid level - had 420' of rise in 98 minutes. Fired guns using APR firing head at 0059 hours. Perforate West Foreland at 8 HPF with 25 gram changes as follows: WF-2, 10,525'-10,565'; WF-3, 10,680'-10,770'; WF-5, 10,833'-10,888'; WF-6, 10,915'-10,972'; WF-7, 10,993'-11,040'. Ran "FAST" reservoir analysis. Cycled "Omni" valve to reversing position and reversed drill pipe clean. Cycled "Omni" valve open and drill pipe went on a vaccum. Mixed sized salt pill. Fluid losses stopped while mixing the pill. Pulled packer loose and circulated well. Pulled out and laid down guns. Packing element on RTTS was in bad shape. Ran weekly BOPE test. Ran in with bit and casing scraper to 11,143' DPM ETD and circulated well clean. Pulled out of hole with casing scraper. Made up RTTS packer on drill pipe and ran in to 10,473' DPM. Rigged up Dowell and tested lines to 5000 psi. Injected 1.8 BPM of FIW at 2490 psi into the West Forland. Started acid treatment at 0945 hours with RTTS bypass open to spot acid at tool. Active system filled up and started dumping clean FIW returns. Received an unexpected slug of oil and put less than 1/2 bbl into the inlet. Closed bypass and bullheaded the balance of the treatment. Pumped acid as follows: 1050 gal 7.5% HCL; 1575 gal 6% HCL/1.5% HF; 4200 gal FIW; 1050 gal 7.5% HCL w/0.1 ppg Sodium Benzoate diverter; 1575 gal 6% HCL/1.5% HF; 4200 gal FIW. Displaced acid with 300 bbl FIW. Acid in place at 1320 hours. Final displacement rate 3.58 BPM at 2300 psi. Well went on a vacuum when pumps were shutdown. Mixed and pumped a sized salt pill to control fluid losses. Trip for permanent packer. Made up Otis hydraulic set "BWH" permanent packer on drill pipe and ran in hole. Set packer at 10,375' DIL (10,382' DPM). LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 16 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/27/90 ll,267'TD/ll,143'ETD 03/28/90 ll,267'TD/ll,143'ETD 03/29/90 ll,267'TD/ll,143'ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Pulled out of hole with packer setting tool. Made up Otis "JP" plug. Ran in and set plug in packer. Spotted 6 sxs sand on top of packer at 10,375' DIL. Pulled to 9900' DPM and waited 30 minutes for sand to settle. Ran in to tag plug and drill pipe was backflowing. Circulated bottoms up at 10,000' DPM. Continued in and tagged sand at 10,363' DIL. Trip for bit and casing scraper. Rigged up and displaced well with clean FIW. Pumped 1200 bbl to shore. Water quality at flowline was 250 NTU. Trip for TCP guns. Made up TCP guns and ran in hole. Ran enough dry pipe to allow for a 500 psi drawdown. Rigged up surface lines and HLS wireline. Ran correlation log and set packer. Ran confirmation log. Opened "Omni" valve and confirmed valve was open with wireline. Rigged down wireline. Perforated Hemlock with 8 HPF, 60° phasing, 25 gram "Big Hole" charges as follows: HB-1, 9892'-9926' DIL; HB-4, 10,128'-10,208' DIL. Fired guns at 1241 hours. Performed "FAST" reservoir analysis. Pulled packer loose and reversed drill pipe clean. Ran in and set packer at 9950' DPM. Injected 5 bbls FIW into HB-4 at 0.5 BPM with 3500 psi. Pulled up and reset packer at 9831' DPM. Injected 10 bbls FIW into both HB-1 and HB-4 at 0.6 BPM with 3500 psi. Pulled packer .loose and pulled out of hole. Laid down perforating guns. Made bit and scraper run to 10,367' DPM. Pulled to !0,350' DPM and circulated well clean. Trip for RTTS packer and retrievable bridge plug. Ran in and set RBP at 10,310' DPM. Pulled up and set RTTS with tail at 10,117' DPM. Rig up Dowell for acid stimulation of HB-4. Test surface lines to 6000 psi. Test drill pipe against perforations to 2000 psi. Establish a 0.5 BMP injection rate with 4000 psi. into HB-4 perforations from 10,128'-10,208' DIL. Pumped acid as follows: 28.57 BBL 7-1/2% HCL; 95.24 BBL 6% HCL/1-1/2% HF; 142.85 BBL FIW w/additives; 300 BBL FIW. Final rate was 3 BPM at 3500 psi. Unset RTTS and recover RBP. Reset RBP at 10,010' DPM. Pulled up and set RTTS with tail at 9870' DPM. Rig up and retest surface lines to 6000 psi. Test drill pipe to 2000 psi. Test annulus to 2500 psi. Establish a 0.5 BPM injection rate with 4000 psi into HB-1 perforations from 9892'-9926' DIL. Pumped acid as follows: 12.14 BBL 7-1/2% HCL; 40.47 BBL 6% HCA/I-i/2% HF; 81 BBL FIW w/additives; 300 BBL FIW. Final rate was 2 BPM at 3600 psi. JUN - 6 1990 Alasga 01; & Gas Cons. Commission Anchorage LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 17 of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 03/30/90 ll,267'TD/ll,143'ETD 03/31/90 ll,267'TD/ll,143'EDT 04/01/90 ll,267'TD/ll,143'ETD 04/02/90 11267'TD/ll143'ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Rigdown Dowell. Retrieve RBP. Trip for "JP" plug retrieving tool. Ran in to 10,353' DPM. Washed down to 10,382' DPM and latched plug trip to check recovery. Laid down plug and retrieving tool. Ran in 5" drill pipe. Pulled out laying down drill pipe. Continued laying down drill pipe and tools. Pulled wear bushings. Changed top pipe rams to 3-1/2" dual and test stack. Rig to pick up injection string. Hydrotested the first 3000' of injection string in hole. Continued running dual injection string. Space out and make up tubing hangers. Stabbed into permanent packer at 10,375' DIL. Pressure tested seals against formation to 1000 psi. Pulled out of seals and changed over to packer fluid. Stabbed back into permanent packer and retested seals. Set dual hydraulic packer. Landed, locked down, and packed off hanger. Pressure tested annulus to 3000 psi for 30 minutes. Installed back pressure valves. Rigged down running equipment. Nipple down BOPE. Continued nippling down BOPE. Install dual block injection tree. Test to 5000 psi. Install wing valves. Turned well over to production. Witness of mechanical integrity test waived by Lonnie Smith of AOGCC. Strung blocks back to 8 lines. Prepare to skid rig. Released riq ~55 from TBUS G-40 at 1200 hours on 4/2/90. UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 18 of LEASE MCARTHUR RIVER WELL NO. G-40 FIELD GRAYLING DATE E.T.D. DE~AILS OF OPERATION, DESCRIPTIONS & RESULTS 04/20/90 COMMENCE OPERATIONS ON TBUS G-40, 0000 11,267' TD/ll,143' ETD HOURS. Rig up on well. Rig up Myers Wireline and install choke in short string. Injected down short string observing 9-5/8" x tubing annulus. Annulus pressure increase to 775 psi in one hour. Shut down injection and bled down well. Shifted open "XA" sleeve in short string at 9783'. Shifted open "XA" sleeve in long string at 10,339'. Pumped two tubing volumes down long string taking returns up the short string. Shut in short string and pumped down long string taking returns up the annulus. Shut down pumps. Well flowing at 5 gpm. Shut well in and pressure built to 60 psi. Ordered NaCl weight material. Rigged up Schlumberger on G-22 for injection survey. 04/21/90 11,267' TD/ll,143' ETD Increased fluid weight from 8.4 ppg to 9.0 ppg. Circulated around 9.0 ppg fluid. Well dead. Installed BPV's and removed tree. Installed and tested BOPE. Rig up tubing handling tools. 04/22/90 11,267' TD/ll,143' ETD Pulled Long String to 170 K and dual packer released~ Well was out of balance. Pumped 250 bbls down long string taking return~ up the short string. Well was out of balance on short string. Mixed and pumped a 25 bbl 9.7 ppg dry job down each string. Pulled and stood back dual 3-1/2" injection string. Sent packer, seal assembly, XA sleeves, and ball catcher to Otis to be redressed. Perform rig maintenance while waiting for equipment to be redressed. LEASE MCARTHUR RIVER UNOCAL DRILLING RECORD '~'~ PAGE NO. REGION WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 04/23/90 11,267' TD/ll,143' ETD 04/24/90 11,267' TD/ll,143' ETD 04/25/90 11,267' TD/ll,143' ETD 04/26/90 11,267' TD/ll,143' ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued rig maintenance. Ran dual 3-1/2" injection string with standing valves in the XA sleeves. Tested both strings with 14 stands above dual packer to 3500 psi. Ran an additional 17 stands on each side. Attempted to test short string-no good. Pulled 17 stands, testing every 5 stands-still leaking. Determined standing valve was leaking in short string. Continued to run tubing. Rig up wireline. Pulled standing valves from long and short strings. Continued to run tubing. Spaced out tubing and installed hangers with landing joints. Tested long string packer seals to 800 psi. Ran and set PX plug and prong in XA sleeve above dual packer. Rig to pressure test short string. Attempted twice to pressure test short string to 3400 psi-no good. Pulled PX plug and replaced packing. Reran plug. Installed tubing hangers. Rig to test at top of hangers. Tested short string to 3500 psi for 30 minutes. Rigged up wireline on long string. Attempt to set PX plug in XA sleeve. Plug would not go below 4962' WLM. Picked up landing joints and spaced out to set dual packer. Injected into formation on long string side at 2-1/4 BPM with 1500 psi with no returns to Surface. Change annulus over to packer fluid. Set dual packer as per tubing detail. Landed hanger with 50 K slackoff on dual packer. Locked down hanger and packed same with plastic. Perform mechanical integrity test against dual packer and hanger to 3000 psi for 30 minutes. Laid down landing joints and installed BPV's. Nipple down BOPE. Nipple down BOPE. Install and test tree to 5000 psi for 30 minutes. Pull back pressure valves and install injection lines. Change out bad choke on long string. RELEASED RIG AT 0930 HRS, 4/26./90. A 20" ( l"wall)j 424' 16", 75#, J K- 55, BU'Fi' 1926' MD 1926' TVD 15-5/8", K-55 & S-80, BUTT / @ 5128' MD 4973' TVD 1 4'.- Dc; 5 D N-80 & S-95 11143' MD BUTT F @ 11232' MD TD 10606' TVD 11267' MD xB C 10638' TVD D) 16', ?~. ~-~5 ~1NG AT 3-112' OTIS '%.A' SLZDZ#6 S~£~'%'£ AT 9761.67' 3-112' OTZ$ 'XA' ~LZDING S~£~ AT 10348.34' R~h~R¥ OT15 RD~ DDA.~ ~¥DRADL/C PACKER TOP OF PKR (;,,ON~ .%'TRZNG) AT 979~. 09' ~'~0~ OF PF~R OTIS BW]B PERM~A-DRZT.~* PACE£E AT ~tA~-TBR0 SF. JLT. ASS¥ FRO~ 103B£.27' ~ 10395.07' 0312019D 03/24/90 ~3/24/90 0~/24/90 WELL TBUS G-40 COMPLETION ( 4/26/90 ') UNION OIL COMPANY OF CALIFORNIA (dbe UNOCAL) DRAWN' DAC SCALE: NONE DATE: 5-3-90 Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713./461-3146 Fax: 713,;461-0920 March 22, 1990 Mr. Don Chudaner Unocal 909 West 9th Ave. Anchorage, Alaska, 99501 Re: Trading Bay Unit, Well G-40 Leg No. 1, Conductor No. 25 Kenai Borough, Cook Inlet, Alaska Dear Mr. Chudaner: Enclosed please find one (1) original and six (6) copies of the completed survey of Well No. G-40. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Gary Uttecht Vice President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway L ICROFIL ED ~ c~ SURVEY REPOR{} ~ I {~ ] i~ j~ UNOCAL TRADING BAY UNIT, WELL G-40 LEG NO.1, CONDUCTOR NO. 25 KENAI BOROUGH, COOK INLET, ALASKA MARCH 22, 1990 A Gyrodata Directional for Survey UNOCAL TRADING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 KENAI BOROUGH, COOK INLET, ALASKA Date Run: 16-MAR-90 19:10:57 Job Number: AK0390G218 Surveyor: AL KUDRLE Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 50min 30sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: S 22deg 31min 48sec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata JNOCAL -- gRADING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 (ENAI BOROUGH, COOK INLET, ALASKA lob Number: AKO390G218 Directional Survey Page MEAS VERT SUB-SEA INCL BORE HOLE DEPTH DEPTH DEPTH BEARING ft ft ft deg min deg min .0 .0 .0 100.0 100.0 100.0 200.0 200.0 200.0 300.0 300.0 300.0 400.0 400.0 400.0 500.0 500.0 500.0 600.0 600.0 600.0 700.0 700.0 700.0 800.0 800.0 800.0 900.0 900.0 900.0 1000.0 1000.0 1000.0 1100.0 1100.0 1100.0 1200.0 1200.0 1200.0 1300.0 1300.0 1300.0 1400.0 1400.0 1400.0 1500.0 1499.9 1499.9 1600.0 1599.9 1599.9 1700.0 1699.9 1699.9 i800.0 1799.9 1799.9 1900.0 1899.9 1899.9 2000.0 1999.9 1999.9 2100.0 2099.9 2099.9 2200.0 2199.9 2199.9 2300.0 2299.9 2299.9 2400.0 2399.9 2399.9 VERT DOG-LEG SECTION SEVERITY ft deg/100' HORIZONTAL COORDINATES feet 0 0 N 0 0 E .0 .00 .00 N GYRODATA SURVEY RUN IN 9 5/8" CASING MEASURED DEPTHS REF TO RIG RKB EVEL 103 FEET TO MSL 0 28 S 18 19 E .3 .46 .38 S 0 46 S 9 23 E 1.2 .32 1.43 S 0 45 S 8 36 E 2.3 .03 2.74 S 0 46 S 6 li E 3.4 .04 4.04 S 0 20 S 7 1 E 4.3 .42 4.99 S 0 15 S 6 28 W 4.7 .11 5.50 S 0 20 S 54 22 W 5.2 .25 5.93 S 0 19 S 45 54 W 5.7 .05 6.30 S 0 20 S 66 45 W 6.2 .12 6.61 S 0 22 S 71 24 W 6.6 .04 6.83 S 0 26 N 69 14 W 6.9 .28 6.82 S 0 30 N 28 19 W 6.6 .34 6.29 S 0 29 N 29 59 W 6.1 .03 5.54 S 0 29 N 32 6 W 5.6 .02 4.81 S 0 33 N 52 6 W 5.2 .19 4.14 S 0 21 N 72 17 W 5.1 .25 3.78 S 0 19 N 89 19 W 5.3 .11 3.68 S 0 26 S 79 44 W 5.6 .13 3 ~ S 0 27 N 86 39 W 5.9 .11 3: S 0 23 N 58 9 W 6.0 .22 3.57 S 0 28 N 59 13 W 5.9 .09 3.18 S 0 15 N 86 52 W 5.9 .27 3.00 S 0 31 S 75 38 W 6.2 .28 3.06 S 3 28 S 49 45 W 8.9 3.01 4.64 S .00 E .13 E .39 E .59 E .76 E .87 E .87 E .62 E .18 E .29 W .87 W 1.55 W 2.15 W 2.57 W 3.01 W 3.61 W 4.31 W 4.89 W 5.54 W 6.30 W 6.99 W 7.62 W 8.22 W 8.88 W 11.94 W CLOSURE DISTANCE BEARING f t deg ~5~-~ .0 N 0 0 E .4 S 18 19 E 1.5 S 15 4 E 2.8 S 12 12 E 4.1 S 10 40 E 5.1 S 954E 5.6 S 9 1E 6.O S 5 58 E 6.3 S 1 41E 6.6 S 2 30 W 6.9 S 7 13 W 7.0 S 12 48 W 6.6 S 18 53 W 6.1 S 24 54 W 5.7 S 32 1W 5.5 S 41~: 5.7 S 48 6.1 S 53 1 {0 6.7 S 55 59 W 7.3 S 59 1W 7.8 S 62 57 W 8.3 S 67 21 W 8.8 S 69 58 W 9.4 S 70 59W 12.8 S 68 46 W A Gyrodata JNOCAL FRADING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 KENAI BOROUGH, COOK INLET, ALASKA Job Number: AK0390G218 Directional Survey Page MEAS VERT SUB-SEA INCL BORE HOLE DEPTH DEPTH DEPTH BEARING ft ft ft deg min deg min 2500.0 2499.5 2499.5 5 52 S 45 51 W 2600.0 2598.8 2598.8 8 10 S 42 34 W 2700.0 2697.6 2697.6 9 36 S 45 46 W 2800.0 2795.8 2795.8 11 55 S 48 11 W 2900.0 2893.1 2893.1 14 42 S 49 16 W 3000.0 2989.0 2989.0 18 18 S 44 13 W 3100.0 3083.4 3083.4 20 3 S 36 23 W 3200.0 3177.2 3177.2 20 35 S 27 58 W 3300.0 3270.7 3270.7 20 51 S 19 9 W 3400.0 3364.1 3364.1 21 9 S 18 29 W 3500.0 3457.4 3457.4 20 58 S 18 19 W 3600.0 3550.8 3550.8 20 59 S 17 46 W 3700.0 3644.2 3644.2 20 57 S 16 58 W 3800.0 3737.6 3737.6 20 42 S 16 22 W 3900.0 3831.3 3831.3 20 21 S 16 9 W 4000.0 3925.0 3925.0 20 31 S 15 40 W 4100.0 4018.7 4018.7 20 29 S 15 15 W 4200.0 4112.5 4112.5 20 4 S 14 5 W 4300.0 4206.4 4206.4 19 58 S 13 1 W 4400.0 4300.2 4300.2 20 34 S 13 5 W 4500.0 4393.4 4393.4 22 1 S 13 20 W 4600.0 4485.7 4485.7 23 19 S 13 13 W 4700.0 4577.3 4577.3 24 1 S 13 15 W 4800.0 4668.9 4668.9 23 6 S 12 23 W 4900.0 4761.1 4761.1 22 27 S 12 12 W VERT DOG-LEG SECTION SEVERITY ft deg/100' 16.2 27.6 41.9 58.9 79.6 105.4 136.7 170.9 206.2 242.0 277.8 313.5 349.1 384.5 419.3 454.0 488.8 523.1 556.9 591.1 626.9 665.0 704.6 744.0 782.1 2.43 2.32 1.52 2.35 2.80 3.86 3.11 2.97 3.13 .39 .19 .20 .29 .33 .35 .23 .15 .58 .38 .61 1.45 1.30 .69 .97 .66 HORIZONTAL COORDINATES feet 10.10 S 17.96 W 18.86 S 26.48 W 29.93 S 37.24 W 42.66 S 50.88 W 57.85 S 68.18 W 77.29 S 88.85 W 102.32 S 110.08 W 131.68 S 128.55 W 164.07 S 142.68 W 197.99 S 154.24 W 232.09 S 165.58 W 266.13 S 176.67 W 300.28 S 187.35 W 334.32 S 197.54 W 367.98 S 207.35 W 401.56 S 216.92 W 435.32 S 226.26 W 468.84 S 235.04 W 502.12 S 243.06 W 535.86 S 250.88 W 571.2~ S 259.17 W 608.73 S 268.02 W 647.80 S 277.21 W 686.76 S 286.07 W 724.59 S 294.31 W CLOSURE DISTANCE BEARING ft deg n_!i~n~ 20.6 S 60 .J9 W 32.5 S 54 33 W 47.8 S 51 13 W 66.4 S 5O 1 W 89.4 S 49 41 W 117.8 S 48 59 W 150.3 S 47 6 W 184.0 S 44 19 W 217.4 S 41 1W 251.0 S 37 55 W 285.1 S 35 30 W 319.4 S 33 35 W 353.9 S 31 58 W 388.3 S 30 35 W 422.4 S 29 24 W 456.4 S 28 23 W 490.6 S 27 28~[~. 524.5 S 26~' 557.9 S 25 591.7 S 25 5 W 627.3 S 24 24 W 665.1 S 23 46 W 704.6 S 23 10 W 744.0 S 22 37 W 782.1 S 22 6 W A Gyrodata Directional Survey JNOCAL ~RADING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 iENAI BOROUGH, COOK INLET, ALASKA ~ob Number: AK0390G218 Page blEAS VERT SUB-SEA INCL BORE HOLE DEPTH DEPTH DEPTH BEARING ft ft ft deg min deg min 5000.0 4853.6 4853.6 22 12 S 10 58 W 5100.0 4946.5 4946.5 21 18 S 10 10 W 5200.0 5039.6 5039.6 21 44 S 10 8 W 5300.0 5131.9 5131.9 23 25 S 10 54 W 5400.0 5223.4 5223.4 24 12 S 11 6 W 5500.0 5314.6 5314.6 24 15 S 16 31 W 5600.0 5405.5 5405.5 24 53 S 19 49 W 5700.0 5496.4 5496.4 24 23 S 19 27 W 5800.0 5587.5 5587.5 24 28 S 19 8 W 5900.0 5678.8 5678.8 23 33 S 18 48 W 6000.0 5770.5 5770.5 23 28 S 19 5 W 6100.0 5862.4 5862.4 22 59 S 18 45 W 6200.0 5954.5 5954.5 22 46 S 19 10 W 6300.0 6046.7 6046.7 22 59 S 19 7 W 6400.0 6138.6 6138.6 23 21 S 19 16 W 6500.0 6230.6 6230.6 22 47 S 19 44 W 6600.0 6323.0 6323.0 22 17 S 19 16 W 6700.0 6415.6 6415.6 21 57 S 19 12 W 6800.0 6508.2 6508.2 22 23 S 19 52 W 6900.0 6600.8 6600.8 22 9 S 19 37 W 7000.0 6693.1 6693.1 23 2 S 20 8 W 7100.0 6785.1 6785.1 23 4 S 20 7 W 7200.0 6877.2 6877.2 22 55 S 19 57 W 7300.0 6969.3 6969.3 22 41 S 20 12 W 7400.0 7061.7 7061.7 22 18 S 19 22 W VERT DOG-LEG SECTION SEVERITY ft deg/100' 819.3 .53 855.6 .94 891.4 .44 929.0 1.71 968.5 .79 1009.1 2.22 1050.5 1.51 1092.1 .51 1133.4 .15 1174.1 .92 1213.9 .14 1253.2 .51 1292.0 .26 1330.8 .22 1370.1 .36 1409.2 .59 1447.5 .53 1485.1 .33 1522.8 .50 1560.6 .26 1599.0 .92 1638.1 .04 1677.1 .17 1715.9 .25 1754.1 .49 HORIZONTAL COORDINATES feet 761.79 S' 301.94 W 798.21 S 308.73 W 834.32 S 315.20 W 872.06 S 322.21 W 911.69 S 329.91 W 951.53 S 339.71 W 991.03 S 352.67 W 1030.28 S 366.68 W 1069.32 S 380.34 W 1107.80 S 393.57 W 1145.54 S 406.52 W 1182.84 S 419.31 W 1219.61 S 431.94 W 1256.34 S 444.69 W 1293.50 S 457.63 W 1330.42 S 470.70 W 1366.54 S 483.49 W 1402.10 S 495.90 W 1437.66 S 508.51 W 1473.31 S 521.31 W 1509.44 S 534.37 W 1546.21 S 547.85 W 1582.91 S 561.23 W 1619.30 S 574.53 W 1655.29 S 587.48 W CLOSURE DISTANCE BEARING ft deg ~im, 819.4 S 21 J7 W 855.8 S 21 9 W 891.9 S 20 42 W 929.7 S 20 17 W 969.6 S 19 54 W 1010.4 S 19 39 W 1051.9 S 19 35 W 1093.6 S 19 35 W 1134.9 S 19 35 W 1175.6 S 19 34 W 1215.5 S 19 32 W 1255.0 S 19 31 W 1293.8 S 19 30 W 1332.7 S 19 30 W 1372.1 S 19 29 W 1411.2 S 19 29 W 1449.6 S 19 29 f~k 1487.2 S 19 1524.9 S 19 1562.8 S 19 29 W 1601.2 S 19 30 W 1640.4 S 19 31 W 1679.5 S 19 31 W. 1718.2 S 19 32 W 1756,5 S 19 32 W A Gyrodata Directional Survey JNOCAL FRADING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 iENAI BOROUGH, COOK INLET, ALASKA Iob Number: AK0390G218 Page MEAS VERT SUB-SEA INCL BORE HOLE DEPTH DEPTH DEPTH BEARING ft ft ft deg min deg min 7500.0 7154.6 7154.6 21 14 S 19 21 W 7600.0 7248.0 7248.0 20 39 S 19 48 W 7700.0 7341.7 7341.7 20 15 S 19 23 W 7800.0 7435.4 7435.4 20 39 S 18 58 W 7900.0 7529.0 7529.0 20 32 S 18 12 W 8000.0 7622.8 7622.8 20 8 S 18 36 W 8i00.0 7716.6 7716.6 20 22 S 20 30 W 8200.0 7810.6 7810.6 19 33 S 21 4 W 8300.0 7904.7 7904.7 20 1 S 20 44 W 8400.0 7998.4 7998.4 20 52 S 22 22 W 8500.0 8091.6 8091.6 21 34 S 23 10 W 8600.0 8184.1 8184.1 23 5 S 23 34 W 8700.0 8275.4 8275.4 25 0 S 22 28 W 8800.0 8365,4 8365.4 26 39 S 22 0 W 8900.0 8454.7 8454.7 27 2 S 21 54 W 9000.0 8543.9 8543.9 26 34 S 21 56 W 9100.0 8633.5 8633.5 26 16 S 22 54 W 9200.0 8723.3 8723.3 26 0 S 22 47 W 9300.0 8813.0 8813.0 26 21 S 22 57 W 9400.0 8902.7 8902.7 26 13 S 24 22 W 9500.0 8992.5 8992.5 25 56 S 25 3 W 9600.0 9082.6 9082.6 25 31 S 24 44 W 9700.0 9173.0 9173.0 24 57 S 25 22 W 9800.0 9264.2 9264.2 23 30 S 25 56 W 9900.0 9356.2 9356.2 22 50 S 26 39 W VERT DOG-LEG SECTION SEVERITY ft deg/100' 1791.1 1.06 1826.8 .61 1861.7 .42 1896.6 .43 1931.7 .30 1966.3 .42 2000.9 .70 2035.0 .83 2068.8 .48 2103.8 1.03 2139.9 .75 2177.9 1.53 2218.7 1.96 2262.2 1.67 2307.4 .39 2352.5 .46 2396.9 .52 2441.0 .26 2485,1 .35 2529.4 .64 2573.3 .42 2616.7 ,43 2659.3 .64 2700.2 1.46 2739.5 .72 HORIZONTAL COORDINATES feet 1690.28 S 599.77 W 1723.97 S 611.75 W 1756.89 S 623.47 W 1789.89 S 634.95 W 1823.22 S 646.16 W 1856.19 S 657.13 W 1888.80 S 668.71 W 1920.71 S 680.82 W 1952.33 S 692.90 W 1984.82 S 705.73 W 2018.20 S 719.74 W 2053.08 S 734.80 W 2090.57 S 750.73 W 2130.89 S 767.21 W 2172.76 S 784.09 W 2214.59 S 800.92 W 2255.71 S 817.89 W 2296.31 S 834.99 W 2336.96 S 852.14 W 2377.52 S 869.91 W 2417.45 S 888.28 W 2456.83 S 906.55 W 2495.45 S 924.60 W 2532.43 S 942.36 W 2567.69 S 959.79 W C L O S U R E DISTANCE BEARING ft deg~_~ 1793.5 S 19 J2 W 1829.3 S 19 32 W 1864.2 S 19 32 W 1899.2 S 19 32 W 1934.3 S 19 31 W 1969.1 S 19 30 W 2003.7 S 19 30 W 2037.8 S 19 31 W 2071.6 S 19 32 W 2106.6 S 19 34 W 2142.7 S 19 38 W 2180.6 S 19 42 W 2221.3 S 19 45 W 2264.8 S 19 48 W 2309.9 S 19 51 W 2355.0 S 19 53 W 2399.4 S 19 56~__~ 2443.4 S 19~-~ 2487.5 S 20 2531.7 S 20 6 W 2575.5 S 20 11W 2618.7 S 20 15 W 2661.2 S 20 20 W. 2702.1 S 20 25 W 2741.2 S 20 30 W A Gyrodata JNOCAL ~DING BAY UNIT, WELL G-40, LEG NO.1, CONDUCTOR NO. 25 {ENAI BOROUGH, COOK INLET, ALASKA Job Number: AK0390G218 Directional Survey Page MEAS VERT SUB-SEA INCL BORE HOLE VERT DOG-LEG DEPTH DEPTH DEPTH BEARING SECTION SEVERITY ft ft ft deg min deg min ft deg/lO0' 10000.0 9448.6 9448.6 21 55- S 26 26 W 2777.5 .92 10100.0 9541.5 9541.5 21 30 S 25 57 W 2814.4 .46 10200.0 9634.7 9634.7 21 15 S 25 50 W 2850,8 .24 10300.0 9727.7 9727.7 21 40 S 26 5 W 2887.3 .42 10400.0 9820.6 9820.6 21 55 S 25 31 W 2924.3 .33 10500.0 9913.1 9913.1 22 31 S 25 31 W 2962.1 .60 10600.0 10005.4 10005.4 22 48 S 24 40 W 3000.6 .42 10700.0 10097.2 10097.2 23 59 S 25 33 W 3040.2 1.24 10800.0 10188.4 10188.4 24 35 S 25 13 W 3081.3 .61 10900.0 10279.0 10279.0 25 18 S 25 25 W 3123.4 .72 11000.0 10369.4 10369.4 25 24 S 25 24 W 3166.2 .10 11100.0 10459.8 10459.8 25 20 S 26 15 W 3209.0 .37 11130.0 10486.9 10486.9 25 14 S 26 25 W 3221.8 .39 HORIZONTAL COORDINATES feet 2601.75 $ 976.80 W 2634.94 S 993.13 W 2667.73 S 1009.04 W 2700.61 S 1025.05 W 2734.04 S 1041.21 W 2768.17 S 1057.50 W 2803.06 S 1073.83 W 2839.01 S 1090.68 W 2876.17 S 1108.31 W 2914.29 S 1126.35 W 2952.97 S ]144.72 W 2991.53 S 1163.38 W 3003.01 S 1169.06 W CLOSURE DISTANCE BEARING f t deg min 2779.1 S 20 J5 W 2815.9 S 20 39 W 2852.2 S 20 43 W 2888.6 S 20 47 W 2925.6 S 20 51 W 2963.3 S 20 54 W 3001.7 S 20 58 W 3041.3 S 21 1W 3082.3 S 21 4 W 3124.4 S 21 8 W 3167.1 S 21 11 W 3209.8 S 21 15 W 3222.5 S 21 16 W Final Station Closure: 3222.5 feet South 21 deg 16 min 15 sec West .;:. ;~.-.~'~-~;::;.~: : ~ ~-:~j-~R,~3go~2~8'--:_:~:-~-st-: ....... , ........ ~ ............ ~-'" .... i .... 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I-~1 ii~ i~ll i ~ !~li , i illi ill l!:X-~- ;il~x-! ! i ~ iii AOGCC GEOLOGICAL MATEI-IIALS INVENTORY LIST FOIl DEVELOPMENTAL WELLS CO~PLEI-~ON DATE WEI..I_ NAME ~, I,~'c' CO. CON'fACT FORM j4~'~ j ..... RECEIVED DAILY DFllLLING SURVEY DIGITAL i.)A1 E t II S'I'O FlY DATA ,Cq.~ , r. -_._'_-~.' ",""1 ~" i.~.i'1'.. ~¢.~_.., i ...... '.1 Memorandum UNOCAL ) DOCUMENT TRANSMITTAL May 18, 1990 HAND DELIVERED TO: $ohn Boyle FROM: R. C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska Region ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Trading Bay Unit~ McArthur River Field - G-40 i sepia and i blueline as follows' Rulse Echo Cement Evaluation (PET) Log.-- 3.~/'~.-. ~;, ~'/, ~'// Acoustic Cement Bond Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: FORM 1-0C03 (REV. 8-85) PRINTED IN U,S.A. i" STATE OF ALASKA i"' ALASKA OIL AND GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Pull tubing x: Alter casing __ Repair well __ Plugging __ Pedorate ~ Other 2. Name of Operator ~ 5. Type of Welh I Development Union Oil Company of California (UNOCAL) Exploratory ! 3. Address ! Stratigraphic Service ~__. P.O. BOX 190247, Anch, Ak., 99519-0~47 4. ~cationdwellatsudace Leg #1, Conductor #25, 1900' NSL & 1459' WEL F/SE Corner, Sec. 29, T9N, R13W, S.M. Top Hemlock-9887' MD, 663' SNL & ~topo~roductiveinterval 2417 WEL F/NE Corner, Sec. 32, T9N, R13W, S.M. ETD=Il,413' MD 1114' SNL ~effe~i~§~Q WEL F/NE Corner, Sec. 32, T9N, R13W, S.M. TD = 11,267' MD, 1155' SNL Att°ta~e~3' WEL F/NE Corner, Sec. 32, T9N, R13W, S.M. 6. Datumelevation(DForKB) 103' RKB above M~ UnitorPrope~yname Trading Bay Unit 8. Well number G-40 9. Permit number/approval number 90-3/90-267 10. APl number 50-- 733-20412 11. Field/P~lock_West Forelan. 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical 11,267' feet Plugs (measured) 10,638 ,feet feet Junk (measured) 11,143 'feet 10,499' Size Cemented RE6EIV,ED MAY 1 8 1990 Naska .0 1 & m,s Cons. C0mmlsslC; Measured d~i'~ True vertical depth 391' 1896' 5098' 11202' 20" Grouted W/314 sxs 421' 16" 1900 sx primary/ 1500 sx top job 1926' 13-3/8" 4300 sx primary/ 650 sx top job 5128' 9-5/8" 2710 sx primary 11232' 421' 1926' 4973' 10579' See attached Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.3#, N-80, MMS threads L.S. @ 10463' S.S. @ 9827' Otis "RDH" Dual Hydraulic packer @ 9796' Otis "BWH" perma-drill packer @ 10386' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation RepresentativeDailyAverageP~du~ionorlnjectionData OiI-Bbl Gas-Md Water-Bbl CasingPressure Shut-in SS (Water injection) 2680 BWPD 1510 psi LS (Water injection) 4317 BWPD 1510 psi Tubing Pressure 3300 psi 3300 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Water In~ection 17. I hereby certify tha~,t~e forego~::~ is true and correct to the best of my knowledge. Signed ~ --~:~) ' Title Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE LEASE MCARTHUR RIVER UNOCAL DRILLING RECO~r· ALASKA REGION ~' PAGE NO. of WELL NO. G-40 FIELD GRAYLING DATE E.T.D. 04/20/90 11,267' TD/ll,143' ETD 04/21/90 11,267' TD/ll,143' ETD 04/22/90 11,267' TD/ll,143' ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS COMMENCE OPERATIONS ON TBUS G-40, 0000 HOURS. Rig up on well. Rig up Myers Wireline and install choke in short string. Injected down short string observing 9-5/8" x tubing annulus. Annulus pressure increase to 775 psi in one hour. Shut down injection and bled down well. Shifted open "XA" sleeve in short string at 9783'. Shifted open "XA" sleeve in long string at 10,339'. Pumped two tubing volumes down long string taking returns up the short string. Shut in short string and pumped down long string taking returns up the annulus. Shut down pumps. Well flowing at 5 gpm. Shut well in and pressure built to 60 psi. Ordered NaCl weight material. Rigged up Schlumberger on G-22 for injection survey. Increased fluid weight from 8.4 ppg to 9.0 ppg. Circulated around 9.0 ppg fluid. Well dead. Installed BPV's and removed tree. Installed and tested BOPE. Rig up tubing handling tools. Pulled Long String to 170 K and dual packer releasedl Well was out of balance. Pumped 250 bbls down long string taking returns up the short string. Well was out of balance on short string. Mixed and pumped a 25 bbl 9.7 ppg dry job down each string. Pulled and stood back dual 3-1/2" injection string. Sent packer, seal assembly, XA sleeves, and ball catcher to Otis to be redressed. Perform rig maintenance while waiting for equipment to be redressed. LEASE MCARTHUR RIVER UNOCAL DRILLING RECOR~ ALASKA REGION i" 'r~GE NO. of WELL NO. G-40 FIELD GRAYLING DATE E. T. D. 04/23/90 11,267' TD/11,143' ETD 04/24/90 11,267' TD/ll,143' ETD 04/25/90 11,267' TD/ll,143' ETD 04/26/90 11,267' TD/ll,143' ETD DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued rig maintenance. Ran dual 3-1/2" injection string with standing valves in the XA sleeves. Tested both strings with 14 stands above dual packer to 3500 psi. Ran an additional 17 stands on each side. Attempted to test short string-no good. Pulled 17 stands, testing every 5 stands-still leaking. Determined standing valve was leaking in short string. Continued to run tubing. Rig up wireline. Pulled standing valves from long and short strings. Continued to run tubing. Spaced out tubing and installed hangers with landing joints. Tested long string packer seals to 800 psi. Ran and set PX plug and prong in XA sleeve above dual packer. Rig to pressure test short string. Attempted twice to pressure test short string to 3400 psi-no good. Pulled PX plug and replaced packing. Reran plug. Installed tubing hangers. Rig to test at top of hangers. Tested short string to 3500 psi for 30 minutes. Rigged up wireline on long string. Attempt to set PX plug in XA sleeve. Plug would not go below 4962' WLM. Picked up landing joints and spaced out to set dual packer. Injected into formation on long string side at 2-1/4 BPM with 1500 psi with no returns to surface. Change annulus over to packer fluid. Set dual packer as per tubing detail. Landed hanger with 50 K slackoff on dual packer. Locked down hanger and packed same with plastic. Perform mechanical integrity test against dual packer and hanger to 3000 psi for 30 minutes. Laid down landing joints and installed BPV's. Nipple down BOPE. Nipple down BOPE. Install and test tree to 5000 psi for 30 minutes. Pull back pressure valves and install injection lines. Change out bad choke on long string. RELEASED RIG AT 0930 HRS, 4/26/90. A 20" ( 1"wall)// @ 424' 75#, K- 55, BUTT @ 1926' MD 1926' TVD 13-3/8", 68#, K-55 & S-80, BUTT / @ 5128' MD 4-973' TVD 9-5/8", 47#, Z~~ N-80 8:S-95 BUTT @ 11232' MD 10606' TVD ETD @ 11143' MD TD 11267' MD 10638' TVD IX,,B C DRT~ 03/18190 03119190 03120190 03/24/90 03/28/9O B) CA,'IERO~ DDAL SPLIT TUB/KG BANGER AT 40.80' C) 20', ~' HALL, DRIV£~ TO 424' D) 1E', 951. ~-55 CASING AT ~926' 13-318°, 681, ~-55 & S-BO CASZHG AT 5128e E) ~-5/8°, 4~d, H-80 & S-95 C.A. SZHG A~ 1&232' TUBING D~TAIL 3-1/2~, 9.2t, ~-80, I~PROVED BDTTRESS WITH TKC ~ SPECIAL CLEARANCE ~OOPLINGS AND T~-99 Z~ERNAL COATING 21 3-1/2' OT/S "XA' SLiDInG SLEEVE AT 9761.67' 4) 3-1/2' OTIS 'XA' SLIDING SLEEVE AT 10348.34 5; 3-1/2' OTIS 'X' NIPPLE AT 10427.63' REENTRY GUID£ W/TB ~K)TTO~ AT ~0461.60~ 6) OTIS RDH DDAL HYDRADLIC PACKER TOP O£ P~R (LONG STRING) AT 9~98.09~ BOTTON OF PKR (LONG STRING) AT 9806.48' 7) OTIS BW~ PEPJ~A-DRILL PACKER AT 10382' STAB-THRO SEAL ASSY FRO~ 10386.2?' TO 10395.07 BBORT STR~NG 1) 3-1/2' OTIS 'XA' SLIDING SLEEVE AT 9960.49' 3) 3-1/2' OTiS 'X~' NIPPLE AT 9813.23' WITH REENTRY GUIDE WITH BOTTO~ AT 9826.58~ OTIS RDE DDAL HYDRAULIC PACKER TOP OF PKR (SBORT STR/NG) AT 9796.2B~ BOT~O~ OF PKR (SHORT STRING) AT 9803.26' ~L~?OR~TTON D~T~ I~L~V]tL 11,042-11,044' DIL 10~455-10,45T' DIL 10,218-10,220' DIL 9,652'-~,654' 10,111-10,11~' 9,55~-9,5~4' 9,934-~,936' DIL ~,880-9,882' DIL 10,993-11,040' DIL W.F.-7 ~0,915-10,97~' DIL N.F.-6 IN~ION-L.S. 10,293'-10,3~4~ 10,218'-10,268' 10,680-10,770~ DZL 10,07~-10,161' 10,525-10,56~' DZL W.~.-2 IN~E~iON-L.S. . ~,936'--9,973' 1~,128--10,208' DIL H.B.-4 ~,892-~,92E' DIL H.~.-1 INfO,ION-S.S. WELL THUS 5;-40 COMPLETION ( 4/26/90 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE' NONE DATE: 5-3-90 I STATE OF ALASKA ("' ALASKA OIL AND GAS CONSERVATION COMMISSION O 7% APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well x__ Plugging __ Time extension ~ Stimulate __ Change approved program __ Pull tubing ~ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development__ 103' RKB above MLLW feet Exploratory ~ _Ad_dr sc_ Stratigraphic 7. _U nit qr. Pro pe_rty na.m. e. 3'p.o'esox 190247, Anch, Ak., 99519-0247 Service_~_~"' Traa~ng Nay un~ 4. Location of well at surface Leg #1, Conductor #25 1900' NSL & 8. Well number 1459' W-EL F/SE Corner, Sec. 29, T9N, R13W, S.M. G-40 Attopof productive interval Top Hemlock-9887' MD 663' SNL & 9. Permit number 2417 WEL F/NE Corner, Sec. 32, T9N, R13W, S.M. 90-3 At effective depth ~ ETD-ii,413' MD 1114' SNL & 2636' WEL lO. APInumber F/NE Corner, Sec. 32, T9N, R13W, S.M. 50--733-20412 At t0tal depth 11,267' TMD 1155' SNL & 2653' WEL 11.~0~r River Field F/NE Corner, Sec. 32, T9N, R13W, S.M. Hemlock-West Foreland 12. Present well condition summary Total depth: meas'ured feet Plugs(measured)RECEIVED true vertical 11267 ' feet 1o611, APR 2 6 1.990 Effective depth' measured feet Junk (measured) true vertical 11143' feet Alaska Dil & Gas Cons. Commission 10499' 'd~ Casing Length Size Cemented Measured~,..... h01'a~9 True vertical depth Structural Conductor 391' 20" Grounted 314 sxs 421' 406' Sudace 1896' 16" 2100 sxs to surf 1926' 1926' Intermediate 5098' 13-3/8" 4950 sxs Top Job 5128' 4973' Production 11202' 9-5/8" 2710 sxs 11232' 10579' Liner Perforation depth: measured See attached true vertical 3-1/2", 9.3#, N-80 MMS threads L.S.,10,453' Tubing (size, grade, and measured depth) S. S. - 9,850 · Otis "RDH" Dual hyd packer @ 9819' , Packers and SSSV (type and measured depth) Ct is "BWH" perma-dril 1 packer @ 10375' 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: April 21, 1990 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Mike Minder April 20.;..,:,t990. ,~./ Name of approver Date approved Service 17. I hereby ceCfy that the foregoing is true and Correct to the best of my knowledge. Signed[ Ii(at(::)~ ~_~ (~",'~'~L Title Pe~. ~r~. ~,n~r Date .Fl[ ~ ' X' FOR COMMISSION USE ONLY Conditions of al:::~)r~val.H~eltify Commission so representative may witness I Approval No. Plug ~egrity __ B~OP ,Test __ Location clearance ~ .¢¢z~ Mechanical Integrity Test'~Z//~ Subsequent form required 10-. "/ ,,,,proved C, oP¥ ORIGINAL SIGNED BY '~//~ ~/~-~'"'"'"'~ Approved by order of the Commission LONNIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE S~Y OF PROPOSAL Repair leak in dual hydraulic packer. 1. MIRU Rig #55 over Conductor ~25; Well G-40. 2. · · · · · · NOTE: Kill Well. Remove tre~. Install and test BOE. , · Pull and stand back dual 3-1/2" tubing and dual hydraulic packer. Repair and redress dual packer. Rerun dual 3-1/2" 'injection tubing as origin'ally designed. Test packer and tubing. Remove BOE and install and test tree. Place well on injection. ANTICIPATED SBHP IS 4025 PSI AT 9450' TVD. WORKOVER FLUID IS FILTERED INLET WATER WITH NACL AS REQUIRED FOR WELL CONTROL. DATE 03/17/90 03/17/90 03/18/90 03/18/90 03/19/90 03/20/90 03/24/90 03/24/90 03/24/90 03/24/90 TBUS G-40 PERFORATION RECORD DEPTH INTERVAL REMARKS 11,042-11,044' DIL 10,407'-10,409' TVD BASE WF-7 10,455-10,457' DIL TOP WF 9,871'-9,873' TVD 10,218-10,220' DIL 9,652'-9,654' TVD 10,111-10,113' DIL 9,552'-9,554' TVD 9,934-9,936' DIL 9,388'-9,390' TVD 9,880-9,882' DIL 9,338'-9,340' TVD BASE HB-4 TOP HB-4 BASE HB-1 TOP HB-1 10,993-11,040' DIL W.F.-7 10,363'-10,406' TVD 10,915-10,972' DIL 10,293'-10,344' TVD 10,833-10,888' DIL 10,218'-10,268' TVD 10,680-10,770' DIL 10,079'-10,161' TVD W.F.-6 W.F.-5 W.F.-3 03/24/90 10,525-10,565' DIL W.F.-2 9,936'-9,973' TVD 03/28/90 10,128-10,208' DIL H.B.-4 9,568'-9,642' TVD 03/28/90 9,892-9,926' DIL H.B.-1 9,349'-9,380' TVD ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE ISOLATION SQUEEZE INJECTION-L.S. INJECTION-L.S. INJECTION-L.S. INJECTION-L.S. INJECTION-L.S. INJECTION-S.S. INJECTION-S.S. BELL NIPPLE I FLOWLINE 3" KILL LINE WITH TWO 3" 5M VALVES I ~J'; d'; KILL LINE FROM MUD PMP & CEMENT UNIT 12" 3000 PSI ANNULAR I PIPE RAMS BLIND RAMS I mi PIPE RAMS RISER I I 1 15-5/8" 5M FLANGE ADAPTER 5M x 5M 15-5//8'' 5M FLANGE DOUBLE GATE 5M 15-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE (I,' d,' I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 15-5/8" 5M FLANGE '~o" 5~ × '~z-5/8" SM ADAPTER CAMERON 5M SPOOL 13-5/8" DOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbQ UNOCAL) DRAWN' DAC APP'D' GSB SCALE: NONE DATE: 11/26/89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY ,,~ ~ o Q O 3 - ~7~z~ - 699'0 DESCRIPTION DAT ' ~ Copy sent to sender YES M~em°randum UNOCAL$ DOCUMENT TRANSMITTAL March 26, 1990 COURIER TO: John Boyle FROM: R. C. Warthen_ ~'~ .... K. D. Kiloh LOCATION' Anchorage LOCATION' Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows' Trading Bay Unit - G-40 boxes: washed and dried cuttings magnetic tape w/listing .~ ~/~/ survey report 1 blueline and 1 sepia of logs as follows: Mudlog 1:240 True Vertical Depth Log 1:600 True Vertical Depth Log Dual Spaced Neutron Log in Casing Caliper Log w/Borehole Volume Compensated Sonic Log Compensated Density Dual Spaced Neutron Log Dual Induction Laterolog Formation Test Log 1 each blueline of field prints: Pulse Echo Cement Evaluation (PET) Log ( " ~) Acoustic Cement Bond Log .//'~ /~~"~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: y~~ DATED' RECEIVED MAR 2 7 !990 Oil & Gc, s Cons. Comm~SsiOt~ Anchorage FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. GEORGE'S COURIER SERVICE 344-3323 FROM ADDRESS STATE CITY ZIP SHIPPER /, ...... DATE / / I TIME TO , ADDRESS ' '"' · CITY STATE ZIP · ATTENTION , ,c;L~. .......... PHONE '.INSTRUCTIONS ,, MAR 2 7 !990 Oil & Gas. Cons, [] 24 HOUR ~Anchoraoe · ' ~ ~ .~'ME DAY LL~'P/U BY 3PM~ CASE NO. COURT DOCUMENTS ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ [] ONE HOUR X J RECEIVED BY ii / / , TIME FROM 'RECEIVED MAR 1 51~0 _ i P. Alaska Oil & G~ Cons. Commission Anchorage MUD SYST~H$~ Trip ~nk VJsuel Aud?g ~r Xe11¥ ~11 t.>,,p~ In~J~t ~OP NUmber' v&lvO~ ~ ......... ... .. _~__ Hyd?tul t:~l ly operated choke ,,....,~_ ...... MEMORANDdM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~MISSION TO: Lonnie C Smit~l// Commissioner DATE: January 25, 1990 FILE NO: A .MTM. 48 TELEPHONE NO: THRU: SUBJECT: FROM: Sr Petroleum Engineer BOP Test Union TBU G- 40 Permit No. 90-3 McArthur Rv Oil Pool ;/.,,..:~ ., ,,~'..',,t .. _Monday, January 22, 1990: I arrived on Grayling Platfoz~n at 5:00pm and had to"'dei~'~ testing Drilling had encountered problems cementing surface casing, and had just completed its second top job with no returns. Quick pretest of the BOP system disclosed a leaking riser flange which was repaired by replacing the API ring. Actual testing commenced shortly before midnight and was concluded at 4:45am with two components having some difficulty passing. The annular preventer required an pward adjustment ~o 1500 psi operating pressure before bag would seal~600 psi test pre°sure. The blind rams had to be cycled twice before they could be tested to 3000 psi with no pressure fall-off. The rubber seal element will be removed and inspected when moved off this well and, if necessary, replaced ~before commencing any new operations. If possible, we should witness testing on next well. In summary, I witnessed the BOP test on Grayling Platform G-40 and recommend follow-up inspection. Attachment 02-001A (Rev. 8/85) Operator ~ ~./?'~ A., 3 Location: Sec. Drlg contrctr Location (general) General housekeeping Reserve pit MUD SYSTEMS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Well sign Rig Audio Visual Trip tank ~ ~ '" I Pit gauge CS)JZ',, [ Flow monitor ~ I Gas detectors 0 ~. I DATE Permit # I~ ~ Casing set @ ~ ~ / ACCUMULATOR SYSTEM: Full charge pressure ~,~'~~ Press after closure J~'~"' ~;P~ ft psig psig sec Pump incr clos press 200 psig min ~-~ Full charge press attained ~ min ~ sec N2 ~ ~/~T~, ~ ~_~,'}~.~m~mpsig, ~ ~ /m~~ Controls: Master ': Remote ~' Blind switch cover V~.~ / KELLY AND FLOOR SAFETY VALVES: Upper Kelly __.[,, , Test pressure~,/~o~ BOPE STACK: Lower Kel 1 y Annular preventer .~d)~/ ~ /"~;~ ....... ' ....... ~:11 type ' U / Pipe / BOP ~/~na rams ~'-~/ ~~ Choke msnifold Choke 1 i ne val yes 0~/' Number valves HCR valve . ,, ~g~) Number flanges Kill line valves ~¢/ ~O00 Adjustable chokes Check valve Test pressure -~/ ~(~D~ Test pressure J)___~.~'~ x~O~ Test pressure ~m~/~,.. Test pressure ~ '- ~c..~:;.;,,;;;~ Hydraulically operated choke TEST RESULTS: Repair or replacement of failed equipment to be made within days and Inspector/Commission office notified. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: JAM 10 ~0 li:B~4 UMOCAL AMCH GRAYLING PLATFORM GENERAL DIVERTER OPERATIONS I. SURFACE HOLE DRILLING DRILLING FOREMAN IS TO KEEP THE PRODUCTION FOREMAN INFORMED OF CURRENT RIG ACTIVITIES ? PROBLEMS TO ALLOW FOR PROPER PRE-PLANNING BY THE PRODUCTION DEPARTMENT. II. DIVERSION OPERATIONS A) WHEN IT IS DEEMED NECESSARY' TO DIVERT THE WELL, THE DRILLING FOREMAN WiLL IMMEDIATELY NOTIFY THE PRODUCTION FOREMAN AND SOUND THE GENERAL ALARM° B) THE DRILLING CREW WILL POSITION THE TOOL JOINT PROPERLY (IF POSSIBLE) AND ACTIVATE THE DIVERTER SYSTEM. C) FLUID FROM THE ACTIVE SYSTEM FOLLOWED BY FIRE WATER WILL BE PUMPED DOWN THE WELL AT MAXIMUM PUMP CAPACfTY. D) SIMULTANEOUSLY TO THE ABOVE~ THE PRODUCTION FOREMAN WILL INITIATE THE FOLLOWING ACTIVITIES IMMEDIATELY UPON NOTIFICATION THAT THE WELL WILL PLACED ON THE DIVERTER. EXTINGUISH THE FLARE PILOTS AND ALL OTHER DIRECT SOURCES OF IGNITION. NOTIFY EMERGENCY EVACUATION SERVICES (HELICOPTERS, BOATS,ETC) ~ PROCEED WITH TOTAL PLATFORM SHUTDOWN. 4) LOCATE ALL PERSONNEL AND DIRECT THEM TO SAFE BRIEFING AREAS FOR EVACUATION BY' BOAT~ 'HELICOPTER, OR ESCAPE CAPSULE. JAM 10 ~0 ll:B5 UMOCAL AMCH GRAYLING WELL TBUS G-40 DIV~RTER ~'UNCTION TEST SUMMARY FUNCTION TESTED DIVERTER AS FOLLOWS: 1) ACTIVATED DIVERTER SYSTEM FROM RIG FLOOR A) 10" DIVERTER VALVE OPENED iMMEDIATeLY UPON ACTIVATION OF TH~ SYSTEM. B) ANNULAR PREVENTER SEALED ON 10" PIPE ONE MINUTE AFTER ACTIVATION OF THE SYSTEM. 2) FUNCTION TESTED DIRECTIONAL CONTROL VALVES A) BOTH VALVES FUNCTIONED PROPERLY. B) ONE VALVE ALWAYS REMAINS OPEN. 3) ACCUMULATOR PRESSURES A) PRIOR TO ACTIVATING SYSTEM - 3000 PSI B) AFTER OPENING DIVERTER VALVE, CLOSING ANNULAR, AND'~ SWITCHING DIRECTIONAL CONTROL VALVES - 1350 PSI , 11::34 UNOCAl- AHCH M~ ~I~T'AN 10 ~ ~0 11: BS UHOCAL AMCH p. 3/4* TURBINE '1~/0 liYO CONTROLL£D DIRECTION CONTROLL VALVES ONE ALWAY5 OPEN 15'OVERBOARD ,~ ,. ._ HYD DIV£RTER VALVE 140'RUN FROM HC[.£ CENT£R *~... PIPE RACK FLARE END OF PLATFORM TURBINE 10' OVERBOARD ,, LIVING QUARTERS RECEIVED N UNOCAL ALASKA REGION Fax Nachine (907) 26~-7.695 Fax Confirmation (907) 276-7600 THIS INFORMATION TO: If you do not receive ~ pages (including this. cover sheet) Please call (~07) 276-7600 and ask for Roxanne Sinz. ALASKA OIL AND GAS CONSERVATION COMMISSION STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 Telecopy No. (907) 276-75~2 January 3, 1990 A D M I N I S T R A T I V E A P P R O V A L N O. 80.55 Re: The application of Union Oil Company Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete the TBU G-40 well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr Robert A Province Landman UNOCAL Corp P 0 Box 190247 Anchorage, AK 99502-0247 Dear Mr Province: Your application letter of January 3, 1990 stated that the drilling and completion of the TBU G-40 service well will provide additional oil recovery from the Hemlock and West Foreland oil pools. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU G-40 service well pursuant to Rule 5 of Conservation Order No. 80. Sincerely, Lonnie C S~~~h C ommis s loner BY ORDER OF THE COMMISSION jo/3 .AA80 January 3, 1990 Telecopy No. (907) 276-7542 Roy D Roberts Environmental Engineer UNOCAL P O Box 190247 Anchorage, AK 99519-0247 Re: Trading Bay Unit G-40 UNOCAL ' Permit # 90-3 Surf Loc 1900'FSL, 1459'FEL, Sec 29, TgN, R13W, SM Btmhole Loc 2700'FEL, ll00'FNL, Sec 32, TgN, R13W, SM Dear Mr Roberts: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt You from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24'hOurS prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl Unocal 011 & Gas Di~" ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Robert T. Anderson Manager, Lands Alaska Region January 3, 1990 Mr. Bob Crandle Alaska Oil & Gas Conservation Commission 3001 Rorcupine Drive Anchorage, AK 99504 Dear Mr. Crandle: TRADING BAY UNIT State of Alaska McArthur River Field Application to Drill and Complete Well G-40, Lease Number ADL-17594 Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and inject the subject well to the west side of the main feature to provide injection support for the Hemlock and West Foreland reservoir producers, pursuant to Rule 5, Conservation Order No. 80. Benches (sub-intervals) i and 4 will be injected into as part of the ongoing Hemlock pressure maintenance program augmenting recovery by 1.735 MMBO. The location for G-40 will fill-in the peripheral flood on the west side of the main feature completing the K-4RD, G-5 and G-22 injection line within the Hemlock reservoir, There is currently no west side injection occurring into the West Foreland Reservoir. Your approval of this request will be appreciated. Very truly yours, Robert A. Province Landman RAR: rms (44801) cc: C. Lockwood E. O'Oonnell R. Warthen JAN- Alaska Oil:&' 'Cons. mIalSd l Anchorage Alaska Region Unocal North American,,' Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL December 27, 1989 Mr. Chat Chatterton AOGCC 3001 Porcupine Drive Anchorage, AK 99504 ~1 Dear Chat: Attached is the G-40 shallow gas evaluation presented to me by~ Unocal Geologist Kirk Kiloh. This is the same information that we/ presented to you on Thursday, December 21st. We wish this information to be included in the ~~_~t.to Dril~.f_?~r~.~e_.l_~__~.0.,. ~Jl~r ........ ,/ Sincerely, Clifford G. Neve' District Drilling Superintendent Attachment CGN/lew RE,¢EIVED DEC 1.9 9 Alaska 0il & Gas,Cons. Comm%Ss%Q~ Anchorage Unocal North Americaq.,' Oil & Gas Division I~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region TO: FROM: Cliff Neve' Kirk Kiloh~Q¢/ G-40 SHALLOW GAS EVALUATION December 21, 1989 A cased hole TDT-P log was run in G-16 on November 25, 1988, to determine if any shallow gas lies beneath or in close proximity to the Grayling Platform. Log analysis indicates that four (4) shallow sands may contain gas of unknown saturation and pressure. These sands are the SZ 17 sand, 2440 (-1948) to 2502 (-1988), SZ 19 sand, 2726 (-2136) to 2805 (-2187), SZ 22 sand, 3010 (-2324) to 3062 (-2360), and SZ 23 sand, 3134 (-2409) to 3165 (-2430) DIL in the G-16 well. These sands occur in the G-i~ wellbore at approximately 1200' due east of the Grayling. The basis for possible gas saturation is the separation of the near and far neutron counts shown on the TDT-P log in G-16. Marathon, TBU M-i, served as the type log for the entire shallow zone to include sands, coals and shales. The above-mentioned interval in G-16 is correlative to the interval from 2172' to 2800' MD in the H-1 well. It is recommended that MWD resistivity, gamma ray, directional, and mud logging services be conducted from the 20" shoe at 454' to approximately 2500' HD in G-40 to better identify if these indeed are gas bearing directly beneath the Grayling. In addition, the shallowest of these four sands is expected to be penetrated approximately 200' below the planned 16" casing shoe at 2000' ~D in G-40. KDK/pg 2971D RE,CEIVED Alaska Oil & Gas ,Cons. CommissioP. Anchorage ~O STATE OF ALASKA ALASKA' ,L AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 ORIGINAL ,,.,MISSION la. Type of work Drill [] Redrill d lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenI-31 Service ~ Developement Gas [] Single Zone Ii. Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 103' RT above MSI4eet McArthur River Field 3. Address 6. Property Designation Hemlock P.O. BOX 190247, Anchorage, AK 99519-0247 ADL 17594 West Foreland 4. Location of well at surface Leg #1, Conductor #25 7. Unit or property Name 11. Type Bond (see 20 AAc 25.025) 1900'N & 1459'W f/S~. Corner, Sec. 29, T9N Trading Bay Unit United Pacific Insurance Co. At top of productive interval R13W, S.M. 8. Well nuqnber Number 2520' FEL, 650' FNL, Sec. 32, T9N, R13W, S.M G-40 ~C.~¢~ U62 9269 At total depth 9. Approximate spud dat~W'~"~' ~Amount 2700' FEL, il00' FNL, Sec. 32, T9N, R13W, S. [. -I~ /.~.~ $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 11350' MI) 4140 feet 29 feetl 5116 acres 10700' TD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o A~C 25.035 (e)(2)) Kickoff depth 2280 feet Maximum hole angle 23o Maximumsurlace pslg At total depth 0'VD) pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" l" W~ll 406' 406' Driven (~routed w/3j4 22" 16" 75# K-55 Butt 2000' 2000! ~. 2100 sxs --¢r'/~ ~ 17-1/2" 13-3/8" 68# K-55 Butt 4100' 4007' ~ 2300 17-1/2" 13-3/8" 68# S-80 Butt 4100' 4007'!5100' 4931' 12-1/4" 9-5/8" 47# N-80 Butt 11350' 10700' 1850 sxs 19. To be completed for Redrill, Re-entry, and Deepen 'Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor S u r face E f. E '1 'V E D Intermediate . Production ,., , L~,t::t,.,, 0 z'i · , Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify.t~at th~,fore, going is .!irae and correct to the best of my knowledge Signed Ro~fD. Roberts Title Environmental Engineer Date/:_2/~ Commission Use Only Permit Number I APInumber IApprovaldate I See cover letter __,,~,~_ ±-t...~ ' 50-- '2,33 '.t O~/I.Z 01 / 03 / 90 for other requirements .......... Conditions of approval Samples required [] Yes ~ No Mud log required L-q Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required 1~ Yes [] No Required working.px.e~sureJorB..Q~ /[~2M; ,~['~3M; J~C._SM; r"l 10M; [] 15M Other: ~___~~~~__//~ e/,~_~ 4¢ ' by order of Approved by "--'~-COmmissioner the commission Dat ~xs) Form 10-401 Rev. 12-1-85 S u I¢'r in triplicate TRADING BAY UNIT G-40 NEW WELL DRILLING PROCEDURE 1. MOVE RIG #55 OVER TBUS G-40, LEG #1, CONDUCTOR 25. 2. RIG UP 20" 2M DIVERTER ON CONDUCTOR PIPE. 3. DRILL 17-1/2" HOLE TO 2000'. 4. UNDERREAM TO 22" HOLE FROM 20" SHOE TO 2000'. 5. RUN AND CEMENT 16" CASING. 6. INSTALL AND TEST 20" 3M BOPE. 7. DIRECTIONALLY DRILL 14-3/4" HOLE TO 5100'. * Thru D-2 Coal & set in shale below D-3A sand. 8. RUN LOGS. 9. UNDERREAM TO 17-1/2" HOLE FROM 16" SHOE TO 5100'. 10. RUN AND CEMENT 13-3/8" CASING. 11. INSTALL AND TEST 13-5/8" 5M BOPE. ].2. DIRECTIONALLY DRILL 12-1/4" HOLE TO 11050' TMD. 13. RUN LOGS. ]..4. RUN AND CEMENT 9-5/8" CASING. 15. RUN CET/CBT AND GYRO SURVEY. 16 CLEAN OUT, SQUEEZE IF NECESSARY, AND PER~ORA.FE 17. RUN DUAL INTERNALLY COATED INJECTION COMPLETION. TRADING BAY UNIT G-40 NEW WELL MUD PROGRAM INTERVAL: 406' to 2000'MD ( 16" CASING ) MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH 65 to 72 PCF 50 to 70 Sec/Qt 10 centipoise 20 Lb/100 Sq Ft 9.0 INTERVAL: 2000' to 5100'MD ( 13-3/8" CASING ) MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH WATER LOSS 72 to 75 PCF 45 to 65 Sec/Qt 10 Centipoise 15 Lb/100 Sq Ft 9.0 15 cc INTERVAL: 5100' 'to 11350'MD ( 9-5/8" CASING ) MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH WATER LOSS ( API ) ( HT-HP ) 70 to 74 PCF 45 to 55 Sec/Qt 10 to 15 Centipoise 15 to 20 I0b/100 Sq Ft 9.5 to 10.0 5 to 8 cc/30min 15 to 17 cc/30min 0.01 20", 1" wallj @ 424' 16", 75#, K-55, BUTT @ 2000' 5-5/8", 68#, K-55 & S-80, BUTT Z @ 5100' MD 4100' TVD KELLY BUSHING TUBING DETAIL LS: 3-1/2", 9.3#, N-80 BUTT, TK-99 COATED, HMS CONN SS' 3-1/2", 9.3#, N-SO BUTT, TK-99 COATED, HMS CONN 1) XA SLEEVE 2) XA SLEEVE ,.3) XN NIPPLE 4) XA SLEEVE 5) X NIPPLE 6) DUAL HYDRAULIC PKR @ 980O' MD 7) PERMANENT PKR @ 10300' MD HEMLOCK HB-1 PERFS HEMLOCK HB-Zl- PERFS 9-5/8", 47#, N-80, BUTT @ 11350' TMD 10700' TVD WEST FORELAND PERFS WELL TBUS G-40 PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba. UNOCAL) DRAWN' DAC SCALE: NONE DATE: 11-:;.'30-89 BELL NIPPLE 20" 2000 PSI ANNULAR I I DIVERTER SPOOL I , , I ONE 10" DIVERTER LINE WITH TWO OUTLET PATHS. RISER ONE 10" HCR VALVE ON THE DIVERTER SPOOL HYDRAULICALLY ATTACHED TO ANNULAR. HCR VALVE TO OPEN WHEN ANNULAR CLOSESt, I 20" WELLHEAD FLANOE 20" DIVERTER STACK ORAYLINO PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 BELL NIPPLE I FLOWLINE 5" KILL LINE WITH TWO 3" 5M VALVES d; _ d; KILL LINE FROM MUD PMP & CEMENT UNIT 20'° 2000 PSI ANNULAR I I PIPE RAMS BLIND RAMS l-- I 'PIPE RAMS I 21- 1/4" 2M FLANGE ADAPTER 2M x 5M 20-,3/4" 5M FLANGE DOUBLE GATE 3M I 20-3/4" 5M FLANGE , 14" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWlNO) 20-3/4" 3M FLANGE SINGLE GATE 3M 20-3/4" 3M FLANGE RISER I 20-3/4" 3M x 16-3/4" 3M ADAPTER 16-,3/4" ZM CASING HEAD 20--5/4" BOPE ZM STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC APP'D' GSB SCALE: NONE DATE: 11/26/t]9 BELL NIPPLE I FLOWLINE .3" KILL LINE WITH TWO 3" 5M VALVES :[) KILL LINE FROM MUD PMP & CEMENT UNIT 12" 5000 PSI ANNULAR I PIPE RAMS BLIND RAMS I , " J I, i PIPE RAMS J J__ I ~1 RISER I I 13-5/8" 3M FLANGE ADAPTER 3M x 5M 15-5/8" 5M FLANGE DOUBLE (;ATE 5M 13-5/8" 5M FLANGE CHOKE LINE WITH ONE REMOTE 1 MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL I 15-5/8" DOPE 5M STACK GRAYLING PLATFORM DRAWN' DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) TO GAS BUSTER /\ 4-1/16" 3-1/8" TO DERRICK VENT Ii I I I 3- 1/8" 1/16" 4-1/16" 4-1/16" TO WELL CLEAN TANK ?\ 4- 1/16" AUTOMATIC CHOKE ~-1/16" 3-1/16" //~ ~-1/16" ~-1//16" / FROM CHOKE LINE AUTO MATI C CHOKE VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES DOWNSTREAM OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE' NONE DATE: 11/26/89 MIXING PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM 185 BBLS VOLUME PIT TRIP TANK 4-5 BBLS 185 BBLS SUCTION PIT 1 ',125 BBLS ! DEGASSER ! I I 'i 'i -- ! -- I I I. 67 BBLS DESILTER 240 BBLS SHAKER SHAKER ...... iCENTRIFUGE RESERVE PIT 475 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO & VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 5) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN BY: DAC APP'D: GSB SCALE: NONE DATE: 11-50-89 0 (3 o .30 .40 .50-- .70 .80 EFFECT OF AXIAL TENSION ON COLLAPSE FOR LONE STAR STEEL CO. CASING Foruulae: · Collapse resistance in tension X (Collapse pressure ratify) Calculations: Burst Pressure - f~P +.Depth ( ]{yd. Gr. II --~5) JIF (Bouyaney Fac'tot) = ~.oo- (o.o~] x ~.~ua w~, ~) 1.00 0 30 .20 .30 .40 .50 .60 .70 .80 .90 1.00 TENSION LOAD AXIAL LOAD FACTOR,I~- BODY YIELD STRENGTH CASING AND lUBING DESIGN WELL CASING SlRING TBUS G-40 i6", 13-3/8", 9-5/8" FIELD McArthur River Field BOROUGH Grayling STATE Alaska DATE 11/28/89 DESIGN BY DAC 1. MUD WT. I #/q. ~IYO GR. I psi/ft. MUD WT. II 2. CASI ~G SIZE 0.5 psi/ft, gradient on outside, void on inside for collapse 0.5 psi/ft, gradient on inside, void on outside for burst WEIGHI W/ BF INTERVAL DESCRIPTION W/O BF x Bottom Top LENGTH Wt. Grade Thread lbs 16" ?0fica' fl' 2000' 75# K-55 Butt 150,000 #/g. HYD. GR. II psi/ft. M.S.P. pst. 1ENSION MINIMUM COLLAPSE COLLAPSE INTERNAL -top of SIRENGTH PRESS. @ RESIST. BURST MINIMUM section TENSION bottom tension P~ESSU~E YIELD lbs 1000 lbs TDF psi pst CDF ps1 psi 150,000 1331 8.9 1000 1020 1.02 1000 2630 BDF 2.6 ~_~_~- 2. 1~-~i8" 4100' 0' 4100' 13-3/8" (4007' TVD) 5100' 4100' 1000' (4931' TVD) ~. ~-~/8" 11135~ 0' 11135' (10700' TVD) 68# K-55 Butt 68# S-80 Butt 47# N-80 Butt 278~800 346,800 1300 3.7 2004 1950 1.0 2004 3450 1.7 68,000 68,000 1496 22 2466 2850 1.2 2466 3450 1.4 523,345 523,345 1161 2.2 5350 4750 0.9 5350 6870 IBO0 2400 3000 3600 A B __ Buztn 2!5 deg/4.0Q ft VERTICAL SECTION UNOCAL CORPORATION G-40 SECTION AT S 22.50 N -' ~ ~ = . feet TVD SCALE ! .n~h 4200 OEP S~A=: ~ inch = 1200 reef · DRAWN ' 11-16-89 Na~km- Identification 14] TVD DEPRT ~JKB 0 0 0 BI KOP 2280 2280 0 C) EGO 34.B0 34.57 t74 DJ TOP HB4_OCK 9944. 9403 2762 ID TOP NEST ~ 4.0503 9923 2977 F] BFL 4.t344 10700 3?_99 4200 T 4800 V 5400 D 6000 6800 7200 7800 5400 9000 9600 10200 IOBOO -600 600 !200 !BOO 2400 3000 3600 4200 4800 5400 6000 6600 D~parture Iq~k~ ]:defl[lftcat[on lid 1VD DEPITT m KOP ~0 ~ 0 CI EOB 34.~0 34.5-7 t74 DJ ~B~ HE~I_DI~ 994t 9403 tr/6~ EJ ~OP WE~ FOREI_I~ t0503 ~ ~977 r"J~ ~4.344 4.0700 ~ PLAN VIEW UNOCAL CORPORATION 2=0 o 250 500 750 !000 ~250 tSO0 !750 2000 2.500' 3000 1500 i250 I000 750 500 ~:n ~ O 250 500 750 lOgO 1250 1EgO GREAT LAND DIRECTIONAL DRILLING,INC Well ....... : G-40 Leg No. 1 Sect Direct: S 22.50 W Mag Decln..: 0 deg 0 min E RKB Elev...: 103.0 ft Data file..: B:G40P25.DAT for UNOCAL CORPORATION Conductor 25 WELL PLAN Computation: Build ...... : 11-17-89 RADIUS OF CURVATURE 2.50/100 to 22.50 deg KB ................ : KOP ............... : EOB ............... : TOP HEMLOCK ....... : TOP WEST FORELAND.: BHL ............... : MEAS INCLN TVD SUB DEPTH ANGLE BKB SEA mmmmm mmmmm 0 0.00 0 -103 2280 0.00 2280 2177 2380 2.50 2380 2277 2480 5.00 2480 2377 2580 7.50 2579 2476 2680 10.00 2678 2575 2780 12.50 2776 2673 2880 15.00 2873 2770 2980 17.50 2969 2866 3080 20.00 3064 2961 3180 9941 10503 11344 22.50 22.50 22.50 22.50 SECT DIST 0 0 2 9 20 35 54 78 106 138 DIRECTION ANGLE RELATIVE COORD DOG FROM WELLHEAD LEG 22.50 W 0 N 0 E 0.0 22.50 W 0 N 0 E 0.0 22.50 W 2 S 1 W 2.5 22.50 W 8 S 3 W 2.5 22.50 W 18 S 8 W 2.5 S 22.50 W S 22.50 W S 22.50 W S 22.50 W S 22.50 W 3157 3054 174 S 22.50 W 9403 9300 2762 S 22.50 W 9923 9820 2977 S 22.50 W 0700 10597 3299 S 22.50 W 32 S 13 W 2.5 50 S 21 W 2.5 72 S 30 W 2.5 98 S 41 W 2.5 128 S 53 W 2.5 161 S 67 W 2.5 2552 S 1057 W 0.0 2750 S 1139 W 0.0 3048 S 1262 W 0.0 GREAT LAND DIRECTIONAL DRILLING, INC. 12-2-89 Don Chudanov Unocal Corporation 1111 E. 80th Anchorage, Alaska 99502 349-4511 Grayling Well G-40 Leg 1 Conductor 25 Close Approach Analysis Don: We have examined the potential intersections of well G-40 with the other Grayling wells. The profile for G-40 was calculated from parameters provided by you. Planned well G-40 has a KOP of 2280 TVD BKB with a 2.5/100 build rate to a maximum angle of 22.50 degrees. It has an initial direction of S 43.00 W turning 6.0/100 to S 25.00 W at 2783 TVD BKB and turning again to S 18.31 W at 3711TVD BKB. The KOP and planned directions were chosen to avoid intersections at depths of 2800 and 3700 TVD BKB. The other wells were calculated form gyro data provided by Unocal Corporation. The closest well to G-40 is G-29 which isi..Z~......~,eet away at 2600 TVD BKB. The close approaches are summarize~-b~low: Well Distance At TVD BKB G-29 29 ft 2600 G-07 30 ft 2847 G-25 34 ft 1220 G-02 50 ft 3750 G-05 58 ft 1058 G-03(RD,RD2) 70 ft surface G-15 72 ft 0 - 400 G-17(RD) 73 ft 300 G-02RD 74 ft surface G-06(RD) 74 ft 1200 G-10(RD) 76 ft surface G-13 76 ft 0 - 800' G-ii 78 ft surface G-14A 80 ft surface G-19 80 ft 1000 G-04(RD) 84 ft surface G-31 84 ft 525 G-01 88 ft 0 - 900 G-32 89 ft 1043 G-12(RD,RD2) 94 ft surface G-09 96 ft surface G-16 97 ft 600 G-40 has crossings with eleven wells in the Grayling area. The closest crossing is with G-29 where G-40 is 209 ft below G-29. The crossings are summarized below: Well TVD BKB G-40 TVD G-40 is: G-29 2509 2718 G-05 858 2814 G-15 870 2882 G-13 1057 2905 G-19 2297 2908 G-17RD 808 2968 G-10 1806 3128 G-27 1781 3138 G-28 2208 3322 G-02 6123 4768 G-22 5827 9152 209 ft below 1956 ft below 2012 ft below 1848 ft below 611 ft below 2160 ft below 1322 ft below 1357 ft below 1114 ft below 1355 ft below 3325 ft below TVD's have been adjusted to the Kelly bushing of G-40. Analysis by: D. Tem~lin Checked by: ~/. D. Thompson CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (.2) .o,c (2 thru (8) (3) Admin (9 thru 13Y (10 and (4) Casg (14 thru 22)' (23 thru 28) le Company (3.~.,.~.. 0.(2 ~- ~0,~ (O.,~o ~ ~(~ ~ Lease & Well No. ;k~)~_ %q59~1 ' YES Is the permit fee attached .......................................... ~__ 2. Is well to be located in a defined pool ............................. 3. Is we~] located proper distance from property line .................. 4. Is we~,i_located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... . 10. 11. 12. 13. 14. 15. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... ~' Is the lease number appropriate ..................................... ~ Does t~e well have a unique name and number ......................... ~ Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and BOPE ,attached ~5 ~oes BOPE have sufficient pressure rating - Test to ~O-~,.pszg .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. 16. 17. 18. 19. 20. 21. 22. NO X C~ R~S 23. 24. 25. 26 27. 28. (6) OTHER (29 thru 31) (6) Add: Geo lo gy: DWJ~ Eng~ggring: _ .. LcS 7'~ rev: 01/30/89 6.0i! For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of ~eabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL& CLASS STATUS AREA ! NO. SHORE ,, Additional Remarks: ',,\ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. DIRECT DIGITAL LOGGING COMPUT'ER PR'OCESSED ANALYSIS ' NICROFILMED LLLLLLLLLL LLLLLLLLLL IIIIIIIIII IIIIIIIIII II II II II II II ii Ii iiiiliiiii IIIIIIIIII SS$$SSS$ SSSSSSSSSS SS SS SS SSSSSSSSS SSSSSSSSS ~'~SSS DDDDDDDDD UU UU MM MM DDDDDDDDDD UU UU HHM birth DD DD UU UU biHHH bIHHH DD DD UU UU HH HH HH HH DD DD UU UU HH HHHH HH bb DD UU UU HH HH HH DD DD UU UU HH DD DD UU UU HH HH DD Db UU UU biH HH DD DD UU LiU HH bi bi DDDDDDDDb~ UUULiUUUUULiUU HH HH D D D D [:, D D D D U U U U U U U IJ U U J'i H i'l bi PPPPPPPPPF PPPPPPPPPF PP PP PPPPPPPPPF P~'~'P~PPPPF PP PP PP PP 222222222 2222222222 22 22 22 22 22 22 22 '2 2222222222 o~,~222.-, 77'7777777777 77777777777 77 77 77 77 77 77 77 77 77 77 77 ii 1111 11 11 11 11 11 11 11 1111111111 'iiiliillii MM MM HMH MMH MHHH MMMH HH MM MM MM MM HMHH HM HH MM MM MH i'lH HH HH HM Ht"l HH HI"I HH HH MM HH 2222222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 AAAA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 00000000 AA 0000000000 AAAA O0 O0 AA AA O0 O0 AA AA O0 O0 AA AA O0 O0 AAAAAAAAAAAA O0 O0 AAAAAAAAAAAA O0 O0 AA AA O0 O0 nA AA 0000000000 AA AA 00000000 AA AA RRRRRRRRRRR 9999999999 RRRRRRRRRRRR 999999999999 RR RR 99 99 RR RR 99 ~9 RR RR 99 99 RRRRRRRRRRRR 9999999999~'~ RRRRRRRRRRR 99999'~~~99 RR RR 99 RR RR 99 RR RR 99 99 RR RR ,,, 999999999999 RR RR 9999999999 NM HHHH HH NH HH MN HHMH HH HH HH HH NH HH HH 0000000~ 00000000~ O0 O0 O0 O0 O0 O0 O0 O0 00000000~ 0000000~ Service name: &GSF01 Previous reel: Date: 90?03/20 Comments: 'HEADER. Origin: RECORDS Reel name: 137655 P,~ge Continuation #: 01 Set. vice name: &GSF01 Previous tape: Date: 90703,:20 Comments: Origin: Tape name: 137655 Continuation #: Oi *** FILE HEADER **** File name: ,.001 Maximum length: 1'024 Service name: File typ~: LO Version Previous ¢ile: Date: I NFORMAT.I ON RECORDS Pagm MNEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR CN WN FN COUN STAT CTRY AP iN LATi LONG SECT T 0 W N RANG El< B EDF E~L PD LHF ~HF RUN T~HE D~TE LCC LUH FL LUL EN~) WI TN DD DL CBD1 C8L1 TLI BLI TCS TLAB BHT HRT HT DFD HVIS DFPH DFL ~hlF HFST HFSS RHC UNOCAL TBU G-4 0 HcARTHUR RIVER KENAI BOROUGH ALASKA USA '-20412. 000 .............................. 0 Dmq. 0 H in, O. 0 Smc, N ....... 0 Om~ 0 Min. O. 0 Sec. W .... .,., 09N .............. 103,000, ,. 1 02. 000. , -I17,000, MS ...... KB...',., 1903,000 2/ 2/90, 30 ...... .. 137G65 G"'8612 STE~LiN~ '3TERLIHG SCHI A',/I/YEE KILOH 5t 35 000 5132 000 1926 OOO 1925 00'0 1925. O00 513'0 000 800. '000, 1407,000 1 '18.00 O, 1'18,000, DEFLOCUL~TED FLOWL I NE 9;400, . , 39, OOO , , 7,500, . , 9. 200, , , 1,100, , . .950 .... AP1 NUH: 50-733-20412 ................ [)ATE LOuukL): 02-02-90 ................ 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 O 20 65 0 0 4 68 0 0 S4 65 0 0 34 65 0 0 '-", ~ 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 6`5 0 3 2 65 0 0 2 79 0 0 4 6`8 ,O 0 8 65 0 0 2 79 0 0 10 65 0 0 10 6`5 0 0 20 65 0 0 20 6,5 0 0 20 6`5 0 0 20 6,5 FT 0 3 4 6,8 FT 0 ,7 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 ..7 4 6,@ FT 0 .3 4 68 HR 0 2 4 68 HR 0 4 4 6`8 DEGF 0 1 4 6`8 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP O 2 4. 68 0 2 4 68 0 2 4 OHMH 0 2 4 68 0 H H H 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 0 H H H 0 2 4 68 I HFCiRM~ T.I OH RECORDS Page MNEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR MCST MCSS CS BS GS,000 ................................................... MEASURED ............................................ i6,OO0 .................................................. i4.750 .................................................. DEGF 0 2 4 68 0 '2 i2 65 0 3 4 68 0 3 4 68 COMME .T RECORDS Well Location Comment 1: Well Location Commmnt 2: Wmll Location Comment 3: LEG ~1, Well Location Comment 4: Well Film Comment l: CHLORIDES: Wmll File Comment 2: DIL/BCS/GR Wmll Film Comment 3: CDL?DSN?GR Well Film Comment 4: '1900' FSL &1459' FEL GRAYLING PLATFORM CONDUCTOR #25 5000 RUN RUN PPH, DDL SYSTEM AND TOOLS USED TO LOG WELL. I IN COMBINATION. IN COMB'INATION. LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most closely match Halliburton curvm and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 396,0e 5150,'00 TEN GEN LBS TEN GEN LBS 397,00 5138,50 SP GEN MY SP GEN MV 397,00 5138,50 GR GEN APl GR GEN APl 397,0'0 5i38.50 ILD DIL OHMM ILD DIL OHMM 39?,00 5138,50 ILH DIL OHMH ILM DIL OHMH 397.00 5'138,50 RLL3 DIL OHMM RLL3 DIL OHMM 397,.00' 5138,50 DT 8C.S US?F DT 8CS US?F 397,.00 5138,50 TT! BCS US TT1 8CS US 397,'0.0 5't38,50 TT2 BCS US TT2 8CS US 397,'.00 5'138,50 Pagm CILD CI LI'I TENI GR1 CALI1 FFDC 1 NFDC 1 RHOBI DRH01 FCNL1 NCNL. 1 NR~TI NPH I 1 DPHI1 8CS 8CS DIL DII_ GEN GEN CD[. CDL CDL CDL CDI, DSN DSN DSN DSN CDL US US MMHO MMHO LBS APl IN CPS CPS G/C3 CPS CPS SSPU PU TT3 TT4 CILD CILM TEN GR CAI,1 FFDC NFDC RHO8 DRHO FCNL NCNL NRAT NPHI DPHI 8CS 8CS DIL DIL GEN GEN CDL CDL C'DL CDL CDL DSN DSN DSN DSN CDL US US MMHO MMHO LBS AP1 IN CPS CPS G?C3 CPS CPS $SPU PU 397 397 397 397 .397 397 397 397 397 ,397 397 397 ,397 ,397 O0 O0 O0 O0 O0 O0 O0 0 O O0 O0 .00 ,00 .00 ,00 , '00 .:00 51 51 51 51 51 51 5i 51 51 5'1 5'1 51 51 5'I 51 5 't ,38.50 .38.50 :38,50 38.50 38.50 38.50 :38.50 38 °50 38.50 38.50 38.50 38.50 38,50 ,38,50 38,50 38.50 D~T~ ENTRY BLOCKS ENTRY OlJllllllllllllllllllilliJlfllllll FORMAT TYPE 0 SIZE SPECIFICATIONS CODE Page :,~*:~ ENTRY BLOCK LEGEND TYPE DESCRIPTION I6 Datum zpeci¢ication block sub-type 0 Terminator ( no more entries ) FORMAT SPEC I F I CA T IONS SERVICE SERVICE APl APl AP1 APl FILE · ID ORDER ti UNIT LOG TYPE CLASS HOD tt PRC II SIZE LVL SMPL- RC: PROCESS INDICATORS DEPT TEN GEN SP GR GEN ILD DIL ILM DIL RLL3 D I L DT BC:S TT i ~C:S TT~ ~C:$ TT3 BC:S TT4 BCS CiLD DiL CILM [)IL T E N G E GE GEN CALl FFDC CDL t,IFDC CDL RHOB CDL DRHO CDL FCNL DSN N C N L D S N NRAT D'~oN ' NPHI DSN DPHI CDL i37665 137665 i37665 137665 137665 137665 137665 137665 137665 137665 137665 137665 .137665 137665 '137665 137665 137665 137665 137665 137665 137665 137665 '137665 137665 'PU FT O 0 0 0 LBS 94 635 0 1 0 HV 94 10 1 1 0 APl 94 31.0 1 1 0 DHHM 94 i2O 46 1 0 OHMH 94 i2O 44 1' 0 OHHH 94 220 6 1 0 US/F 94 52,0 32 1 0 US 94 522 32 1 0 US 94 522 32 i 0 US 94 522 32 i 0 US 94 522 32 1 0 MHHO 94 ilo 46 i 0 HMHO 94 11.0 44 I 0 LBS 94 635 0 1 0 AP1 94 3'1.0 I 1 0 IN 94 280 2 I 0 CPS 94 354 2 1 CPS 94 354 1 i 0 G/C3 94 350 1 1 0 G/C3 94 356 1 i 0 CPS 94 334 31 1 0 CPS 94 334 31 I 0 94 42O 1 1 0 SSPU 94 890 3 1 ,0 94 89.0 12 i 0 4 0 1 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 'i 68 4 0 1 68 4 0 I 68 4 0 I 68 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 OOOO00 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .000000 O00000 000000 000000 ,000000 000000 ,000000 000000 000000 000000 000000 000000 DEPT TTI CALi NPHI TEN TT2 DPHI SP TT3 NFDC DATA GR TT4 RHOB .RECORDS ILD CILD DRHO ILM CILM FCNL RLL3 TEN NCNL DT NRAT Page 5138.500 453.000 0.000 O,O00 5100,000 399.900 17,600 48.410 5000,000 414.900 18.580 59.630 4.900.000 455.900 15,190 1i,392 4800,000 393,000 17,i00. 32.690 4700.000 395,000 14,810 29,460 4600,000 411,,000 14,830 29,2i0 4500,000 463,900 16,520 37,720. 1692. 452. 468. O. 2147, 420. 679. 28. 1892, 465, 1691. 67, 1830. 432, 260, 2. 1805. 405. 439. 16, '1765. 400, 496, 24, 1755, 41'0, 510, 24, 1727, 415. 513. 19. 000 900 400 000 000 900 100 000 000 900 000 576 000 000 000 364 000 000 OOO 545 0'00 000 900 242 000 000 000 545 000 900 ,300 212 -30.000 675.000 587.000 -69.400 609. 000 611 ,400 -110,700 626.900 729,900 -51,90O 690,900 413.000 -56.8'00 601,000 5'70,900 -49,000 599,000 524,900 -42,400 630,000 553,900 -:30. 500 68 O, 000 633,200 0.000 668.000 2.730 89,800 622.900 2.18'8 61.800 691.900 1.535 36,100 670,900 2,611 83,4.00 61 4. 900 2.377 57,1.'0'0 599,0'00 2,250 42.400 625,000 2,245 84, '00 '0 626,900 2,,333 99769.875 0,000 -i4.560 5.861 i70,776 .090 23,659 42,361 .007 10,139 98,430 -,036 6.138 162.850 ,096 2,547 391,897 ,019 2,286 436.876 ,032 5.610 178,182 ,145 5,483 181.982 0,000 5,483 i 82,068 53,800 24,889 40.122 45.900 13,305 75,3i0 189.900 5,483 102,354 87.900 2.636 379,026 105,000 2,.483 402,509 98.000 5,117 i 95.1 02 77,400 9,016 2022. 000 0.000 7.925 2642.000 176,900 22,751 2736. 000 172,900 22,182 2598.000 393,200 6,266 2529.000 228,000 4,246 2426,000 273,900 4.276 2398,000 268,900 5.689 2369,000 2i7,400 0.000 0.000 0,000 115.200 i 03. 400 3.281 133.900 55.300 3.609 60.000 39,200 1,995 1 01 , 1 O0 82.400 2,623 1 07. 700 52,900 2.413 1 07,900 44.900 2,505 1 09. 600 82,400 2,801 DEPT TT1 CALl NPHI TEN TT2 FFDC DPHI SP TT3 NFDC DA GR TT4 RH08 TA RECORDS IL[) CILD DRHO ILM CILM FCNL RLL3 TEN NCNL DT GR NRAT Pmgm 4400.000 348.900 17.070 5i.740 4300,000 452,900 16,560 47,900 4200,000 450,000 16,390 39,470 4100,000 433,900 17,690 63,540 4000,'000 450.000 15.7~0 31,700 3900.000 487,000 16.260 28.790 3800.000 478.900 15,960 31.660 3700,000 427,900 18,560 59,210 1717.000 467.000 600.800 34.727 1644,000 482.900 645.3.00 32.606 1633,000 403,000 494,500 17,939 1576.000 419.000 1308,000 66.000 1551,000 458,000 533,500 23,394 537, .000 497,900 447,200 i9,515 1468,.000 475.000 377,100 29,697 1459.000 428,000 '1937,200 74,909 -23.800 583,900 608, i O0 -24.600 726.900 589,000 -48.500 803,000 608. 000 -36,500 652,000 643,600 -16,400 714..000 602. 600 -24,00:0 785.900 529,000 -50,900 748,00'0 526,200 -81,800 658,000 672,600 65.600 673.900 2.077 61 .100 761 ,900 2.112 89.800 649,000 2.354 59.900 648.900 1,561 44,700 714.000 2.264 49,5:00 798,900 2,328 68,3.00 763.9'00 2,160 16.8.'00 657. O00 1 ,414 7.870 127.225 .078 6,383 156.622 ,066 5.984 167,226 .138 17,660 56.570 -.OiO 3,828 260.743 ,120 4.519 22i .782 .106 7,112 140,626 ,105 35,075 28,549 -,042 7.413 134.968 68,900 6,138 162.799 69,000 5.248 190,733 69,900 15,885 62.837 46,200 3,258 306,471 11 o.,ooo 3,999 25 O. 088 131 .700 5.470 183. 169 180,000 41,020 24,339 43,500 10. 023 2340. 000 208. i O0 8,492 2326.000 190.000 6.950 2300,000 200,000 17.338 2249,000 167,100 4,102 2219. '000 280.900 5.47'0 2155. 000 301 ,800 7.178 2132. 000 305. 400 28,774 1983,000 170,800 123.700 61 ,800 3.i37 127.400 57.i00 2.952 116.300 85.800 2,837 137,500 58.i00 3,5i7 1 09. 700 41 ,700 2,512 111,700 46,800 2.287 122,900 66,70'0 1,782 144.600 17.200 3,689 DEPT TTI CALl NPHI TEN TT2 FFDC DPHI SP TTJ HFDC DATA GR TT4 RHOB .RECORDS ILD CILD DRHO ILM ClLH FCNL RLL3 TEN [,l C N L DT NRAT Page 3600,000 483.900 26.650 3500,000 465.000 16,930 38,400 3400,000 491,000 16.i50 J300.O00 448,900 15,670 39,920 3200.000 432,900 14,810 43.920 3100,000 456,900 15,790 45,630 3000,000 482,000 17 43,03 0 469.i000 16,750 28.490 1415.000 4~0.000 492.700 26.364 1394.000 488.900 498,900 21.758 1317,000 448.900 511,$00 29.636 1316,000 392. 000 480. 900 24.303 1278,000 437,900 30,788 1249,000 521,900 490,900 23.758 1472, 000 517,000 614,500 25,758 1399,000 468,900 513,500 -29,200 789.000 516.200 -13.500 751 .900 546.200 -58,200 713.000 511,700 -17,000 692,900 539.000 -35 800 684.000 522,000 -23.600 705.000 554,500 -13,700 775,900 576,300 -12.300 715,000 520,000 49.900 775. 000 2.215 62.600 769.900 2,291 49, '000 668. 000 2.161 64.3'00 631,00.0 2.249 71. 100 932,000 2,142 59.3.00 766,900 2,258 57,500 776,900 2.225 46,5.00 71 3,9:00 2,220 4. 634 216,043 -.0i6 4.325 231 .683 , 079 12. 134 82,574 -. 020 4,842 206,302 .020 9,506 1 05,054 ,023 5.834 171,036 ,052 6. 039 165.868 ,040 4,150 240,565 ,014 4,539 220.508 126,200 3,622 276.365 81.700 8.933 111,805 179.900 4,467 223.912 66. OOO 8.166 122,447 70,000 5,333 187,447 64,500 5,370 186,083 58,100 4,159 240,517 108.000 6.209 i971.000 265.400 4.943 1996.000 226.300 10,399 189~,000 339,000 5.346 1782,000 209,000 7,962 1833,000 203.600 6, '1 09 i 751. 000 2i0,800 5,572 1774,000 194,400 4.808 1793,000 266,200 163,000 46.600 2.i33 1'20.000 6i .400 2.987 152.500 47. 000 i .839 121 ,600 58,200 3,057 136,500 69.400 2,831 123,800 56,200 3,007 127,200 51 ,200 3,152 120,200 44,400 2.400 DEPT TT1 CALI NPH i TEN TT2 FFDC DPHI SP TT3 NFDC DATA GR TT4 RHOB RECORDS ILD CILD DRHO ILM CILM FCNL RLL3 TEN NCNL DT HRAT Page 1[ 2800,000 513,000 16.370 25.660 2700.000 544.900 17.360 46,080 2600.000 553..000 i5.300 40,860 2500.000 574.900 17,450 45,5i0 2400,000 467.'000 15,930 44,250 2300.000 526,000 16.220 49,200 2200. 000 619, .,0.00 15,410 42,860 2100.000 529.000 16.,080 43.840 1365.080 507.000 426.000 23.636 1311,000 550,900 542,000 30,121 1272.000 597,000 579.000 26,606 1244,000 537.000 785.900 34.424 1224,00.0 49'0,900 535,400 25,576 '1'189,.000 524,000 606,200 21,576 165. 000 5'03,000 794,5.00 26.970 1127,'0'00 5'11.900 588,100 27.212 -32.900 808. 000 486. 000 -1 .400 8i0.000 545.000 5.000 823.900 552.000 -13,1.00 858,000 691,900 -ii,900 711,000 566,300 1,6'0,0 795,000 603,50.0 -11 ,500 821 , ~OOO 646, ,3.00 -2,9.00 783,00'0 556.300 45.900 796.900 2.260 50.700 828,000 2,153 53.700 863.900 2,2il 42.600 829,000 2,082 59,500 736,00.0 2.228 54,100 794,9'00 2,294 42,400 752,-OO.O 2,205 36,900 823,900 2.201 9.550 i 04. 849 -. 009 4,710 2i2,760 .042 4,753 210.810 ,0i6 7,261 137.506 ,053 5,420 184,282 .053 4,246 235,365 ,09i 3,404 293,155 ,057 2.208 453,439 ,04 i 8,166 122,363 1i4.500 4,064 246.455 64,400 4.285 232.982 55.400 8,110 123,130 59,000 5.358 186,599 54,'000 4,406 226,626 46,300 3.698 269,999 56.900 2,36'0 424,425 57,200 9,311 1710.000 278,900 4,656 1625.000 194,400 5.284 1592.000 20i.700 8.933 1581,000 175,400 6,209 146i , 000 i 7I, '000 5.236 i424,000 i55,400 4,710 1369,000 177.900 '3,373 1344,000 178,100 141.200 43,600 2.258 139.700 58.400 3.028 136.400 6,800 3.i93 127.200 42.300 2.828 225,800 49,600 3,096 190,400 48.800 3,282 184. 000 40.700 3,142 131 .200 36,400 3,00t DATA RECORDS DEPT TT1 CALl NPHI TEN TT2 FFDC DPHI SP TT3 NFDC GR TT4 RHO8 ILD CILD DRHO ILM CILM FCNL RLL3 TEN N C N L DT GR NRAT Page 11 2000 590 17 54 1900 300 15 59 1800 -999 15 58 1700 -999 15 62 1600 -999 15 75 1500 -999 15 71 .00 .90 ,60 ,000 .000 ,600 .720 ,000 ,250 .530 ,090 ,000 ,250 .530 ,310 ,000 ,250 ,530 .820 ,000 .250 .540 ,790 1400,000 -999,250 15,570 65.580 130 .-99 1 6 0',000 9,250 5,570 5,170 1088,000 614.000 550.800 36,485 1 072,000 307,900 113,900 34. i 82 -999,250 -999,250 218.100 56,121 -999,250 -999.250 220.000 66,364 -999,250 -999,250 251,500 68,000 -999,250 -999,250 297.100 76,485 -999,250 -999,250 297,300 75,979 -999,25'0 -999,250 333,2'00 77.758 -10.200 888.900 542,600 -1 00. 1 O0 751. 000 113,900 -999.250 -999,250 122.600 -999,250 -999,250 123,300 -999,258 -999,250 128,200 -999,250 -999.250 120.000 -999,250 -999 o= ,~0 1 06,600 -999,250 -999.250 128,200 42.700 896. 000 2,048 24.900 585.000 2.086 -999,250 -999,250 1,724 -999,250 -999,250 1,555 -999,250 -999.250 i,528 -999,250 -999,250 1.388 -999.250 -999.250 1 ,397 -999.250 -999,250 1.367 2.188 458,027 ,098 99769.875 0,000 -.977 -999,250 -999,250 -1 . 002 -999.250 -999,250 - 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OOO 149,900 -999,250 881 , 000 157,900 -999,250 838,000 134.000 '-999,250 813,000 138,000 -999.250 22.300 3.438 -999,250 23.200 ..3,7i '2 -999.250 36,400 3.533 -999,250 22,800 3,791 -999,250 21,60.0 3.814 -999,250 33,500 3,404 -999,250 28,400 3,836 -999,250 26,500 ~,892 DATA RECORDS DEPT TT1 CALI NPH i TEN TT2 FFDC DPHI SP TT3 NFDC GR TT4 RHOB ILD CILD DRHO ILM CILM FCNL RLL3 TEN NCt,IL D T GR NRAT Page 13 400.-000 -999.250 15.4~0 56.~10 -999,250 -999.250 64,900 4.667 -999,250 --999,250 127.400 -999,250 -999,250 2.573 -999,250 -999,258 -.787 -999,250 -999,250 44.000 -999,250 771,000 162.000 -999.250 i8.800 3.634 FILE TRAILER **** File name: &GSF01 .0'01 I',la×imum length: 1024 TRRILER RECORDS Service name: File t~pe: LO Version Next f'ile: Date: Page 14 File namm~ ..0:02 Service name: Version #: Date: Haximum length: 1024 File type: LO Previous MHEM CN WN FN COUN STAT CTRY AP IN LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DMF RUN TIME DATE LOC SON LUN FL LUL ENGI td I T N DD DL CBL1 TLI BLI TC9 TLA8 8HT MRT MT MSS DFD I"lV I 9 DFPH DFL R H RHF i"IFST HFSS RHC CONTENTS UNOCAL TBU 6-40 McARTHUR RIVER KENAI BOROUGH ALASKA LISA 20412.000 .......... O.Deg. 0 Min. O 0 Dmg. 0 Min. 0 OgN .......... 13W .......... 103, OOO ..... 102,000 ..... -I~7,00'0 . . , HS 1903,000 . . 2/ 2/'90, , . 137665 , 6-8612 , STERLING STERLING SCHIAVI/YEE KI LOH 5135,000 5i 32. OO,O . i 926,0 O0 , . 1925, OOO , . i 925,00'0 , , 5130,000 , . 80'0,000, . . 1407,000 , . ii 8 . O00o . , i '1 8~ 000 , DEr I~ 0 C U l-'- A l ~D FLOWL I tie 9,4'0'0 ..... 39,000 .... 7,5'00 ..... 9.200 ..... 1 , '1 '00 ..... ,950 ...... 68,0 O0 .... MEASURED , i 4850 t m ! m INFORMAT.ION RECORDS AP1NUM: '50-733-20412 ..... DATE LOGGED: 02- 02-90 ................ IllIlIItllIllllllImlllmllII]llllllll laliJlIalIllltlBlIIJIIlJIIIIlIIiIIII IIIlIIIIllIIIIIIIlIIIlIIIlIIIlIlJIlI 0 Sec, N ........................ 0 Sec W .................. 4. I i i m i I · ,! ,i iati,ii mi m , I . I· a I · I I, I a I 4. I . m I I I m I m l i i mi m I, m i m 4. m m , . I m . ! . , I , m , m m I I m m m m i ,i ! I UNIT TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 O 0 34 65 O 0 34 65 0 0 2 65 0 0 3 65 O 0 S 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 '0 3 2 65 0 0 2 79 0 0 4 68 0 0 8 65 .0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT ,0 3 4 68 FT ,0 3 4 68 FT O ~ 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 1 4 68 0 2 20 65 O 2 ~ °O65 LB/G 0 2 4 68 CP O 2 4 68 O 2 4 68 0 2 4 68 OHMH 0 2 4 68 Oi4HH 0 2 4 68 DEGF 0 2 4 68 O 2 12 65 OHHM 0 2 4 68 Page. ERROR 15 I NFORMAT~I ON RECORDS Page 16 MHEI'I CONTENTS UNIT TYPE CATG SIZE CODE ERROR MCST MCSS CS 68.000 ................................................... MEASURED ............................................ 16.00-0 .................................................. i4.750 .................................................. DEGF 0 2 4 68 0 2 is., 65 0 3 4 68 0 3 4 68 COMMENT RECORDS Well Location'Comment 1: 1900' FSL &1459' FEL Well Location Comment 2: GRAYLING PLATFORM Well Location Comment 3: LEG #1, CONDUCTOR #25 Well Location Comment 4: Well File Comment 1: CHLORIDES: 5000 PPM, DDL SYSTEM AND Well File Comment 2: DIL/BCS/GR RUN IN COMBINATIOH. Well File Comment 3: CDL?DSN?GR RUN IN COMBINATION. TOOLS USED TO LOG WELL, Well File Comment 4: LIS tape written bY: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which Halliburton curve and tool mnemonicz, moz.t closely match HALLIBURTON TO SCHLUMBERGER TOP BOTTOM .MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 396,0:0 515'0,00 TEN2 GEN LBS TEN GEN LBS 4867,00 5'137,50 SP2 GEN MV SP GEN MV 4867,00 5i37,50 GE2 GEN APl GE GEN APl 4867,00 5'137,50 ILD2 DIL OHMM ILD DIL OHMM 4867,.0'0 5i37,50 ILM2 DIL OHMM ILM [)IL OHMM 4867.,00 5'137,50 ELL32 DIL OHMM RLL3 DIL OHMM 4867.'00 5137.50 DT2 8CS US?F DT 8CS US/F 4867,00 5'137,50 TT12 BC$ US TT1 8CS US 4867,00 5'137,50 TT22 BCS US TT2 8CS US 4867.0,0 5'1~7,50 Page 17 TT32 TT42 CILD2 CILH2 TEN3 GR3 CALI3 FFDC3 NFDC3 RHOB3 DRH03 FCNL3 ~C~L3 NRflT3 NPHI3' DPHI~ 8CS BCS DIL DIL GEN GEN CDL CDL CDL CDL CDL D.SN D$'N DSN DSN CDL US USEC MMHO MMHO LBS AP1 IN CPS CPS G/C3 G?C3 CPS CPS SSPU PU TT3 TT4 CILD CILM TEN GR CALl FFDC NFDC RHOB DRHO FCNL NCNL NRAT NPHI DPHI 8CS 8C$ DIL DIL GEN GEN CDL CDL CDL CDL CDL DSH DSN DSN DSN CDL US USEC MMHO MMHO LBS APl IN CPS CPS G/C3 G?C3 CPS CPS SSPU PU 4867,00 4867.00 486?°00 4867.00 4867.00 4867.00 4867,00 4867.00 4867°00 4867.00 4867.00 4867, O0 4867. O0 4867, .00 4867, ;O:O 4867. :i00 5137o50 51,.7,7.50 51:37,50 5137.50 5137,50 5'137,50 5137.50 5137.50 51 '37,50 5137.50 5137,50 5137.50 5137,50 5137,50 5137.50 5137,50 DATA FORMAT ;~ EHTRY. BLOCKS EHTRY TYPE DESCRIPTION 16 Datum zpeci?ication block sub-tppe 0 Terminator ( no more entries ) TYPE 0 SIZE .SPEC I F I CA T I.OHS CODE G6 Page DATA 'FORMAT SPECIFICATIONS DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE APl API API API FILE ID ORDER # UNIT LOG TYPE 'CLASS MOD # ~mmw DEPT TEN 9EN SP 9EN 9R GEN ILD DIL ILM DIL RLL3 DIL DT BCS TTi BC9 TT2 BCS TT3 BCS TT4 BCS CILD DIL ClLM DIL TEN GEN GE GEN': ,CALl CDL FFDC CDL NFDC CDI. RHOB CDL DRHO CDL FCNL DSM NCNL DSM NRAT DSM NPHI DSM DPHI CDL i37665 137665 137665 137665 137665 137665 137665 "137665 137665 '137665 .137665 137665 137665 137665 137665 137665 137665 137665 '1'37665 1'37665 137668 '137665 "137665 FT 0 8 0 0 2 LBS 94 635 0 3 I API 94 310 OHMM 94 120 46 3 1 OHMM 94 120 44 3 i OHMM 94 220 G 3 1 US/F 94 52.0 32 3 1 US 94 523 32 3 1 US 94 523 32 3 1 US 94 522 32 3 1 USEC 94 522 32 3 i MMHO 94 ll.',O 46 3 1 MMHO 94 118 44 3 LBS 94 635 0 3 1 APl 94 31.0 IN 94 280 2 3 1 CPS 94 354 92 3 1, CPS 94 354 1 3 i ~/C3 94 350 ~/03 94 356 1 3 CPS 94' 334 31 3 i CPS 94 334 30 3 1 94 420 $SPU 94 890 3 3 i PU 94 89,0 12 3 1 PRC # SIZE LVL SMPL RC 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 4 0 1 68 4 0 1 68 4 0 '1 4 0 1 68 4 0 1 4 0 1 68 4 0 1 4 0 1 4 0 1 68 4 0 '1 4 0 1 4 0 1 4 0 1 ',68 4 0 '1 68 4 O i 68 4 0 '1. 68 4 O 1 4 0 1 :68 4 o 1 4 o 1 4 o i 4 o i es PROCESS INDICATORS 000000 000000 000000 000000 O0000O 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 O00OO0 000000 000000 000000 ~000000 O0000O 000000 O0000O 000.000 000000 000000 OOO000 O0000O 000000 000'000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O O000OO 000000 .000000 O0'O,OOO 000000 OOO00O 000000 000000 :!O000O 00000'0 000000 O00OO 000008 O00000 00000 000000 000000 00000 .00000,0 000000 .lO0000 O'OOO00 000000 00000 000'000 000000 ~000000 00000'0 000000 pO0000 000000 000000 Page 1S DEPT TT1 CRLI NPHI 5137.500 434.000 12.340 0.000 5100,000 398.000 17,680 45.110 5000,000 407,900 18,580 57.480 4900,~000 448.000 i5.200 i2,ii9 TEN TT2 FFDC DPHi 1781,000 439.000 453.300 8.303 2225,000 418.000 667,900 26,182 2132,000 448,900 1639,000 66,061 2103,000 435,000 248,000 1,879 SP TT3 NFDC -58,000 659,000 588,200 -70.500 608. OOO 606,900 -114.400 616,900 707,900 -54.500 682, 0 O0 415,900 DATA GR TT4 EHO@ 0,000 652,000 2,5i3 88,900 621.000 2,21'8 57,200 663,900 1 ,560 36,1.00 666,000 2,619 RECORDS ILD CiLD DRHO ILH CILH FCNL RLL3 TEN NCNL DT 6R NR~T 99769. 875 O,O00 -5.9i9 5.433 iS3,960 O.OOO 9.226 2024.000 0,000 0,000 0,000 0,000 5,794 i72.797 ,103 5,483 i82,019 56,'000 7,780 2698.000 181,000 116.400 iiO.400 3,144 24,.831 40,296 ,019 10,186 98,i65 -o018 25,1 77. 39,631 44,900 13,366 74,752 208,900 23,335 2574,000 162,000 19,770 2574,000 440.900 138.700 58.700 3,57i 62,800 ~,500 i,956 Page '20 FILE TRAILER File name: &G5F01 ,002 Maximum length: 1024 TRAILER RECORDS Service name: Version #: File type: LO Next &ile: Date: Page 21 REEL TRAILER **** Service name: &G5F01 Date: 90/03220 Commentz: Origin: Reel name: 1~7&65 Continuation ~: 01 TAPE' TRAILER **** Service name,: &GSF01 tape Date: 90/03/20 ~omment~: Origin: Tape name: 137665 Continuation #: 0t REEL HEADER .*** .* Smrvice name: Previous reel: Date: 90,:'03/20 Comments: HEADER RECORDS Origin: Reel name: 137687 Pmge Contir, uation #: Oi Service name: &GSF01 Previous tape: Date: 90703/20 Comments: Origin: Tape name: 13.?,7687 Continuation :+:** FILE HEADER **** File name: ,001 Service Version ,#: Date: Maximum length: '1,024 File type: LO Previous ?ile: INFORMAT.ION RECORDS F'agm MHEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR CN him FH COUN STAT C'TRY AP 1N LATI LOHG SECT TOWN RANG EK8 EDF EGL PD LMF RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DD DL CSDi CSL~ TLI BL.I TCS TLA8 BHT MAT MT DFD HVIS DFPH DFL RN RHF MFST MFSS RHC UNOCAL TBU G-40 HcARTHUR RIVER KENAI ALASKA USA 20412,000 ..... 0 Dmg, 0 Min 0 Dmg, 0 Min 09N ..... I~W ..... iO~,.O00. 102.000, -117.000 HS ........ K8 ....... KB ....... 104,.000, , i'O/ 3/9.0 ,, i37687 ,, G-86i2 ., STERLING STERLING SCHIAVI KILOH ii267,'000, 11200,000, 5.125,000,, 5118,000,, 5118,000,, 11197,000, °4~,,.000 1643,00.0,, i~O,O00,,, i6.0,000,,, DEFLOCUL~TED FLOWLINE 9,50'0, , 52,00.0 , '9',5.00, , 7,200, , .420,, , ,3eo,, . 46,00'0 , MEAS, 45.0 AP1 HUH: DATE LOGGED #IIIllI II IllIII, I, 0 Sec 50-733-20412' 0-90 03- N W i . i i i i i a 0 0 40 65 0 0 4 0 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 :3 65 0 0 ~ 65 FT 0 3 4 68 FT 0 3 4 68 FT O 3 4 68 0 ~ 2 65 0 3 '2 65 0 .3 2 65 0 0 2 79 0 0 4 68 .0 0 8 65 0 0 '2 79 0 0 i 0 65 0 0 10 65 0 0 2 0 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 .3 4 68 FT 0 3 4 68 FT 0 3 4 G8 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 6,8 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 i 4. 6:9 0 2 20 65 0 2 20 65 LB,."G 0 2 4 6,8 CP 0 2 4 68 0 2 4 68 O "" ~ 4 68 OHMH .0 2 4 68 OHHH .0 2 4 68 DEGF 0 2 4 6,8 0 2 12 65 OHMM 0 2 4 68 MNEM MCST HCSS CS BS INFORMAT.ION RECORDS CONTENTS UNIT 4~.000 ................................................... MEAS ............................................. i~.375 .................................................. I~,250 .................................................. DEGF TYPE CATG SIZE 4 12 4 4 CODE 68 65 68 68 Page ERROR COMMENT RECORDS Well Location Comment 1: Well Location Comment 2: ~ell Location Comment 3: Well Location Comment 4: Well File Comment i: DDL ~ell File Comment 2: Well File Comment 3: Well File Comment 4: 1900' FSL & 1459~ FEL S~1PALTFORM ~RAYLIN~ LE~ #1, CONDUCTOR #25 SYSTEM AND TOOLS USED TO LOG WELL, ~+;~¢ LIS .tape written bp: ANCHORAGE CO~IPUTING CENTER · ~ All curve and tool mnemonicz uzed are t.hoze which mm Halliburton curve and tool mnemonicz, most closely match HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SERVICE UNIT. DEPTH DEPTH DEPTH FT DEPT FT 4957.00 11205,00 TEN DILBCS LBS TEN DILBCS LBS 4972,50 11199.50 SP D, ILBCS NV SP DILBCS NV 4972,50 11'199,50 GR DILBCS API GR DILBCS API 4972,50 11199.50 ILD [)IL OHMN ILD DIL OHMM 4972,5,0 11'199.50 ILH DIL OHNN ILM [)IL OHHH 4972,50 1'1199.50 RLL3 DIL OHMM RLL3 DIL OHMM 4972,50 ii199,50 CTEH DILBCS LBS CTEN DILBCS LBS 4972,5'0 11199.50 DT BCS US/F DT BCS US/F 4972,50 11'199.50 TTI BCS US TT1 BCS US 4972,50 11'199.5'0 Pmge TT2 TT3 TT4 TEN1 CALI 1 CTEN1 FFDCI NFDCl RHOBI DRH01 FCNL 1 NCNL 1 CILD ClLM NPHI1 DPHI1 NRflT 1 BCS BCS BCS CDLDSN CDLDSN CDL CDLDSN CDL CDL CDL CDL DSN DS'N DSN CDL DSN US US US LBS API IH lbz CPS CPS G/CS CPS CPS MMHO MMHO SSPU PU TT2 TT3 TT4 TEN GR CflLI CTEN FFDC NFDC RHOB DRHO FCNL NCNL CILD CILM NPHI DPHI HRAT BCS BCS BCS CDLDSH CDLDSN CDL CDLDSN CDL C'DL CDL CDL DSN DSN DIL DIL DSN CDL DSN US US US LBS API IN lbs CPS CPS CPS CPS MMHO MMHO SSPU PU 4972,50 4972,50 4972,50 49?2.50 4972,50 4972.50 4972,50 4972,50 4972.50 4972.50 4972.50 4972.50 4972,50 4972.50 4972,50 4972.50' 49?2.5'0' 49?2.50 11199,50 11199.50 11199,50 11199,50 11199,50 11199,50 11199.50 11199.50 11199,50 11199,50 11199.50 11199.50 1't199,50 11199.50 t1'199.50 11199.50 ,, 11199,50 !1!99,$o DATA ~'-~ ENTRY BLOCKS ENTRY FORMAT .SPEC I F I CA TYPE SIZE CODE TIONS Page ENTRY BLOCK LEGEND ~:~ TYPE DESCRIPTION 16 Datum specification 0 Terminator ( no more block sub-tppe entries ) FORMAT SPEC l F I IONS ~** DATUH SPECIFICATION BLOCKS Page SERVICE SERVICE HNEbl ID ORDER # APl API APl API FILE UNIT LOC, TYPE 'CLASS HOC, ~ PRC # SIZE LVL SHPL RC PROCESS iNDICATORS DEPT TEN SP GR ILD ILM RLL3 CTEN DT TT1 TT2 TT3 TT4 TEN CALl CTEN FFDC NFDC RHOB DRHO FCNL NCNL CILD CILM NPNI DPHI NRAT D I LBCS D I LBC.S DILBCS D iL D IL D I L DILBCS BCS BC:S BC:S BCS CDLDSN CDLDSN CDL :CDLDSN COL CDL COl. COL DSN DSN OIL OIL DSN COL D~ N 137687 137687 137687 137687 i37687 137687 137687 i37687 i37687 137687 i37687 137~87 ,137687 137687 137687 137687 137687 i37687 137687 i37687 137687 137687 137687 137687 137687 137687 137687 137687 FT 0 O 0 0 1 4 0 1 LBS 94 635 0 1 0 4 0 1 HV 94 10 i 1 0 4 0 i APl 94 3i0 1 1 O 4 0 i OHMH 94 120 46 i 0 4 0 i OHHH 94 i20 44 i' 0 4 0 1 OHHH 94 220 6 i O 4 0 1 LBS 94 0 0 1 0 4 0 1 US/F 94 520 32 1 0 4 0 1 US 94 522 32 1 0 4 0 1 US 94 522 32 1 0 4 0 i US 94 522 32 1 0 4 0 1 US 94 522 32 i 0 4 0 i LBS 94 635 0 1 0 4 0 1 APl 94 310 i 1 0 4 0 1 IN 94 280 2 1 0 4 0 1 lbs 94 .0 0 '1 0 4 0 1 CPS 94 354 2 1 0 4 0 CPS 94 354 6/C3 94 35:8 I 1 0 4 0 1 6/C3 94 356 I i 0 4 0 1 CPS 94 334 31 1 0 4 0 1 CPS 94 334 30 i 0 4 0 NHHO 94 110 46 1 0 4 0 1 HHHO 94 118 44 i 0 4 8 i SSPU 94 89,0 3 1 0 4 0 i P,U 94 890 12 94 42~0 i i O 4 0 1 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~0 0 0 0 o 0 0 0 0 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 O00000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 O00OO0 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 00000'0 000000 00000 000000 000000 00000 O0000.O 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 000000 000000 00000 O0000O 000000 DEPT DT CTEN C! LH 11199.500 0.000 0.000 393,550 11100.000 109,600 i420.000 280,543 11000.000 63.000 1442,000 111,430 10900.000 78,700 1506,000 232.809 10800,000 79,200 1475,000 284,446. 10700,000 70,200 1530.000 157.761 10600,000 76,700 1401,000 43,752 10500,,000 73,300 1456,000 133,968 DATA RECORDS TEN TT1 FFDC NPHI SP TT2 NFDC DPHI GR TT3 RH08 NRAT ILD TT4 DRHO ILM TEN FCNL RLL3 GR NCNL 3880,00 0,00 0,00 O,OO 4581.000 422.000 829,900 42.820 4648,000 274,900 512,100 17.843 4499,000 328,000 818,900 31,72.0 4380.000 302,980 387,700 22,400 4388,000 281,000 360,000 16,252 4336,.000 329,900 496,600 25,490 4274,000 287.900 354.400 19,990 40,200 0,000 0,000 -8.121 7.200 429,000 664,900 40,424 -19.800 264,900 677.700 14,970 11 ,500 336. 000 780, 000 3;3. 697 -9,80,0 303,900 505,400 18,121 -.37,2 O0 278,000 493,300 1.3,333 -24,1 O0 31 .9, 000 585,4.0 O 13, 152 -56.600 289,900 513,200 11,636 0.000 0.000 2.784 0,000 58.100 640,900 1.983 47,600 401 ,900 2,403 1 ,383 95,500 496.900 2,094 ,783 60,700 459,000 2,35i 1,477 68.700 429.900 2.430 2.254 41,800 487.900 2.433 ,952 50.1 '00 444,900 2,458 1 ,713 2,051 0,000 -16,697 4,018 646,900 .064 i 3,092 394,900 .172 4,667 502,900 ,189 3,954 458,900 ,013 7.709 424,900 ,044 6,761 481 .900 ,150 1 O, 568 4.35.900 ,037 2,541 3190,000 0,000 3,565 4927.000 289,500 8,974 4754,000 i79,900 4,295 4716,000 255,008 3,516 4751,000 195,108 6,339 4645.000 164,400 22.856 4705,000 226,900 7,464 4558,000 185.600 2,606 0,000 0.000 5.610 1~ 8,io0 2 000 13,032 45,700 248,800 4.477 88.300 204,400 4.6'03: 57,400 29i. I O0 8,590 64,000 385,900 6.266 39,100 212,100 10, 328 48.100 329.900 CTEN CALl C iLD 0,000 -.700 487,529 694.000 i8.220 248,886 706. 000 15,460 76.384 708,000 i6,800 214,~g 664, 000 i2.ilO 252,930 699,0 O0 i2,760 129,718 691 , 000 18,270 147,9i 1 673,000 13,380 94.624 P~ge DEPT DT CTEN CILH TEN TTI FFDC NPHi SP TT2 NFDC DPHI DATA GR TT3 F',HOB ),IRAT RECORDS ILD TT4 DRHO ILM TEN FCNL RLL3 GR N C N L CTEN CALl CiLD Pag~ 1 0400 78 1483 140 1 0300 74 1483 1 0200 70 1470 21 1 O1 O0 74 1438 132 I0000 78 1437 135 99 14 1 98 14 1 97 14 1 .000 .500 ,000 .929 .000 .600 ,000 ,893 ,000 .500 .000 .979 ,000 ,300 ,000 .739 ,000 .100 , :000 .207 00.000 71.100, 66.000 27,057 00.'000 88.700 80,,000 61.808 O0. '000 66,500 70.000 54, 170 4421.000 290.000 388.700 17,255 4190.000 283.000 313.300 14,934 4146,000 275.000 325,500 14,272 4081 , 000 290,900 346.600 16,991 4042,000 297.000 395,400 19,285 3984.00'0 281 .900 335,500 13,446 3925,0'00 337,000 301,100 30,300 3925,000 301,900 368.800 19,700 -73 284 499 15 -73 287 463 13 -88 269 472 11 -80 294 504 iO -64 296 494 15 -94 284 485 10 -74 363 471 27 -78 311 8 .000 .000 .900 .636 ,500 ,000 .300 .273 .3'00 .000 .200 .576 ,400 .900 .300 ,200 ,900 ,300 ,333 ,9.00 ,900 ,40'0 ,121 ,800 ,000 ,200 ,697 .400 .900 .500 ,788 54.100 442,000 2.392 1.816 51 .500 435.900 2,431 2.714 45.600 418.900 2,459 2.430 52.500 423.000 2,484 1,984 47.600 457.000 2.397 1,805 47, '100 428.900 2,483 2,574 67,9'00 540, '000 2,193 1 . ,032 60.000 435,900' 2,505 i,523 7.311 435. 000 ,0i7 8. 730 432.900 -,001 18. 072 415.900 .019 9,750 432,000 ,060 9,036 453,000 ,011 12,706 430,900 ,025 7,194 542,900 9.886 452.900 .026 7,096 4841,000 i69.i00 6.808 4500. 000 157,300 45.499 4477. 000 153,90'0 7,534 4443,000 170.000 7,39~ 4381,',00 179,200 7,870 4209,000 149,300 6,180 4372,:'000 248,800 6,486 4199,000 186,500 8.375 50.000 3i2,i00 11,350 49,20.0 437,600 17.061 42,800 386.500 11,220 45,900 345.500 11,041 45,800 327,700 16,672 43,700 404,300 64,700 257.50.0 10,023 55,300 292,100 683. 000 i2,600 i36. r,'J 685.000 i2.660 114.551 669,000 i2,630 55.335 698.000 13,450 102,565 674. 000 12.450 11 O. 662 697,000 12,450 78,705 686,000 17,940 138,995 685.000 14,330 101.158 DEPT DT CTEN C ILH TEN FFDC NPHi SP TT2 NFDC DPHI DATA GR TT3 ~H08 NRAT .RECORDS ILD TT4 DRHO ILM TEN FCt,iL RLL3 GR NCNL CTEN CALl C:iLD Page 9600.000 75,500 14i3.000 i33.045 9500,000 112,200 1396,000 i07.895 9400.000 81,300 i525.000 178,238 9300,:000 i'02.700 1412,000 310.456 9200.000 79.700 1515,'000 99,770 9100,000 76,000 2288,.000 127.644 9000.000 79.3.00 1401,000 108.893 8900,000 79,700 1470,000 150,66i 3924,000 287,900 352.i00 17.780 3858,000 281,000 1693,300 56.940 3791,000 297,000 355,400 25,020 3782,000 400,000 587,600 45,950 3717, 00'0 303,000 520, 000 30,700 3729,000 307,900 1303,200 25,350 3654,.000 312,900 27'1,100 27,34,0 3601 , 0'00 309,900 362. i 00 19, 171 -87,600 288,900 493,200 13,758 -83,000 283,000 729.900 59.030 -67,800 291,000 506,500 10,06i -51,200 398.900 545,500 29,.030 -60,100 303. 000 542,200 16,727 -25,30,0 302,900 706.600 55,152 -55,300 311,000 450.000 6,242 -39,000 305,900 475.500 15,939 50,700 44i.900 2.423 1.968 69,400' 464.000 1,676 ,492 82,500 469.000 2.484 1,174 69. 200 609.9.00 2.171 ,677 1 0.0,6'00 467,9'00 2,374 .820 96.800 454.9'00 1,740 1,107 94,9,00 482,00O 2,547 1,252 46,100 481,9:00 2.387 1.969 10,814 442.900 ,02i 11,940 462,000 ,025 6.310 460,900 ,092 3.475 624.900 ,077 15.346 458,900 ,036 8,954 455,000 .094 10.399 479.000 -,003 11.169 474,900 -.,003 7.,516 421 O, 000 i7i .400 9,268 4423,000 322,500 5,610 4061, 000 2i6,700 3.221 406~.000 296.300 1 O, 023 4098. 000 247.800 7.834 4052.'000 223.400 9.183 3869,000 233.700 6.637 178,900 10.839 50,300 349.900 14,791 48,700 150.000 8.337 80,700 257,700 5.140 70. i O0 206,5'00 14,894 93. 600 208,700 11,535 84.300 253,200 9,333 95,400 305,400 10,864 41,500 352.200 671 . 000 i2.430 92.470 688,000 i6,860 83.753 676,000 14,670 i58.489 734.000 15,800 287,740 687,000 15.140 65,i63 676,00'0 16,380 111,686 710,000 i8,110 96,161 692. 000 12.540 89,537 DEPT DT CTEN CILH 8800 89 1435 192 8700 85 1491 22~ 8600 i27 1474 234 8500 80 1508 141 8400 82 144~ 161 8300 79 1449 145 8200 77 1473 92 ,000 ,400 .000 ,309 TEN TTJ FFDC NPHI .000 .200 ,000 ,357 3563 407 351 34 .00 .90 ,00 ,09 ,000 ,300 ,000 .423 3513 308 411 22 ,00 .00 ,20 .07 ,000 .600 ,000 .579 :3480 355 2065 73 .00 .00 .40 .000 ,500 .000 ,436 :35'02 33'1 28 .00 ,90 ,50 ,23 . '000 .600 , '000 ,881 3405 310 599 31' .000 .000 .900 ,660 ,000 ,600 ,000 .045 3366 310 342 28 ,00 ,00 ,40 ,82 81 00,000 140,4.00 1401,000 240,436 334 '1 303 504 26 .00 ,90 ,30 ,68 331.0,00 527,00 2107,60 62,48 SP TT2 NFDC DPHI -34,000 413,900 477.700 12,000 -10.800 3i0.000 516,200 17.697 -34.200 722,100 75.636 -41,900 330,9.00 556,500 9,939 -50.10,0 312,900 694,900 28,909 -41,1 O0 311 ,900 483,700 12,485 -73,200 315,900 664.300 14,242 -64,30'0 518,000 692,20,0 77,515 DATA GR TTJ RHOB NEAT 100,100 602,900 2,452 .859 48.000 481,000 2.358 1.454 43.800 561,.000 1,402 .476 94,200 472.0O0 2,486 .,947 72,400 479,900 2,173 ,.867 95,400 470,980 2,444 ,952 79,4.00 455,0.00' 2,415 1,066 36,70:0 7:37, OOO 1 ,371 ,419 .RECORDS TT4 DRHO ILM TEl{ FCNL RLL3 GR N C N L CTEN CALl CiLD 6,295 599.900 .024 5,200 3858,000 259,200 6.237 92,000 226,600 654.000 14.460 i58.055 6.123 482. O00 ,033 4.477 3863,000 194.300 5.585 44.200 285,400 700,000 i2.460 163,305 8.650 563,000 -.011 4.266 3810.000 350,300 13.428 45.900 170,000 721.000 18.270 115.611 7,925 484.000 .105 7,063 4000.000 236.200 ?. 870 93, ;300 229,908 684.000 15.740 126,183 6,353 472,000 ,215 6,194 3683,000 255.408 6,823 62,000 227,40:0 665,000 17.780 157,398 7.656 463.'000 ,020 6,855 3702, OO'O 240,900 9,078 86.40,0 232,20.0 680.000 16,970 130,617 13,614 456, ,000 ,087 I 0. 864 3'772,00 230,300 14,125 76.500 257,400 689.000 17,590 73.451 3'1.261 732,'0'00 -.018 4,159 3595,008 333,1 00 11,324 34,300 143,600 687.000 18.280 31.989 Page 10 DEPT TEN SP DT TT1 TT2 CTEN FFDC NFDC CiLH NPHI DPHI 8000.000 3284.000 -37.600 88,500 362.000 `363,900 14`35,000 433.600 524.900 139.637 31.470 16.788 DATA GR RHO~ NRAT , · 94.700 554.900 2.373 .909 7900.000 3238.000 -54.400 95.000 80.400 310.900 319.000 492.000 1457.000 407.600 474.400 2.388 174.101 32.310 15.079 .062 7800.000 3188.000 -32.700 46.400 78.200 319.900 316.900 490.900 1430.'000 357.400 477.400 2.431 194.009 15.201 13.273 2.215 7700.000 3169.000 -27.100 68.100 92.200 355.000 356.000 549.900 1397.000 985.500 606.600 1.968 253.513 31.180 41.333 .881 7600..000 3=090.000 -58.000 71.7:0'0 I 03. 000 46'0. 900 471 . 900 685.9.00 1409..000 333. 700 509. 900 2. 291 140. 605 38. 020 21 . 758 .034 7500. :000 3047. OOO -21 . 900 6`I . 1 O0 323. 900 31 O. 900 1438. 000 242.400 462.400 62.006 19. 056 .061 6@. 1 ~00 472. 900 2.649 1 ,78@ 7400. 000 3033. 000 -I 1 .200 77.700 90. 600 334. 900 348. 000 521 . 900 1478. 000 616.2.00 602. 500 2. 312 3.33. 427' 33. 420 20. 405 .76`5 7300. 000 297:9. 000 -7. '000 95.6,00 336. 000 339. 000 1433.000 420.700 491.100 299. 916 25.51 0 20. 700 45.2:00 525.000 2.3.07 1.330 ,RECORDS ILD TT4 DRHO 6,607 558.900 .095 ILM TEH FCNL 7.161 3540. 000 252.900 RLL3 GR NCNL 6,531 07.400 230.000 CTEN CALl CiLD 679.000 15.910 15i.356 6.138 490.000 .020 5.741 3608.000 256.500 6.412 90.300 215. 000 5.383 484.900 .007 5.152 3471.'000 150.200 6.012 40.000 350.800 3,776 545.900 -.003 3.945 3372.000 253.200 3.656 65.200 231.100 9.141 693,900 .009 7.112 3402.000 270.200 7.482 07.300 243.600 10.351 46`2.900 .056 15.922 3363.000 191.300 9.616 50.@'00 36`7.400 4.932 522.900 -.009 2.999 3283.000 261.300 4.677 81 .700 200.600 4,093 525. '000 ,005 3.334 3300.000 213.800 4.14'0 40.800 203.70'0 700.000 i6.320 162.930 660.000 12.450 105,700 681,000 18.180 264.050 745.000 18.190 109.396 692.000 17.020 96.605 651.000 i7.470 202.768 657.000 12.710 244.343 Page 11 DEPT DT CTEN CILH TEN TT1 FFDC NPHi SP TT2 NFDC DPHI DATA GR TT3 RH08 NRAT RECORDS ILD TT4 DRHO ILM TEN FCNL RLL3 GR NCNL CTEN CALl UILD Pagm 12 7200.000 89.500 1416.-000 242,66J 7100,000 85.200 J354,000 86,696 7000,000 92.700 1426.,000 252,930 6900,000 99,700 1462,000 147,911 6800,'000 94,600 1431,000 248,886 93,900 365,595 6600,000 1399,'000 297,167 6500,000 137,600 1431,'000 197,242 2984,00 326.00 988,80 30.13 2930,000 344,900 624,000 30.430 2902,000 349,900 474,900 31,500 2849.000 365,900 416,5.00 35,000 2793,000 342,900 430,000 22,140 2.770,00'0 350,000 438,900 37,090 2685. :OOO 353. 000 439,9.00 24.860 2688,000 318,000 4.49,900 21.390 -9.800 326,000 778.700 35.939 -28,800 333.000 495,000 36.485 -29.700 349,900 661.900 17.879 -17,5'00 361,900 506.600 18,970 -10,800 342. 000 503,000 2 O, 0 O0 -16,900 354,000 593,000 15.273 -20,300 357,000 497,600 21,273 -24,100 315,900 552,000 19,212 78,600 506.900 2,057 .847 94,800 505,000 2,04'8 ,770 65,480 529,0.00 2,355 ,827 87.2O0 548,000 2,337 ,788 46,20'0 530.000 2.320 1,487 61 , 3 O 0 556,900 2,398 ,830 51.9'0.0 550.9'00 2,299 1 ,336 55.3:00 584, O.O.O 2,333 '1 , 484 4,966 508.900 .183 7,278 501 ,900 ,025 4.677 530.000 .198 6,109 546,000 ,051 6,457 526.000 3.112 545.000 ,11.0 5,082 553,900 ,007 7,638 580,000 ,024 4.121 3242. O 0 O 248, OOO 11.535 3120.000 249,500 3,954 3131,.000 254.900 6.761 309G.000 266.400 4.818 3078.000 198.500 2,735 3073.000 271.500 3.365 2924, O'O O 210,700 5,070 2956, :000 192.600 4.276 75.600 207.800 7,962 88.600 190.000 4.436 62.500 214.000 5,483 87,000 214,900 5,140 42.600 304,900 3,304 57,5'00 224,400 4. 920 47,000 280,000 G ,653 58,800 294,900 682, OOO 18.250 20i .372 683.000 i8,i80 137,404 704,000 18,220 213,796 677.000 i8,240 163.682 688,000 13,830 154,882 639.000 i6.020 321,366 677,000 12,8{;0 196,789 666,000 13,170 130.918 DT CTEN CILH TEN TT1 FFDC NPHI SP TT2 NFDC DPH! DATA GR TT3 RHOB t,IRAT RECORDS ILD TT4 DRHO ILM TEH FCNL RLL3 NCNL CTEN CALi CiLD Page 13 6400,000 i07.700 i4~2.000 140,929 6300.000 98.400 1421.000 235.505 6200.000 78,500 1450.000 101,39i 6100,000 106,900 1383.000 281,83@ 6000,000 t I O. 400 1404. 000 169,044 5900,000 92.300 1372.000 149,624 5800.'000 105.900 i401,000 298,538 5700,000 i11,900 1435,000' i24,451 2621,00 348.00 6i5.00 46,80 2639.000 361,000 434,900 27,570 2536,000 417.000 327,300 22.500 2528.000 359,000 446,900 22.720 2526,000 385.900 708.000 45,610 2451,000 355.000 453.000 30.960 2442,000 373,000 449,900 24,850 2389.0'00 394.900 1642,000 48,440 -35.000 356.000 555.000 27,394. -3,100 361.000 523,900 19.212 -22,000 433,900 459.900 14,364 -,I00 364,000 518,900 24.364 -15,9.0'0 382,90.0 587,000 28,667 -2,700 352,900 6'05. 900 20,000 -.800 367. 000 504,900 23.09 i .-7.9'00 396.900 638,000 49,333 88,300 561,000 2,198 .646 63,600 555.000 2,333 1,i35 49.2:00 599,000 2,4i3 2.199 55.200 575. O00 2,248 i ,567 1 04,7.00 594, '000 2.177 ,645 95.100 555,900 2.320 ,922 55.8 O0 578.0,00 2,269 I ,427 58,300 600,9'00 i,836 ,484 7,943 559,000 ,024 5.321 554,000 ,022 596,900 ,027 4,295 572.000 ,0i2 6,427 595,0'00 .072 7,691 553,900 ,101 5.224 573,000 -,009 8,770 595.00,0 ,017 7. 096 2912. 000 299,900 4.246 2880,000 226,S00 9.863 2797.000 201 , '1 O0 3,548 2781,000 204,508 5,916 2669,.000 297.000 6.683 2737,000 252,200 ,3,350 2667,000 2i2,500 8,035 2673,000 304,000 6,887 85,900 i93,200 4.742 57.500 262,900 11,117 48,400 462.900 3.724 48,300 321,000 5.093 94,200 i87.'000 5,470 95,600 234,300 4,467 50,500 309,90.0 7,379 50,500 141.000 704. 000 17.770 125.893 651.000 i3.200 187,932 704. 000 i4,060 53.95i 68.8.000 i4,830 232.@09 703,000 18,250 155,597 679,000 i8.230 130.0i7 676,000 i3,490 191,426 671,000 18.230 114,025 DATA RECORDS DEPT DT CTEN CILH TEN SP TTi TT2 FFDC NFDC NPHi DPHi 2351.000 7,600 371,900 365.900 494,000 584.000 29.210 i7.939 i479 224 5500 1489 393 .000 ,400 .000 .906 .000 .000 .000 .550 GR TT3 RHO8 NRAT 61 .300 559. 900 2.354 ,895 ILD TT4 DRHO 4.198 556,900 ,li5 2289.008 1.000 56,200 2.924 375,900 375.900 594,900 593.900 431,000 464,000 2,287 -,024 27,140 22,000 1,037 5400.000 2232,008 -12,300 86,0.00 98.300 365.900 378.900 551.008 1491,000 450.008 567,000 2,412 202,302 30,730 i4,424 1,023 5300.000 2228,0'0:0 -3.300 78..6:00 10i,000 367,000 360,000 550.000 1424,000 390,.000 491,.000 2,412 230.675 3i.960 14,424 ,780 7,499 562,000 ,139 ,000 ,900 ,000 .293. 5200 1'03 '220 G, 053 537,000 ,064 2163,000 36,700 84.9'00 5,508 433,9.0.0 426,900 624,..000 612,000 · 519.900 577.9.80 2.314 ,130 42.700 20.364 ,631 ILM TEN FCNL 4,446 2690,000 2.36.700 RLL3 NCNL 4.645 58,200 2i8.780 CTEN CALl CILD 669,000 13,580 51 00, '000 2'I 46. 000 79,200 47,2,00 84,600 259,.000 257,900 376,'0'00 1402,000 200,0'00 1 06,00'0 1 ,553 , 1 02 82,750 66,485 , 369 5000.'0.00 2.096,'000 132,300 35,4,0'0 196.800 254,900 331,90'0 546,000 1391,000 221,1:0.0 129,900 1,653 ,I02 87,220 60,424 ,363 99769,875 430,900 -1 ,144 99769,875 546,000 -,95i 2,541 2567,'000 222,508 3.467 51,700 238,908 685.000 12,620 341,980 4,943 2578,.000 245,300 6,934 77.300 257.600 661,000 13,920 i33,352 4.335 2439..000 256.408 4,581 76,500 205, O00 681,000 18.260 165,196 4,539 2323,808 289.200 4,159 76. 900 i 81 , 000 639,000 18,190 181,552 9772.375 2399, '000 359,608 ,143 46.000 133.000 G60,000 12,490 ,010 9772,375 2345,00I 364.1 0 ,142 32,100 133,300 650,000 i2,460 ,OiO Pagm 14 ~,~ FILE TRAILER File name: &G5F01.00! Maximum length: 1024 TRAILER RECORDS Service nam.e: Version #: File type: LO Next 4'ile: Date: Page 15 FILE HEADER File name: .0'02 Service name: Version #: Date: Maximum length: 1'024 File type: LO Previous ~'ile: MN EM CN WN FN COUN STAT CTRY APiN LATi LONG SECT T 0 W N RANG EDF E~L PD L~F RUN TIME DATE LCC SON LUN LUL EN~I WITN DL CBD i CBLI TLI TCS TLAB BHT MRT ~T MSS MVIS D~PH DFL RHF MFST MFSS RHC CONTENTS UNOCAL TBU G-4 0 HcARTHUR RIVER KEHAI ALASKA USA 204i 2.'000 ..... 0 Deg. 0 0 De.g 0 Nin ;"9 09N ..... I~W ..... 1'03. ~000. 102,000. -117,000 MS ...... 104. O00. I O/ J/90 .70 ....... STERLING STERLIH~ SCHIAYI KILOH 1'126~. ~:0,00.. ..... 11200.:000 ...... 51.25,000 ....... 5118,000 ....... 5118,0,00 ....... 1'1197. 000 ...... 84~, O00 ........ 1 ~4~. 0 O0 ....... 160. 000 ........ 1~0.000 ........ DEFLOCULATED FLOWLINE 9.500 ....... 52. O00 ...... 9';500 ....... 7,200 ....... ,420 ........ . JS'O ........ 46,000 ...... MEAS, , ,45'0 ......... · i i . Il i a . i i . m . . . I i i I i I NFORMAT I ON RECORDS UNIT API NUM: 50-73~-20412 .............. DATE LOGGED: 03-10-90 .............. a , i iiimiii ii~llli Sac Ill,I iimi . Il m . FT FT FT FT FT FT FT FT FT HR HR DEGF DEaF LB/G CP OHMM OHM DEUF OHHN TYPE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CATG 0 0 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 0 0 0 0 0 0 0 0 0 0 3 3 3 3 2 4 t 1 2 2 2 2 2 2 2 2 2 SIZE 4O 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 8 2 10 10 20 2O 20 20 4 4 4 4 '4 4 ,4 4 20 2O 4 4 4 4 4 4 12 4 CODE G5 65 65 65 65 65 68 65 65 65 &5 &5 79 &5 79 65 ~5 &5 65 ~5 68 ~8 65 68 68 65 Page ERROR 1E MNEF1 HCST HCS$ CS BS I HFORH~T I OH RECORDS CONTENTS UNIT 4~,000 .................................................. HE~S ............................................. i3,375 .................................................. 12.250 .................................................. DEGF TYPE CATG SIZE 4 i2 4 4 CODE 68 65 Page ERROR 17 COMMENT RECORDS ~lell Location Comment 1: Well Location Comment 2: ttlell Location Comment 3: Wmll Location Comment 4~ t~ell File Comment 1: Yell File Comment 2: Well Film Comment 3: 1900' FSL & 1459' FEL SM PALTFORM GRAYLING LEG ~l, CONDUCTOR #25 DDL SYSTEM AND TOOLS USED TO LOG WELL. Well Film Comment 4: · ~ LIS tape written bp: ANCHORAGE COMPUTING CENTER · ~ Rll curve' and tool mnemonics usmd are those which most closely match · ~ Halliburton curve and tool mnemonics, HRLLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT. DEPTH DEPTH DEPTH FT , DEPT FT 4957.00 !120§,00 TEN2 DILBCS LBS TEN DILBCS LBS 10961 ,5'0 11203.50 SP2 DILBCS MV SP DILBCS MV I 0961 , 50 11203,50 GR2 DILBCS API GR DILBCS API 1 0961 , 50 'i ! 203,50 ILD2 DIL OHMM ILD DIL OHMM 1 0961 , 50 i 1203.50 ILM2 DIL OH'MM ILM DIL OHMM '1 0961 .50 11203,50 RLL32 DIL OHMM RLL3 DIL OHMM 1 0961 ,50 1 1203,5,0 CTEN2 DILBCS LBS CTEN DILBCS LBS 10961.50 11203.50 DT2 BCS US/F DT BCS US?F '10961.50 112.03.50 TTI 2 BCS US TT1 BCS US '1.0961 . 50 ' i 1203 . 50 P~ge TT22 TT32 TT42 TEH3 GRJ CALI3 CTEN3 FFDCJ HFDC3 RHOB3 DRH03 FCHL3 HCHL3 CILD2 C I LH2 HPH 13 DPHI3 NRRT3 BCS BCS BCS CDLDSN CDLDSN CDL CDLDSN CDL CDL CDL CDL DSN US US US LBS API IN LBS CPS CPS G?C3 G/C3 CPS CPS MMHO MHHO SSPU PU CPS TT2 TT3 TT4 TEN GR CALI CTEH FFDC NFDC RHOB DRHO FCNL NCNL CILD CILM NPHI DPHI HRAT BCS BCS BCS CDLDSN CDLDSN CDL CDLDSN CDL CDL CDL CDL DSN DSN DIL DIL DSN CDL DSN US US US LBS API IH LBS CPS CPS G?C3 G/C3 CPS CPS MMHO MMHO SSPU PU CPS 1 0961 . 5'0 '1 0961 . 50 1 0961.50 1 0961 . 50 1 0961.50 1 0961 , 5 0 1 0961 . 50 1 0961 . 5 0 1 0961.50 1 0961,50 I 0961,5 0 '1 0961 . 5 0 '1 0961 , 5 0 1 0961 , 50 1 0961.5 0 1 0961.50 1 '0961 . 5 0 10961.5 0 11203 11203 11203 1120.3 11203 11203 11203 11203 11203 11203 11203 1120:3 11203 11203 ! 12o, 11203 11203 50 50 50 50 50 50 50 ,50 ,50 ,50 ,50 ,50 ,50 ,50 .50 ,50 .50 DATA FORMAT ENTRY ~=~ EHTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum ~Bmci?ication block zub-t6/pm 0 Tmrmina~or ( no morm mntrims TYPE SIZE SPECIFICATIONS CODE Pag~ DATA FORMAT *** DATUM SPECIFICATION BLOCKS SERVICE SERVICE API API API API FILE MNEM ID ORDER ~ UNIT LOG TYPE CLASS MOD # DEPT TEN SP ILD ILM RLL3 CTEN bT TTi TT2 TT3 TT4 TEN GR CALI CTEN FFDC NFDC RHOB DRHO FCNL NCNL CILD CILM NPHI DPHI NRAT 137687 DILBCS 137687 DILBCS 137687 DILBCS 137607 [)IL 137687 DIL 137687 DIL 137687 DILBCS 137687 BCS i37687 BCS 137687 BCS 137687 BCS 137687 BCS ,137687 CDLDSN 137687 CDLDSN 137687 CDL t37687 CDLD,SN '137687' CDL CDL CDL CDL DSN DSN DIL DIL DSN CDL DSN 137687 1'37687 137687 137697 137687 1'37687 137687 1'37687 137687 137687 137687 FT 0 0 0 0 2 LBS 94 635 .0 3 1 MV 94 10 1 3 I API 94 310 1 3 I OHMM 94 120 46 3 1 OHHH 94 120 44 3 OHMM 94 220 6 3 1 LBS 94 0 0 3 i .US/F 94 520 32 3 1 US 94 522 32 3 1 US 94 522 32 3 US 94 522 32 3 1 US 94 522 32 3 i LBS 94 635 .0 3 1 AP1 94 310 1 3 1 IN 94 280 2 3 i LBS 94 0 0 3 1 CPS 94 354 2 3 CPS 94 354 1 3 i G/C3 94 350 1 3 1 G/C3 94 356 1 3 i CPS 94 334 CPS 94 334 30 .3 1 MMHO 94 110 46 ,3 1 MMHO 94 110 44 3 i SSPU 94 89:0 3 3 PU 94 89~0 12 3 i CPS 94 42.0 1 3 SPECIFICATIONS PRC # SIZE LVL SMPL RC 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 4 0 1 4 0 1 68 4 0 1 60 4 0 i 6'0 4 0 1 4 0 i 68 4 0 1 68 4 0 1 4 0 1 68 4 0 I 68 4 0 1 4 0 1 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 4 0 i 68 4 0 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 :000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 00000.0 000000 000000 000000 O00000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ,000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pag~ 2O DEPT DT CTEN CILH TEN TT1 FFDC NPHI SP TT2 NFDC DPHI DATA GR TT3 RHO@ NRAT RECORDS ILD TT4 DRHO ILH TEH FCNL RLL3 GR IICI,IL CTEN CALl CiLD Page 21 11203, O. -999, 364, Ii200. 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