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Home My WebLink About188-034 • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Friday, October 09, 2015 7:24 AM To: Wallace, Chris D (DOA) Subject: RE: Request for Cancellation of Administrative Approval (AA)AIO 6.007 for Anna 38 (PTD #1880340) Hi Chris We've had a shuffling of team personnel over here and this changed who's minding the Anna platform- kind of a domino effect. The current status for An-38 is to cease work on any conversion efforts, keep the well as a shut-in injector and hope we get some money in the new year to recover the wellbore and open up all the options for this well. Therefore the request to cancel A10 6.007 is withdrawn. We'd probably get the money to do this if the price of oil wasn't so low...can you do something about that?? Larry From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, October 08, 2015 3:54 PM To: Larry Greenstein Subject: RE: Request for Cancellation of Administrative Approval (AA)AIO 6.007 for Anna 38 (PTD #1880340) Larry, This was flagged in an internal review. I know we left this in limbo since February. What is the current thinking and status of the well? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission same)Ea MAY 2 7 2016 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] Sent: Tuesday, February 17, 2015 9:31 AM To: Wallace, Chris D (DOA) Subject: Request for Cancellation of Administrative Approval (AA) AIO 6.007 for Anna 38 (PTD #1880340) 1 • • Chris &Jim, With the failed conversion of the Anna 38 well from an injector to a producer in early 2014, the AA is no longer needed to continue injection into this well. The scale issues and rig work required to remedy the pump problems mean this well probably won't be producing for a while. Hilcorp requests that AA AIO 6.007 be cancelled. Thank you. Larry 2 • • RECEIVED Wallace, Chris D (DOA) tB 17 Z015 From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Tuesday, February 17, 2015 9:31 AM AOGCC To: Wallace, Chris D (DOA) Subject: Request for Cancellation of Administrative Approval (AA)AIO 6.007 for Anna 38 (PTD # 1880340) Chris &Jim, With the failed conversion of the Anna 38 well from an injector to a producer in early 2014, the AA is no longer needed to continue injection into this well. The scale issues and rig work required to remedy the pump problems mean this well probably won't be producing for a while. Hilcorp requests that AA AIO 6.007 be cancelled. Thank you. Larry 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the Original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. / (~-/~i~y Well History File Identifier Organization (do~el '~~Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [3 Diskettes, No. [] Maps: Grayscale items: [] Other, No/Type Poor Quality Originals' ~._~.~ ~:, ~),i 0'1 "' ¢t O Other: TO"I'AL PAGES: i ,_'.'.~ ;~'-- NOTES: [3 Other items scannable by large scanner OVERSIZED (Non-Scannable) [] L..pgs o! various kinds Other ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MAR',A LOWELL DATE: Project Proofing [] Slaff Prooi,~ PROOFED BY I3EVERLY BREN VINCENT SHEIAYL MARIA LOWELL DATE ~SI ,~CANNEO Ex,. BEVERLY BREN VINCE~AF];~' LOWELL ReScanned ~0on~, Gene[al Nole5 Or C. ornmenls aboul Ih~s file Oual~ly Checked • • qr2 t i se,034 Regg, James B (DOA) From: Regg, James B (DOA) SiV61 Sent: Tuesday, August 28, 2012 10:35 AM t I To: 'Larry Greenstein' Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Leave anniversary date May 20 as required in AIO 6.007 (Revised 3/31/2009). Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DINED i\4AY 0 2 2013 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreenstein @hilcorp.com] Sent: Tuesday, August 28, 2012 9:56 AM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Hi Jim, Lots of moving parts over here and I just stumbled on one more...this one. Sorry I didn't follow up with a formal response before now. Attached please find a temp survey on the An -38 well done in March of this year (I didn't know they did it). The overlay with the May 2010 temp survey shows no downhole temperature anomalies of any kind. The well appears stable while it remains shut -in. W ith the discrepancies in the anniversary dates for the AA /temp survey listed below, I'm unclear how to proceed. Do you have a preference ?? Leave the date of May alone, move to August ?? Also attached is the original e-mail from Hal Martin to Tom Maunder that opened this can of worms. I'm leaning to leaving the May date alone (since we logged in March), but I'm open for any ideas you have...help me figure this one out. Larry Original Message From: Larry Greenstein Sent: Tuesday, February 28, 2012 7:28 AM To: 'Regg, James B (DOA)' Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Will do Jim. I'll put together something on letterhead for you to work from. Larry 1 • • Original Message From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, February 27, 2012 3:48 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question A formal request from Hilcorp would make this much cleaner. Does't have to be real elaborate, just make the request to amend permanently the temp survey anniversary date and include reason for request. It's a bit messy extrapolating a request from Chevron /Union to Hilcorp. I've started on the admin approval, amending AIO 6.007 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreenstein @hilcorp.com] Sent: Thursday, February 02, 2012 3:55 PM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Thanks Jim. We can perform the TS in May of this year, but that would be the 'off cycle' year based on the original March 2005 approval and subsequently revised to May in 2009. If it wasn't for that darn rig out there, we would have been able to keep this on schedule and avoid all of this. Let me know what works best for you and we will get it done. Larry Original Message From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, February 02, 2012 3:41 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question I think this is going to require an Admin Approval since precedent was set by AIO 6.001, and to document reasons for not doing temp survey in May 2011 as required. I'll work on this based on info provided and see if Commissioners agree with delaying until August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 2 III • Original Message From: Larry Greenstein [ mailto:lgreenstein @hilcorp.com] Sent: Thursday, February 02, 2012 1:51 PM To: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Yes, that is true, Jim. Shifting from March to May was a big help, if we would have been able to stay on that schedule. When it turned out we couldn't get the temp survey done until August of 2010 due to the reasons explained in Hal's e-mail (physical obstacle), Hal thought it seemed premature to then go back to the May 2011 due date (9 months later) for the next compliance temp survey to be due. He requested two years from the August 2010 survey to sort of reset the due date to August 2012. That's as much as I know about it, Jim. Hopefully this explains why we didn't do a temp survey in May of 2011 and planned on doing the survey in 2012. We could do this in May 2012 if this would help keep your records straight. Larry Original Message From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, February 02, 2012 12:41 PM To: Larry Greenstein Subject: RE: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question We previously approved the shift from March to May to take advantage of the warmer months and resulting improvements to slick line ops; it is not clear to me the reasons for delaying the required temp survey from May to August. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Larry Greenstein [ mailto:lgreenstein @hilcorp.com] Sent: Thursday, February 02, 2012 9:37 AM To: Regg, James B (DOA) Subject: Granite Point State 18742 #38 (PTD #1880340) An -38 temp survey question Hi Jim, I found this old e -mail from Hal to Tom about a delayed MIT compliance temp survey on An -38 in 2010. In the last paragraph, Hal asked for approval to modify the anniversary date to two years from the 8/25/10 temp survey. After contacting Hal (who's now down in Houston with Chevron), it appears he never got a response from Tom about the request for a change to the anniversary date. The well is 3 • • currently shut -in and we were planning on doing our compliance temp survey this summer (before'8 /25/12), but the current AA anniversary date is in May (per Hal's e- mail). Do you have any issue with us modifying the anniversary date for the An -38 well to the August timeframe ?? Call me if you would like to discuss this, Jim. Thanks Larry 777 -8322 4 Hilcorp Energy Well: An -38 Prtt iYi�td34o Fi Anna 103 -09 -2012 � I I I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 o- 1000 RE � L I Pressure - Temperature Profile 1. Going in hole 2000 2. Well Shut - in 3. 2012 vs 2010 MD Overlay 3000 Ism 4000 IMO 1 CD I II ci 5000 6 II i ikli 111 111 000 , s ti 1 CD 7000 Lk 8000 illi Il E 161 :111 9000 I Pi I. 10000 4,..1 11000 12000 i 1 I 1 i 1 1 1 i I 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) — 3-9-12 Pressure - Perfs 13 3/8" 9 5/8" —7" —LS Tbg - SS Tbg 3 -9 -12 Temp 8 -25 -10 Temp Report date: 8/28/2012 I Hilcorp Energy WeII:IAn -38 CO) 8 F Field Anna 103 -09 -2012 I C Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 000 m =Fir M. MP1 Pressure - Temperature Profile 1. Going in hole 2000 , 2. Well Shut -in 3000 4000 , 5000 a) 2 6000 , kik i r , CI 7000 8000 I ' 9000 10000 41 : 11000 12000 i i 1 1 1 i 1 l 1 l l 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) — 3-9-12 Pressure – Perfs 13 3/8" 9 5/8" — 7" LS Tbg SS Tbg 3 -9 -12 Temp Report date: 8/28/2012 IHilcorp Energy WeII:lAn -38 t'Qitixi34� I Field: Anna 103 -09 -2012 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1000 Pressure-Temperature Profile 1. Going in hole TVD 2. Well Shut -in 2000 3000 — — 4000 G) - I 5000 I— - .0 6000 - CI G) - 7000 8000 9000 — . 10000 = 11000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) —Pressure — Perfs 13 3/8" 9 5/8" —7" —LS Tbg —SS Tbg —Temperature Report date: 8/28/2012 • • „,,c, 7, r \ ` \ ,',, + i L ! ! 1 p i SEAN PARNELL, GOVERNOR tt , N . �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 COl`SERVATIOl` COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 6.007 AMENDED Mr. Larry Greenstein Regulatory Compliance Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 AN r) MAR 1,1 1 ZU1. RE: Request for Administrative Approval Amendment Granite Point State 18742 Well 38 (PTD 1880340) Granite Point, Middle Kenai Oil Pool Dear Mr. Greenstein: Hilcorp Alaska, LLC (Hilcorp) requests a permanent revision to the anniversary date for temperature surveys for water injection wells located on the Anna Platform (Granite Point Field). The Alaska Oil and Gas Conservation Commission (AOGCC) approves Hilcorp's request to change the anniversary date for wellbore temperature surveys in Granite Point State 18742 Well 38 (Anna 38) from May 20 of odd numbered years to August of even numbered years. The next temperature survey for Anna 38 is due August 25, 2012. Administrative Approval AIO 6.007 authorized continued water injection into Anna 38 subject to wellbore temperature surveys at a 2 -year interval in lieu of pressure testing the tubing- casing annulus. Anna 38 is one of several packerless wells on the Granite Point State "Anna" platform converted from production to injection. The style of completion prevents performing a conventional mechanical integrity pressure test. Temperature surveys are intended to demonstrate that injected fluids are exiting the wellbore and remaining confined as required by Area Injection Order 6.000. Amended Administrative Approval AIO 6.007 dated March 31, 2009 established a new schedule for Anna 38, allowing the wireline survey work to be conducted in May instead of March to take advantage of warmer weather. Temperature surveys performed on April 5, 2007 and August 25, 2010, and pressure monitoring data indicate injected fluids continue to be confined to the injection zone. Administrative Approval 6.007 as amended requires Anna 38 to be immediately shut in if there is any measurable change in the well's mechanical integrity.' Daily surveillance of wellhead pressures and injection rates with monthly reporting to the AOGCC — mandated by the administrative approval — provide for early detection and action 1 Water flood injection has been shut down on Anna platform since January 2008 due to surface facility issues; consequently Anna 38 has been shut in until the water flood injection can be restored. • • AIO 6.007 Amended March 5, 2012 Page 2 of 2 regarding any deterioration of well integrity that might occur during the 2 -year interval between temperature surveys. The AOGCC finds that moving the anniversary date for temperature surveys to August of even numbered years will not compromise overall well integrity so as to threaten the environment or human safety. 5 u, OIL gN DONE at Anchorage, Alaska and dated March 5, 2012.. ' \ i Cathy P. Foerster Daniel T. Seamount, Jr. Tioly coe Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 4 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Friday, January 15, 2010 8:39 AM To: Maunder, Thomas E (DOA) Subject: FW: Granite Point State 18742 #19 (aka Anna #19) AIO 6.008 Compliance Temp Survey Attachments: An-19 Temp Survey 1-8-10 vs 10-3-06.zip 1-~- ~~ -~~Q~c-o.~r~..ZS S2r~~~~~ ~~ Jim Regg ~tJG~.~ ~--~c-~+.r.. ~ 4 -3 -O ~o ~ AOGCC ` t_ 333 W.7th Avenue, Suite 100 c ~; `~O'~C . , O ~ J Anchorage, AK 99501 ~~,~~ ~" ~ ~~ ~` ~~ 907-793-1236 ~~ `I ~~ \~ From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, January 14, 2010 6:26 PM To: Regg, James B (DOA) Cc: Greenstein, Larry P Subject: Granite Point Stat 18042 (aka Aima ~ 19) P(I~J 6.008 Compliance Temp Survey ]im, A compliance temp survey was conduced on Granite Point State 18742 #19 (a.k.a. Anna Well No. 19), AIO 6.008 (PTD 1680060) produced water injector on 1/8/10. The previous compliance temp survey was conducted on 10/3/06. The attached temp plots (MD and TVD) overlaying Anna Well No. 19 temp surveys on 1/8/10 and 10/3/06 indicate downhole containment of the injection fluids with no significant temperature anomalies. A compliance temp survey was due for this well by 5/20/09. As mentioned below in our correspondence, access to Anna Well No. 19 was prevented until mid-December 2009 because of a rig-use building set on the deck covering the slot. As you recall, our waterflood injection has been down on the Anna since January 2008 due to surface facility issues. However, previous communication with you indicated your desire and acceptance of a compliance temp survey for Anna Well No. 19 even though the well has not been on injection for a period immediately prior to running a tem survey. ~~ ( ~,,._ On another related issue, the compliance temp survey for Anna Well No. 38 is still ~1 outstanding due to similar reasons as mentioned below. The rig has been skidded but there are still some miscellaneous obstacles preventing access to the well. It is expected that these obstacles will be removed from the platform shortly and a compliance temp survey completed within the next 30 days. Please call me if you have any questions. 1/15/2010 UNSCANNED, OVERSIZED MATERIALS AVAILABLE: t ~<¡ é)'fI FILE # / /Jd¿[ (Jó~tLreÞa To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission i 333 W. 7th Ave., Ste. 1 00 ~ Anchorage, Alaska 99501 Voice (907) 279-1433 ¡Fax (907) 276-7542 • • Page 1 of 2 Regg, James B (DOA) - ~ l(~7_ ~~~ ~~a 5 ) ~_~ ,_ __ _ _____ ._ r h ~__ _ __ _ .. .__ __ ~__~ _.~_~_.a...~ _ _ ___ _~. w__ ____ __,_ _ Jr-~ 1 ~~ -~,~ ~,,-.~ ~ i From: Martin, J. Hal [HaLMartin@chevron.com] ,- ~---°---~ Sent: Wednesday, September 16, 2009 11:07 AM ~~ 1~j~3~i- ~~'"ti"~ 3 To: Regg, James B (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA); Freeman, Justin T Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and n-38 C/ Tim, ~ '~ ~ ~' The short answer is: ~~g/l' ~~~~ ~~ 1. Drilling is supposed to be working the plan to remove the rig-use buildings that covering the An-5 and An-19 slots and the rig is on the leg that An-38 is on, but out of position to get over it. Once the building and utility module are removed, access to all the wells will be available on An-5 and An-19 and my understanding is that then skidding the rig can be planned. 2. The waterflood will be down for a while and it is not a given that it will be restored at this point. The sand filters were recently inspected internally and uncovered a failure of the grating that kept the various sizes of sand media stable and properly layered. As you recall, we were hoping it was a butterfly control valve issue, which would have been an easier fix. We are in the process of evaluating whether to proceed with repairs given the significant cost impact coupled with budget constraints. I am guessing that we should be close to an answer on this by mid November. I'll get back to you on this either tomorrow or Monday afternoon with more info on the current timing guesstimate from our drilling guys on the rig-use building removal. Let me know if you have any other questions. Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 16, 2009 9:00 AM To: Martin, J. Hal Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Platform Remaining WaterFlood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Would appreciate an update on schedule for completing temp survey in Anna 5. Same for Anna wells 19 and 38 if they are back on injection; otherwise, we would appreciate an update on status of water flood on Anna platform. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 9/16/2009 • Page 2 of 2 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G Subject: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim and Tom, FYI and reminder. I just sent you the compliance temp surveys for An-21 and An-25. We were able to access those wells. We have yet to do the compliance temp surveys for An-5, An-19, and An-38, which were also due on May 20th as well. The reason, as we've discussed before, is that the wells are currently not accessible with slickline due to rig equipment covering the wells and supply boat support issues. We will run temp surveys on the three wells above when we regain access to the well bores. All of the Anna waterflood injectors have been shut in since .Ianuary 2008 due to ongoing surface facility issues compounded with heavy drilling rig activity during much of 2008. An-5, a produced water injector, is still on injection, averaging about 60 BWPD. As we've discussed, as a result of the unusual shut-in circumstances brought on by the Redoubt volcano, this is because we are still producing some wells on the platform, separating out the produced fluids, and injecting the produced water down An-5. The oil is being injected in to four producers. This is a temporary situation that we are monitoring during this period of downtime for oil shipments. Let me know if you have any questions. Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 9/16/2009 Granite Point State 18742 #38 (aka Anna #3.06.007 Complian... Jim & Tom, The previous compliance temp survey was conducted on 6/16/05. The attached temp plots (MD and TVD) overlaying Anna #38 temp surveys on 6/16/05 and 4/5/07 indicate downhole containment of the injection fluids with no significant temperature anomalies. The shape of the temp surveys are virtually ./ identical with the 4/5/07 survey slightly warmer at depth. Please call me to discuss if you have any questions. «Anna 38 Temp Survey 4-05-07 vs 6-16-05.zip» Thanx, HaC !M.artin Optimization Engr Chevron 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 5CAt1aa:> MA'{ 0 2 2007 . . . Anna 38 Temp Survey Content-DescnptIOn. 4-05-07 vs 6-16-05.zip Anna 38 Temp Survey 4-05-07 vs 6-16-05.zip Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 4/30/2007 12:51 PM 10000 11000 12000 40 500 1000 2000 3000 4000 5000 6000 7000 8000 9000 55 70 85 Pressure Perfs 5/8" 7" 7/8" Report date: 4130/2001 10000 11000 1000 3000 4000 5000 6000 1000 8000 9000 Report date: 413012001 55 70 130 175 190 85 100 11 Pressure 1/2" -6-16-05 Anna 38 AIO 6.007 Compliance Temp Survey • • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Wednesday, April 19, 2006 2:39 PM To: Thomas Maunder; James Regg Cc: Martin, J. Hal Subject: Anna 38 AIO 6.007 Compliance Temp Survey ~r~ ~ APR ~. ~ Zfl~~ Attachments: Anna 38 Temp Survey 5-30-03 vs 6-16-05.zip Jim & Tom, Page 1 of 1 While reviewing our M1T books, I noticed that the compliance temp survey on this well didn't get sent to you last year. The new Admin Approval process bit us here. This well was in the first wave (ie there may be more wells) of this new procedure and had been hung up for over a year until we ironed out the new process (from Variance to Admin Approval}. Jim has stated (see below) that we will use the AIO 6.007 approval date of 3/29/05 as the anniversary date for compliance issues for this well. But in this case, the AA was so late in coming (over 21 months) that we did a follow-up temp survey at the 24 month mark from the previous temp survey date, 5/30/03, and not from the AA approval date. This seems to be more along the intent of the approved process of compliance temp surverys. Somehow in all the procedural newness, we didn't send this temp survey over to you guys. I will be looking for others from that early batch of AA's that fall into this same'late reporting' category or is it'reaNy early reporting' category. Hope we can be forgiven for stumbling on the timing for this first compliance temp survey. The well will be scheduled for its next temp survey in the early summer 2007 as we would rather avoid March water well surveys, if at all possible. Bottom line is that the overlaid temp plots on An-38 show great similarity and indicate very stable downhole containment of the injection fluids. Please call me to discuss if there is any confusion. Larry 263-7661 «Anna 38 Temp Survey 5-30-03 vs 6-16-05.zip» MIT Due Dates We did not talk about this subject but clarification is appropriate based on recent discussions with other operators and within the Commission regarding scheduling MITs. Mechanical integrity determinations are due on or before the anniversary date. The Commission must approve an extension to go beyond the due date. For Admininstrative Approvals (welll integrity, alternate demonstration of mechanical integrity), we are using the admin approval date to establish when the next mechanical integrity demonstration is due. Jim Regg AOGCC 4/8/2008 • • unoca~ well: AN-38 Field: Anna Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1000 2000 Pressure-Temperature Profile 1. Going in hole TVD 2. Making Stops ~ . ---- __ __ , - -- - -- _ __ _- - :. _:. 3000 4000 r v 5000 fl. 6000 7000 8000 9000 10000 11000 r 40 55 70 85 100 115 130 145 160 175 190 Temperature (Deg. F) Pressure - Perfs 13 3/8" .~.-~.9 5/8" ~°- 7" 3 1/2" --2 7/8" Temperature Report date: 4/8/2008 ~lJlÆiJŒ WJ~ )!Æ~~~iÄ!Æ / AI,ASKA OIL AlU) GAS j, ,...' CONSERVATION COMMISSION .. ) FRANK H. MURKOWSK/, GOVERNOR 333 W. 7"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.007 Mr. Larry Greenstein Production Technician U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 SCAN~~E[!; /-\PH 2; Ü 2005 RE: Granite Point State 18742 #38 [aka Anna #38] (PTD 188-034) f.{equest for Administrative Approval AID 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AID") 006, 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. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 38 from producer to injector via Sundry permit 300-219 approved October 25, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion sundry and a graphical maximum operating pressure determination. 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 pressure integrity loss. 6. The original analysis performed for the conversion in October 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.1 02(b )(2)(i).] Mr. Larry Greenstein March 29,2005 Page 2 of2 ) ) Accordingly, the Commission 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 Granite Point State 18742 #38 [aka Anna #38] 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 Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Commissioner ~/,,.,rl~,. ulL .& J I~tj;\·~\~ì~~ . ';¡(\;q),' ¡II~~~' l '. '" â!t,\ /-............~ u1. J' .~, '~-·Fi~r. ~-" '¡ H .....-:"?.--,;.\ ).,'..... ""'~""~""" ..~~~ ~ \ (.....:3~~-:::,J.:;;;·ß~!t:;;ú..~. ;1\ . ~¡){;"'~ ~ ('~.·ï ,(.;7 tlji}~ 1:~ <: :':1:~;r,~'~~;?i ~ (""" '\~ ~ M ! I; ì\ ;;·;¡..·..~t .' ~.; '-- ~... ~:;f~~~~.~.\\~.!!~,jJ~~0~~:,:~j,~~1.t:~ro \ ~ \<.. '-, .""'~.,. ...J,~"r. "...~."¡:,,~,,, "" f) , ~;t¡t;~]i,~~7;l~~t{g3 -;'V.i.·~ \..",.~~~¡. -, ' \...~..:...-J:~ r ) 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 UNOCALe '.-', "l\iAH\..Iii..-fr"",\ pi nrì¡ 2· n 700¡: ~(,,k"!"'!r;J,)1 ¡'-U" !1~. ,,' _ .,,~ Larry P. Greenstein Prodction Technician Date: February 17, 2005 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. An-38 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for the Anna Platform Well No. An-38 Injector (Permit # 188-034) in Granite Point 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 producer in June of 1988. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled IIProcedures to Obtain Variances on Packerless Wells (Version 4) dated February 9,200011. This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/30/2003 matches the last survey run on 11/24/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-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 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 Hal Martin at 263-7675. Sincerely, ~A"J ¡? ~ L~~enstein cc: Dave Cole Hal Martin MIT book Well File " 1 í , I J , ~ , ~ ''''331 aÂar : I . A ~ , i : , :; . , I . I' ..' : . ; . ".M-.' . . : III" "535' : " ~ " ~ .:~;s ..._~' 1171' 5 I ~ ....,. ;'1 · '\ .,.. ., 7: . ... 47,DJJf Top of Lhr . IIØ 1'_ ' eM tooer , I ~ J_ 'I! ~ 10317-t04k-/ .. 104U-1GS7Ir - ~1° 101U-10171r -- 10111-1'" UDt3-t1CD1· :11 11214-112.. : '. 11271-11215- .. .,. Unw P/////þ ell. 11451' P8ID 11400' 1D 11453' GRANITE POINT FIELD GP ADL 18742 Weti No. 38 LOWER KENAI SANDS PLATFORM ANNA ....a~ DaIas _... ........... iIY_. ~. -l. f 11M ....... ....- MiIWi ~2""" -. ... SUrfaoe ... = ,I n lAII 2 IIet .. . 1Wf~.., AmII .... .... Depth ~ u.... ........,.... fIL J: ,.. DCJ Dual. 'III a- .... .. SID 12. n.... tUft...... 3. =" $....;NItft H72' ._ .: 'OS' .. U~ 4. . j vr 8m . 3 1n-~s; --! 1D: 114U' so..-:r .....r :- PID 11'" -: f7JrlV:s." 3 RD ,= ~ .. 1Uf. CIIIItIIMt tit'" .".... GMt tI::.:,r:;..-:.: Z /Ir" 1CØ74' ~\!". .~ '!'! !fIL.1M!!llnl1IIt at ... ...... .. OInt 1 NOS. U/Ir ..~ ..4IAt 10378' ;;:»I. tIi.:, .,.6i5.=.-Uft. -= .. OInt 1t....... -~ ,..,............ ~c:=: Short .... A. 3 vr NIO .. 1:JI1I't a X02~"'x~1I2M Co PW'. I ~ lID HID ~16ft (AI runl-t.....) c-s: 10317-1CMW t04l3-tDS7I' c-e: t0lD-10117r C-7: tOt1""01t1' 11013-11031' c-a t1224-t121r 11275-tt2H' '-foraIaI. 1-14-11 ea 8DPD x at ... X 340 MCPD NOtE NONE NONE NON! 05-30 . PDC-CH.-GII. UIID 10100'-1D' 01 0:..... CeoAml.Iß Cheak 01-14-11 Cll.-XDL .. srA11C CIL PII1D-t7IIr 01-13-11 ,.,., SOnIo. 1131O-100ar 01-13-11 _-.. 11373-111D' oe-1~ o,n. PllTD-SUrfaoe .... P-...1W. ...... ....... ~ Cand 'í.... ~= .... ......./1 11742-38 TEMPERATURE(DEG. F) 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 o -I :;.....' " , , , '~_' , .' , , I , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , I , , , , , , , , , , , , , , , , , , , , 500 U--..,'i .-........ Ii .' '\ 1000 1-; -~ L, 1500 -f{.- t 5: i 11 ¡¡ i 2000 -tllll- ¡ ~ i, 2500 -{ ~\ 3000 -tl - 3500 f- ~ m ~ I¡. 4000 ,,¡-~ - -'!I i . 4500 - . I 5000 5500 6000 6500 7000 7500 8000 8500 9000 PKR @ 9707' !!! 9500 10000 ~ I~ 5: t 10500 ~ ~ ~- 11 000 ~ '~ i 11500 PBTD=11400' 12000 -1000 -500 ') ) Anna Platform AN 38 Temp Survey 5/30/03 MIT vs 11/24/01 MIT -CCL -5/30/03 TEMP RIH, SI=12HRS -11/24/01 Temp RIH -5/30/03 PRES RIH, SI=12HRS I PERFORATIONS C-5 10397-10459 C-5 10483-10578 C-6 10663-10675 C-7 1 0918-1 0962 C-7 11013-11031 C-8 11224-11262 C-8 11275-11295 IBHP=4912.4 PSIG o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 PRESSURE(PSIG) ,-,,' An-38 Maximum Allowable Operating Pressure Graph o 1,000 2,000 3,000 + Pressure (PSI) 4,000 5,000 6,000 '. \ Variable Definitions \ - - -RP-=-Re"5etVoir-Pre-ssure--~----------------"\ CYP = Casing Yield Pressure '\ SF = Safety Factor (70% for working annulus; 45% for d~ter annuli) HP = Internal Fluid Hydraulic Pressure' MASP = Maximum allowable surface working pressure Graphical cal~ulatio~ method . Inside pressure potential == Outside pressure containment Therefore. HP + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP .~.~-= Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% \\ C\ \ ~ --\ \ '"\ \ 7,000 8,000 9,000 date: 2/16/2005 10:56:54 AM S operating pressures (surface gauge) PrMu ion = 4809 psi. @ 70% nominal casing yield IntE-m iate = 887 psi. limited by fracture pressure at shoe Su 'ace 164 psi. limited by fracture pressure at shoe Cl..rrent - ressure readings TBt;PRES, = 2289 CS 3PRESC _ = 2300 CSf3PRESS, == 375 CS SPRESS5 - 160 Casing Det 1s Un 1r Hanger = #, internal yield = N/A psi from 11450' to 11453' MD' Un.¡r Reentry Joi = 7" #, internal yield = N/A psi from 11446' to 11453' MD' Un,r Casing = {" #, S-95 internal yield = 11210 psi from 98r4' to 11453' Mu' Unoer Flcollar = 7" internal yield = N/A psi from 11451' to 11453' MD' Un~r Casing = 7" 3 ,S-95 internal yield = 11210 psi from 11414' to 11453' MD' Un~r Floatshoe = 7" , internal yield = N/A psi from 11451' to 11453' MD' Prc:luction Segment 9.625" 53.5#, N-80 internal yield = 7927 psi from 10057' to 10061 Prc:iuction Segment = .625" 47#, N-80 internal yield = 6870 psi from 3594' to 1 0068' ~ Prc:iuction Segment = 625" 53.5#, N-80 internal yield = 7927 psi from 6520' to 10068' Sh....e = 9.625" #, intern yield = N/A psi from 10066' to 10068' MD' Intermediate CasinQ = 13. 75" 61#, K-55 internal yield = 3090 psi from 38' to 3535' MD' IntE -mediate Shoe = 13.3 II #, internal yield = N/A psi from 3534' to 3535' MD' Su 'ace Casing = 20" 133#, -52 internal yield = 2840 psi from 42' to 620' MD' Su 'ace Shoe = 20" #, inter I yield = N/A psi from 617' to 620' MD' Casing Parameters I A sumptions Prc-:iuction casing yield @ 700 of nominal with fluid weight of 0.433 #/ft IntE::lmediate casing yield @ 45 of nominal with fluid weight of 0.433 #/ft Su 'ace casing yield @ 45% of n minal with fluid weight of 0.433 #/ft -r~ture gradient = O. r #/ft AP : 507332039800 Pe llit : 1880340 Wc.--kbook : An-38 Casing Pressure An lysis @70 percent 20050216.xls \ \ _~ _u._...~_~__ ) ) I~" ----. ,. . , NOTE TO FILE InRe: Anna 38 (18742 #38)... PTD (188-034) '-- ~-~\~ " UnocaJ hasêipp'ied to convert this production well to an injector. Since the well does not have a packer in' it, MI demonstration must be byo1her means. ThewelJ wasdrHled beginning in late April 1988 and completed in late June, 1988. There is very· little ·informa1ion available in the AOGCC well fns. It does not appear that any of theorJgfnalperfora1ionshave been altered sinoe the original completion. A note in the file does indicate1hat Unocal employed a snubbing unit on the well in 1997. No information on that work ¡sin the file, Unocal has provided a copy of the eBl run June 14, 1988. A copy of the log is not available in the AOGCC well fifes, ThequaJity of the provided copy is not great. Two passes are presented one at 0 psi and the other with 1000 psi. Aoement top is shown at about 103101 in each presentation approximately 90' above the top perforation.' , The' nonpreS$ured pass indicates the presence of a microannufus. The initjal wave arrivals are pretty consistent,throughbut the log run. When pressure is appried1 the:re is improvement in the attenuatiQn. The available information indicates there' is cemen1 present beginning about 90' above the top perforation. MI is indica1ed. The MI T demonstration methods andsu bseq uent mon itoring program will identify any deficjencies in isolation. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances onPackerlessWeUs (version 4) February 9 20001' I I recommend approval to convert Anna 38 (188-034) as proposed, J-tYWl ~~ Tom Maunder 0 Petroleum Engineer \ /\'1 - aU } r 61'~ ¿.os: .1-.-, r~c 11¿ /1 !IlL .J "I J'-#"-flt, 4 . ~ V, ~ 1/ '-' /. ~ ~. lk. 0 /,,1 1""& ~~~~ ~ ~~) ~ r r....... _J.I~ .,.~ /d'....". '·""'1 l~ ~ .:z..tl G ~ -:/ .J.. ~ea4~ ~ ~J~i!!. -~ . I ,~-~ -ù~~ecJ ~ ,.. /''')~''' r~~/J. r'" J ~;dU:¡ ~ - of ~~r /¥~ ~1J~1fŒ])~ fÆ lA' r~n( I~ lÄ\@~LA\ FRANK H. MURKOWSKI, GOVERNOR AIiASIiA. OIL AND GAS CONSERVATION COMMISSION November 16,2004 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Larry Greenstein Production Technician UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Granite Point State 18742 #32RD (Anna-32RD) Granite Point State 18742 #5 (Anna-5) PTD: 187-063 Sundry Application: 304-305 PTD: 168-036 Sundry Application: 304-306 PTD: 188-034 Sundry Application: 304-307 PTD: 167-014 Sundry Application: 304-318 PTD: 187-109 Sundry Application: 304-327 Granite Point State 18742 #25 (Anna-25) Granite Point State 18742 #38 (Anna-38) Granite Point State 18742 #37 (Anna-37) Dear Mr. Greenstein: We are returning, without approval, the Applications for Sundry Approval (Form 403) relating to the above-referenced wells, because the relief you request needs to be sought through a different procedure. AIO 6 regulates injection activities on Anna and Bruce Platforms in the Northern Portion of Granite Point Field. When an injection well exhibits an integrity loss, the injection order requires that the Commission be notified and that the Operator submit a plan for corrective action. Corrective action for purposes of an integrity loss means proposing to accomplish the physical well work necessary to repair the integrity loss. A corrective action plan should be submitted as an attachment to Form 403 per usual practice. If it is proposed to keep a well in operation without accomplishing a repair that would restore complete integrity, a request for Administrative Relief ("AR") in accord with Rule 9 of AIO 6 should be submitted. If you desire to request AR, your application should be similar to the attachment submitted with the sundry, however it should also include an evaluation/verification of the remaining barrier(s) that serve to confine injection fluids to the wellbore, SCANNE[;j NO\I 2; 11 2004 consideration of trapped pressures and the consequence thereof in any well bore "space" and an explanation of the management decision not to repair the well. F or these particular wells, it is acknowledged that none of the wells are equipped with packers, ordinarily a standard piece of completion equipment for injection wells. Injection was previously authorized for 4 of these wells (Anna-5 is a new application) after a review of the wells' construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure entitled, "Procedures to Obtain Variances on Packerless Wells (version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 AAC 25.450 (a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. All aquifers within 'l4 mile of Granite Point Field are exempt according to 40 CFR 147.102 (b)(2). Should you have any questions on this process, please contact Jim Regg at 793-1236 or Tom Maunder at 793-1250. ~in ~p , lr - . Chairman "- BY ORDER OF THE COMMISSION DATED this LZ.day of November, 2004 Encl. + e ~ • Unocal Alaska Union Oil Company of California 909 West 9'h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCAL76 Larry P. Greenstein Prodction Technician Date: August 4, 2004 State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7t"Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Re: Granite Point Field An-38 Water Injector Request for Continuation of Variance Dear Mr. Maunder, This letter is to request a continuation of the MIT variance for the Anna Platform An-38 water injector. (Permit # 1880340 API # 50-733-20398-00). This well has tubing / casing communication and has been injecting with a variance since June of 2003. The temperature survey run on 5/30/2003 matches the last survey run on 11/24/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-Sands. In support of this request, the temperature survey comparison plot and 10-403 sundry have been attached. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, ~ ~ ~ ~~ Larry P. reenstein cc: Dave Cole Hal Martin MIT book Well File ' • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Suspend ^ Operational shutdown Perforate Waive Annular Dispos. Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Exten ' n ^ Other 0 Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspende ell ^ VARIANCE 2. Operator Name: UNION OIL COMPANY OF CALIFORNIA 4. Current Well Class: 5. Per t to Drill Number: (UNOCAL) Development ^ Exploratory ^ 18 340 3. Address: P.O. BOX 196247 ANCHORAGE, AK 99519 Stratigraphic ^ Service ~ .API Number: 50-733-20398-00 7. KB Elevation (ft): 9. Well Name and Number: 105' Anna - 38 8. Property Designation: 10. Field/Pools(s): Granite Point 18742 Middle. Kenai 'C' Sand 11. PRESENT WELL CONDITION SUMM Y Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth {ft): Plugs (measured): Junk (measured): 111453' 10598' 11400' 10548' none none Casing Length Size MD D Burst Collapse Structural 620' 20" 133# X-52 620' 3060 psi 1500 psi Conductor '} Surface 3535' 13 3/8" 61#/68# K-55 3535' I 5 3090 psi 1540 psi Intermediate Production 10068' 9 5/8" 47#/53.5# N-80 006 ' 9033' 6870 psi 4750 psi Liner 1630' 7" 35# S-95 23' 1453' 8840'-10115' 11830 psi 11640 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): ub g e: Tubing Grade: Tubing MD (ft): 10397'-10459', 10483'-10578', 9572'-9633', 9656'-9750', 9 4'- ~ g tring 3 1/2" / 2 7/8" 9.2# N-80 / 6.4# N-80 surface to 9684' / 9708'- 10663'-10675', 10918'-10962', 9846', 10082'-10125', 10175' S string 3 1/2" / 2 3/8" 9.2# N-80 / 4.6# N-80 10401' surface to 9671' / 11013'-11031', 11224'-11262', 10192', 10379'-10416', 428' 9673'-9683' 11275'-11295' 10447' Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Pr osal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP etch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: N/A Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is t e and correct to the best of my knowledge. Contact Larry P. Greenstein C~3 263-7661 Printed Name Larry P. Gre s in , Title Production Technician Signature - , j ' r ~~ /~ ~ Phone 263-7661 Date 8/3/2004 COMMISSION USE ONLY e Conditions of approval: Notif Commission so that a representative may witness Sundry Number: s Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~phMS Dr D3J u1'1 ~aV 2 ~ 7004 Subsequent orm Required: Approved by: CIO~JR ~ ~~OMM SSION Date: Form 10-403 Revised 12/2003 fNSTRUCTIONS ON REVERSE Submit in Duplicate r ~ ~ y ' • ~ , • Anna Platform AN 38 Temp Survey 5/30/03 MIT vs 11/24/01 MIT TEMPERATURE(DEG. F) 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 0 i ~ CCL _ S1=12HRS -5/30/03 TEMP RIH , , , - 11/24/01 Temp RIH - 5/30/03 PRES RIH, S1=12HRS i _ i 7 1 - - J i PKR @ 9707 PERFORATIONS ~- ='- C-5 10397-10459 C-5 10483-10578 C-6 10663-10675 C-7 10918-10962 C-7 11013-11031 _' C-8 11224-11262 C-8 11275-11295 PBTD=11400' BHP=4912.4 PSIG 12000 - - - ~ -~- ' -'000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 PRESSURE(PSIG) 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 - 7500 8000 8500 9000 9500 - 10000 10500 - 11000 11500 JAM. 1.200B ?:B~AM M0.074 P.2/2 Month..!y InjBctor Variance Aid 36-42 Dec ~002 607~32030g0D ANNA PLATFORM 1/1/2003 ~n_.~ ........ Hfs On Volume Injected '~IBG Press 9.625 CSG press 1~/1~002 24 230 3256 ~ 142 ~2 24 227 =~au 3296 142 1~002 2& 233 ~3B ~8 142 1W~O02 - ' 24 237 ~ 3364 14 1~12002 24 240 3380 33~ I~=~2 24' 24t 3384 3~ ' 121W2002 24 243 ' ~ 3366 141 .... 1219~002 24 246 ~ ~O0 141 1~10~002 24 ..... ~7 ~- ~06 ..... 141 ,._ 1~11~002 2~ 245 ~03 3403 139 1~1~002 " 24 '2~ " ~0~ 3408 100 1~13~? 24 241., ~11 ~4OO 100 t ~14/~ 24 233 3259 3~0 139 1 ~15~2 24 69 2~1 2750 1 fl0 . ~ 2116~2 24 149 3173' ~0 138 121t ?;002 '~4 ,. ~ 0~ 24~ 24~ ,136 _ 12118~002 20 112 3197 3497 138 1~1912002 24 ~ 31M 31~ 138 12~O/~gO~ "24 i 96 3265 3~55 138 1~2t~00~, 24 201 3275 ...... 3275 1~2002 ~ ' 206 ~95 ~9~ 136 ~2002 24 201 ~06 330~. 138 1 ~4/2002 24 ' ' 201 ~20 3325 1 1 Z~5~'002 ~ 201 3330 333p 1W2~002 "' 24 203 sasa 3350 ~ ~ _ 1~7~2 24 ..... 206 33~ 3~0 1212BI2~2 24. 210 3350 ~,75 - 133 12129;0~2 24 2t 1 '"~350 3375 1~ .... 12130~002 24 20~ 3360 3360 1 12~31~02 2~ '" 412 311~ 3141 .... ~. SCANNED MAR 1 0 2003 NOV. ?.~00~ ?:IB~M MO.?B8 P.~z8 Montitly ..~.~_-=torVar Aoee AN ~_~2 6ap ~02 '" &~?~3203~;~ ' ANNA PLATFORI~I t117/02 b71~00~ 24 '11 ~oOO .... 2o~o ,_ -' 8141200~ ~ '~" 3259' 3~9 530, ~5~2002 2~ ~, 3~ ~ 3163 '525 -- ' 6~6~002 24 106 .... 27~ 27~ 517 97712~2 ~ 75 ~95 2605 .... 9t812~2 24 72 2697 2697 .,.520 a~l~02 " 2~ 70 2505 ~uu 533 ._ 6110~2 24 60 20~ 2650 5t7 611112~2 24 80 ~OO 27fi5 614 611~gD2 ~4 80 2713 2~ ~14 glI312D02 ~ 79 2713 2700 ~11 011~2~02 2~ .... 80 z/zu 2700 611~12~2 24 92 ~n 2000 5~ .. 911~2 ~ 7~ 2661 26~1 509 611~0~ "24 ' 296 3367 ~67 520 g119~h~ 24 201 303~ ~6 " 509 9120/~00~ '24 166 . ,. 3070 ' 3070 5~ .... ~ 24 176 31~ 3105 508 912~2002 24 ~Ta 3140 3150 510 9124120d~ 24 186 3160 '" 3q50 , ~t0 ~12512002 24 167 ' 3160 3~ 510 ' 91~12002 24 164 32~ ~200 01271~2 24 103 3215 3215 510 ~2W2002 ' 24 190 n~n 32~ 510 W~2002 24 1~ 317~ 3i75 . .510 9~2~2 .2~ 172, 31~ 3~ 506 ~C;ANNED ~AR 1 0 20D3 SEP. 1.2002 6:44AM M0.431 P.Ss9 Report Na_me_ SiTing IMonthh/In]~t0r.,,V~rMnc~ AN Month L ~ Year APl No 5.07532E;~.11 Volume .......TBG 9,625 CSG ...... Date ..Hm On Injected Press ,~_reas,, 13.3T$ Cs~ Press Commenls 8/1/2002 O 0 0 0 565 812/2002 0 0 0 0 565 ~/2oo2 o o'" o o I,,, 57'0 ..... EF412002 0 0 0 0 875 a/s/2oo2" o ~ 1~% ' 20oo 570 8/6/2002 0 '-15 2130 2130 5'~ ....... 817/2002 '-0 ...... 9 2206 2250 555 818/2002 0 0 2244 2250 585 8/9/20"d2~- 0 8 2270 " 2270 5.58 811012002 0 0 2292 " 2292 556 8/11/2002 0 0 2341 2341 555 8112/2002 0 0 2389 2380 558 8/I 3/2002 0 0 245 250 530 8114/2002 0 0 0 0 555 8115/2002 0 D '1983 1800 533 8116/2002 - 0 0 2228 2250 533 ..... 8/17/2"d~'~;' ' o o 0 .... o 523 8/18/2002 0 0 0 0 0 8/19/2002 0 9 2189 2189 547 8/20/2002 0 '7' ' 2253 2253 541 8/2112002 0 2 0 0 52E! 8/22/2D~2 ........ 0 0 0 0 ' -' 56'4 ~/2~/2002 0 0 0 0 .... 580 5/2412002 0 0 0 0 533 8/25/2002 0 ...... D" 0 0 570 8/26/2002 ...... 0 0 0 0 585 8/27/2002 0 0 O 0 595 812812002 0 0 0 0 585 al2912002 0 0 0 0 575 .... 813012002 0 0 0 0 .....560 8/311~,002 0 19 1770 1800 540 End M R~en Tbg Report Name String Month Year APl No Platform Date Created Monthly ln~ector Varlanc, AN 38.4~ Jul 2002 5.07332E+11 ANISe, PLATFORN 8/II02 "Volume "TBG 9.625 CS'G Date Hxs On Injected Press Press 13.376 CeQ Press Comments 7/1/200:~ 24 266 3565 3550 575 7/2/2002 24 259 3490 3500 575 7/3/2002 24 274 3500 ' ;~500 575 714/2002 24 2?¥ 3505 3500 580 715/2002 24 223 3115 3150 560 716/2002 24 138 3145 3150 565 7m2002 24 126 3085 3100 560 718/2002 24 150 3141 3141 581 7/g/2002 24 148 3164 3184 581 7t10/2002 24 264 3497 3497 567 7/11/2002 24 270 3448 3448 575 7112/2002 24 252 3442 ~J42 " 577 71i3/2002 24 254 3458 3458 581 7/14/2002 24 251 3466 3486 584 7/15/2002 24 36 2385 2,~C~0 57b 711612002 2~' I 2256 2300 575 7/17/2002 24 (} 22 t 5 2250 380 7118/2002 24 O 21~0 2200 575 7/19/2002 24 0 2t 70 2200 580 7/20/21~2 24 Q 2.:155 2200 575 7/21/2002 24 0 2150 2200 575 7/22/2002 24 0 2145 2i45 578 7/23/2002 24 0 2141 2141 580 7/24/2002 23.5 1 2103 2103 581 7/25/2602 24 0 2109 2109 581 7/2612002 24 0 2103 2103 581 7/2712002 24 0 2103 2103 584 7/28/2002 24 0 2'~02 2102 566 7129/2002 24 0 2i 0~) 21 O0 585 7130f2002 24 0 0 0 555 7t31f2002 24 0 0 0 575 RECEIVED AUG 0 1 AI~ Oil & Gas C,,ons. C, ommission Ancho 9e MAY. 1.£00£ 9:59AM M0.806 P.8/8 Repor~ Name Tbg Strln,,g, Time Period Date Created _W,"terflood Injector Well Status AN 36-42 Last Month 5/I!02 Ou~r Ceg Length Volume Tbg Prm~ Csg Press Pre~s Date ..... (h.,,°.Um) ...... ~Pd) (psi) (psi) (psi) 4/30~002 24 266 ~4~8 3~0 , 4,129~002 24 305 344,2 3~45 519 4128t2002 24 301 3486 3450 52 ~27~002 24 332 3414 3~00 533 4/26/20D2 24 100 2763 2750 563 4125/20D2 24 3 2450 2450 500 4J24/20D2 24 13 2458 2450 500 4/23/2002 24 195 2578 2550[ 50~ ~2~00~ 2~ 20~ ~.~ ~ ~0 4/21~002 24 249 3461 3465 517 ...... : 4120~002, ,, ,,~, ..... 2~ 250 ~459 3450 ~ 0 4/19G002 ~ 250 3466 3470 0 4118/2002 24 250 3472 3470 5~6 4/1712002 ~ 240 3451 3460 514 4/16/2DD2 24 249 3467 3465 516 411S~002 24 250 3452 3450 ........ 4114/2002 ~ 249 3456 3450 4/~ ~002 24 24~ ~440 34s0 .......... 4ii2/2002 .............. ~ 245 3442 3450 4!11/2002 24 2~ ~39 3450 514 4110/2002 24 244 3425 ~4SO ~ 41912oo2 24 22~ ...... ~413 3400 515 418120~2 ........ 24 234 3427 3450 520 ..................... ~'~/2002 ............. 24 23~ 3405 34o5 515 41612002 24 212 3~15 3315 510 4~5~2002 ~ ' E6e. , ,~, .. ~plO ~310 41412002 ~ 248 3245 3~45 510 413/2002 ~ ~21 .............3445 3445 515 41212002 24 219 3415 3415 295 4/112002 ~ 230 3390 3390 515 End Of Report ~PR. 1.£00£ 8:31~M M0.659 Report Name IMdii~.hlY I~e=~or varlanm Tog String AN 38-12 Month I Year Mar I 2002 APl NO 5.07332E+11 P.!m ,tform 1 Da~ Created ANNA PLATFORMI 4/1/02 Volume 'TBG 9.625 .... D,a~ Hrs On Injected, Press Press 13_.375 Csg Press Commen.lp._ 3/1/2002 .......... 24 258 .... 3.388 3400 15,,0 312/2002 24 2I 0 33gl 3400 '~ 50 313/2002 2;4 233 3259 ~00 '150 ............ ~14/2002 ..... 24 236 "' 32 .~,,6 3300 '150 315/2002 2,.4 236 ' '3302 ,, 3310 151:] 3/612002 2,4 236 3309 3300 150 .... 3/712002 24 2'~5 3319 3330 ..... 150 . 3/8i:~0'02 24 235" 3319 3330 ..... 150 :] .... 319i~0'0-2 ,., 22 227 ,,,3303 33'10 ....150 3110/2002 24 212 3197 3200 '~ 50 311t/2002 24 204 3~97 . 3200 15'0 3/12/2002 24 0 61 100 150 .... :~113/2002 24 "'- 0 0 0,, 150 3/14/2i:)"0'2 24, 22 2298 2400 ,, 150 ............. ~/15/2002 24 146 2503 2550 150,, 3/16/2002 24 ' 159 .... 3427 " 34,50 150 ....... 3/17/2002 24 229 3261 3300 130 311812002 24 290 33'1,5 33'15 '150 311912002 '~24 255 3-~0 3360 ..... ~ 50 3f2012002 24 253 3400 ...... 3400 150 .... 3/21/20,0,,2 24 .... 255, 3425 ' '3425 15~) 3122/2002 ....... 24 255 ,. 3440 3.440 '150 3/2312002 .2~ 238 3390 3390 ..,'150 3124/2002 24 237 340'5 3405 150 .. 3/25/2002 24 '232 2850 ' ~Z850 150 - 3/26~2002, . 24 200" 3356 3350 150 3127/2002 24 ......... 247 3406 ,~ 3400 1,50 3/2812002 24 245 3428 34..00 150 312g12002 24 241 3438 3430 0 313012002 24 24'1-', .... 3450 3450 ...... 0 . .. 313~1'2'~2 __ 24 239 3.4.,5~ 3450 t50 SCANNED 1 0 2003 ~Historical Deta >Wells >Sb lus (defly info) >Waterflood lqj~-tors Select Time l.Las~ Month -~.T] l Select Tbg lAN 3842. '-. ~'] Period: String: Report Name Tbg String Time Period Date Created Waterflood Injector Well Status AN 3e-42 Last Month 612/02 · Dale Length Volume Tbg Press C$g Press Outer csg Press (hours) (bpd) (psi) (psi) (psi) 6/1/02 24 50 2480 2480 550 S/3~/02 24 50 2570 2570 54 5/30/02 24 52 2566 2565 540 5/29/02 24 52 2560 2560 540 5/28/02 24 53 2545' 2545 535 5/27/02 24 76 2500 2500 535 5/26/02 24 89 2870 2900 552 6/25/02 24 72 2533 2500 55~ 5/2,t/02 24 205 3300 3300 555 5/23/02 24 1~0 3019 3000 548 5/22/02 24 13:~ 3017 3000 548 $/21/02 24 134 2980 3000 548 5/20/02 24 131 2952 2950 550 5/19/02 17 99 3245 32,t5 505 5/18/02 21 I83 3242 32~5 538 5/17/02 22 208 3208 3210 539 5/16/02 24 22§ 34:1.1 34;[0 533 5/15/02 24 22~ 3'i06 3410 533 5/]4/02 24 228 3~8 3410 533 5/13/02 2'~ 220 3381 3385 531 5/12/02 24 230 338¢~ 3400 530 5/.~ 1/02 24 263 3360 3350 530 5/~0/02 24 266 3~00 3~00 535 5/9/02 24 93 ~91 3100 556 5/8/02 24 224 3360 3375 515 5/7/02 24 224 3369 3350 516 5/6/02 24 221 3350 3350 51,4 5/S/02 21 189 3214 3200 525 5/4/02 24 234 3391 3400 520 5/3/02 ~8 206 3463 3465 525 Comments RECEIVED JUN 0 3 ~,, ~ I~ne of Report http ://kodiak,anchonown,unocal.com/da/templates/tabular,asP 6/2/2002 An-3 $ Temp Survey MIT • Maunder, Thomas E (DOA) From: Greenstein, Larry P [greensteinlp@unocal.comj Sent: Monday, June 09, 2003 9.15 AM To: Tom Maunder Subject: An-38 Temp Survey MIT Attachments: AN38RDMay03.xls; An-38 403 Variance 6-06-2003.x1s Tom, • Page 1 of 1 Attached you will find the temp survey run on May 30, 2003 for the An-38 injection well. All temperature indications are that the water is going into the injection interval and nothing is moving uphote. Unocal requests a continuance of the waiver so that injection may continue on this well per the attached sundry. Larry «AN38RDMay03.xls» «An-38 403 Variance 6-06-2003.x1s» ~~~,ir1N~t~ APR ~ ~ 2~€~8 4/8/2008 • 30 40 50 60 70 0 :a . 500 ~" 1000 .; - - 1500 2000 s""' ~r 2500 ~' 3000 =~ G 3500 „+ ~; 4000 ~' 4500 ~: ~5; 5000 ~=: " ='~' • Anna Platform AN 38-2 Temp Survey 5/30/2003 MIT TEIIPERATURE(DEG. F) 80 90 100 110 120 130 140 150 160 170 __1 - 5500 - =_ 6000 6500 "- 7000 7500 ~ ~~+ ~:< 8000 8500 - .: - PKR @ 9707' 9000 - ~, `~" PERFORATIONS 9500 - C-5 10397-10459 C-5 10483-10578 10000 `' : C-6 10663-10675 ~ C-7 10918-10962 10500 C-7 11013-11031 '" C-8 11224-11262 11000 - C-8 11275-11295 CCL -5/30/03 TEMP RIH, SI=I2HRS -5/30/03 PRES RIH, SI=12HRS 11500 PBTD=11400' BHP=4912.4 PSIG 12000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 PRESSURE(PSIG) Unocal Corporation Alaska Business Unit 909 West 9'h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) January 17, 2002 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: ANNA-38 Variance Request Dear Tom: Unocal is requesting a 2-year variance for ANNA-38 (Permit# 88-0034-0). The plan is to rerun the temperature survey every two years, report the daily dates/pressures monthly to the AOGCC and monitor the rates/pressures daily using Unocal's web-enabled surveillance system. The attached baseline and follow-up temperature surveys show no anomalies indicating injection is occurring above the injection interval. Please review the attached data and approve the variance. If you have any questions, please call me at 263-7830 or email me at ruffc@unocal.com. Sincerely, Senior Reservoir Engineer Cook Inlet Waterflood Management O:XAOGCC\CorrespondencesXAN-38 2002-01-11 Variance cover letter.doc ORI¢INAL Jeff Dolan 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) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: X Middle Ground Shoals 4. Location of well at surface 8. Well number Leg 2, Slot 6, 795' FNL, 604' FEL, Sec. 12, T10N, R12W, SM Anna-38 At top of productive interval 9. Permit number 1460' FSL, 1009' FWL, Sec. 7, T10N, R1 lW, SM 88-0034-0 At effective depth 10. APl number 50- 733-20398-00 At total depth 11. Field/Pool 1445' FSL, 798' FWL, Sec. 7, T10N, R11W, S.M. Middle Kenai "C_" Sands 12. Present well condition summary Total depth: measured 11,453' feet Plugs (measured) true vertical 10,598' feet Effective depth: measured 11,400' feet Junk (measured) true ve~ical 10,548' feet Casing Length Size Cemented Measured depth True vertical depth Structural 620' 20" 1086 sx 620' 620' Conductor Sudace 3535' 13-3/8" 2,450 sx 3535 3529 Intermediate Production 10,068' 9-5/8" 950 sx 10,068 9033 Liner 1,630 7" 9,823 11,453 8840 10115 Pedoration depth: measured See Attachment true ve~ical See ABachment Tubing (size, grade, and measured depth) Long Stdng 3-1/2", 9.2¢, L-80, BuBre~ ¢ 9684' & 2-7/8", 6.4¢, N-80, Buttre~ f/9708' to 10,375' Sho~ String 3-1/2", 9.2¢, L-80, BuBress ~ 9670' Packers and SSSV (~pe and measured depth) 13. Attachements Description summaw of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well clarification as: 16. If propo~l well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Se~ice: 17. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge. Signed: ~ ~'"' Title: Senior Rese~oir Engineer Date: 1/10/2002 ~ ~ FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commi~ion so representative may witne~ lApproval No. Plug integri~. BOP Test Location clearanceI Mechanical Integri~ Test ~ ~~ S~bseque.t [orm req.,red ~0- ~~ Oricn81 Signed By Approved by order of the Commi~ioner Cammy Oechsli Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE 0 0' 500' 1,000' 1,500' 2,000' 2,500' 3,000' 3,500' 4,000' 4,500' 5,000' 5,500' 6,000' 6,500' 7,000' 7,500' 8,000' 8,500' 9,000' 9,500' 10,000' 10,500' 2O Anna An-38 Comparison Temperature Survey 4o 6o 10/82o8/00 vs 11/24101 100 120 140 160 180 200 ~ 10/28/00 Temp Survey ~ 11/24/01 Temp Survey Cavity ~ 9707' ~,nna 38 Temp Survey 10-28-00 & 11-24-01 .xls 01/16/02 GRANITE POINT FIELD GP ADL 187,42 Well No. 58 LOWER KENAI SANDS PLATFORM ANNA Xo 3 1/Z' 8lin x 3 1/',LP* M XO 2 ?/8'* But~ x 3 ~ IqD ~ 2 7_~" NfO B~tt &41~R 1O373' XO 27~1~ M~Dx 2 7')'~' Butt 10374' 10M7-1~ lO483-1o57~ lO663-1~ 1O118-10112' 11013-11031' 11~24-.112e2' 11275-t1~ XO 2 ~9'* 8RD x 3 1,A~ B~d~ r. Irdbi ~ 0--14-M 843 StX'D X M IMPD X 340 iftXq) t~742-38 NONE eat · 11451' 10el8--101~2' 11013,-11011' 11~24-,-11212' UNOCAL APl # 733-20398-00 Granite Point Field Well # An-38RD Slickline Proposal Revised 10/20/00 Rev #1 Assembled by Steve Tyler Objectives: 1 Qualify wellbore integrity, with temp surveys, to convert to an active injector. Wireline Problems: Tubing Size: Elevations Minimum I.D. 2 Gauge tbg, Tag TCP Guns. Cut TCP Guns off and allow to drop. Gauge tbg, Tag TCP Gun fish, Run Temperature Survey. Place well on Injection for 1 month. Re-run Temp Survey LS 3-1/2", 9.2#, N-80, Buttress Surf. to 2-7/8", 6.4#, N-80, Buttress 9888 to SS 3-1/2", 9.2#, N-80, Buttress Surf. to 2-3/8", 4.6#, N-80, Buttress 9859' to Kobe Cavity TCP Guns Max Deviation: Perforations: 9684' 10,401' 9671' 9683' 9684'to 9707' 10,401'to 11,308' Kobe Cavity 2.687" 9705' 3-1/2" x 2-7/8" XO 2.441" 9707' Max 36.68° @ 4,400' zone Top Btm Amt C-5 10,397' 10,459' 62' 10,483' 10,578' 95' C-6 C-7 10,663' 10,675' 12' 10,918' 10,962' 44' 11,013' 11,031' 18' C-8 11224 11262 38' 11275 11295 20' Brief History or Discussion · An-38 Slickline E-line Procedurel0-20-00.doc 10/19/00 Slickline E/line Procedure An-38 I. Well Preparation [Prior to Slickline Work] 1. Circulate pump from well. I1. Slickline Work [Gage tbg, Tag TCP Guns] Hold safety meeting with production, and slickline personnel. NOTE: This is an H2S Facility. Ensure that lubricator can be bled off to facility system. 1 2. Establish tag out procedure for wellhead valves while wireline is in the well. 3. Spot SCBA's for rig up/rig down operation. 4. Production will issue a "Safe Work" permit for Slickline work. Establish that well room is free of gas and H2S. 5. Establish whom slickline personnel is to contact for pressure test and to operate wellhead valves. Note: a pump-in sub with a valve is required below the wireline BOP's. 6. Open well room exterior door prior to breaking lubricator. 7. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. MU equalizing prong onto tool string. 8. RI and shear Kobe knock-out plugs in standing valve. POOH. 9. BO equalizing prong. MU pulling tool. RI and retrieve standing valve. 10. MU 2.25" gauge ring onto slickline tools string. 11. RI and tag TCP Guns @ 10,401' [2.687" ID through Cavity @ 9,705']. POOH. BO GR. 12. RD Slickline. III. E/line Work [Cut TCP Guns Off] Hold safety meeting with production, APRS personnel and Drilling Forman. NOTE: This is an H2S Facility. . 2. 3. 4. Sm Note: a 6. 7. Ensure that lubricator can be bled off to facility system. Establish tag out procedure for wellhead valves while wireline is in the well. Spot SCBA's for rig up/rig down operation. Production will issue a "Safe Work" permit for E/line work. Establish that well room is free of gas and H2S. Establish whom APRS personnel is to contact for pressure test and to operate wellhead valves. pump-in sub with a valve is required below the wireline BOP's. Open well room exterior door prior to breaking lubricator. RU APRS unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. An-38 Slickline E-line Procedurel0-20-00.doc PAGE #2 8/4/99 8. Initiate "UNOCAL ALASKA - PERFORATING / EXPLOSIVES SAFETY CHECKLIST". Warn all non- APRS personnel to stay clear of explosive loading / arming area. 9. MU Jet cutter, CCL and Weight Bars onto E/line. 10. RIH tag TCP guns @ 10,401'. Log up to cavity. RI correlate Jet cutter 1' above Ported sub w/XO @ 10,737'. 11. When APRS and UNOCAL witness have agreed on depth, fire jet cutter. (Note: watch weight increment indicator for indication that jet cutter fired). POOH. 12. Confirm jet cutter had fired. RD APRS. IV. Slickline Work [Gage tbg, Tag TCP Gun Fish, Run Temp Survey] 1. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. MU 2.25" gauge ring onto slickline tools string. 2. RI and tag TCP Gun fish ( should be at about 10,465' ) [2.687" ID through Cavity @ 9,705']. POOH. BO GR. 3. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. 4. Record time gages are started and the time slickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) 5. MU Temperature probe onto wireline tool string. Wait till bombs are "awake". 6. RIH at 60' per min making 2 minute stops every even 1,000' to tagged depth [2.687" ID through cavity @ 9,705']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) 7. Wait 5 minutes at 8800'. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) 8. Once out of hole down load data. Insure data is good prior to releasing Slickline. 9. RD Slickline. Put well on injection. Vi Slickline Work After One (1) Month of Injection [Gage tbg, Run Temp Survey] 1. Take well off injection 12 hrs prior to rigging up slickline 2. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. 3. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. 4. Record time gages are started and the time $1ickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) 5. MU Temperature probe onto slickline tools string. Wait till bombs are "awake". 6. RIH at 60' per min making 2 minute stops every even 1,000' to tagged depth [2.687" ID through cavity @ 9,705']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) Wait 5 minutes at 8800'. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) . An-38 Slickline E-line Procedurel0-20-00.doc PAGE #3 8/4/99 8. Once out of hole down load data. Insure data is good prior to releasing Slickline. 9. RD Slickline. Put well on injection. An-38 Slickline E-line Procedurel0-20-00.do¢ PAGE #4 8/4/99 Pollard Wireline Inc. Survey Data Sheet Location Anna Well # AN-38 Date 11/24/01 Gauges On 03:30:43 Gauges Off 10:39:40 Bomb Serial # Depth KB Arrive Leave Duration Lub 03:40:00 !04:05:00 10 min 1000' 04:20:24 04:22:24 2 min 2000' 04:38:37 04:40:37 2 min 3000' 04:56:39 04:58:39 2 min 4000' 05:14:55 05:16:55 2 min 5000' 05:33:17 05:35:17 2 min 6000' 05:51:25 05:53:25 2 min 7000' 06:09:04 06:11:04 2 min 8000' 06:26:58 06:28:58 2 min !8800' 06:41:56 06:46:56 5 min 9000' 06:48:09 06:50:09 2 min 10000' 07:06:05 07:08:05 2 min 10380' 07:14:14 07:19:14 5 min 10000' 07:25:28 07:27:28 2 min 9000' 07:43:38 07:45:38 2 min 8000' 08:01:59 08:03:59 2 min 7000' 08:20:04 08:22:04 2 min 6000' 08:38:05 08:40:05 2 min 5000' 08:55:42 08:57:42 2 min 4000' 09:13:23 09:15:23 2 min 2976' 09:31:08 09:33:08 2 min 2000' 09:48:39 09:50:39 2 min 1000' 10:06:20 10:08:20 2 min Lub 10:23:20 10:33:20 10 min Turn Encoder off 10:40:16 Date: Wireline Company: Work Being Done: Present Operations: UNOCAL Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: UN ,.;AL ALASKA RESOURC,_,¢ WELL SERVICE REPORT 11/24/01 Pollard Wireline Inc. Temp & Pressure Survey Done G. Brown Anna Unit Tubing Hanger 2.44" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: An-38 Anna AFE # 143917 D. Pollard/Tomlinson/Kroto 8 10380' 36' 2.25" Time Operation Details, 00:30 Rig over to AN-38RD ..... 02:00 RIH w/2.25" GR to 8800', POOH 03:45 RIH w/Tandem Quick Temp Tools, making stops to 10380', POOH, making stops 10:30 OOH, download data 12:30 Rig over to AN-25 ,, , ,, Tool Cost: 12 hr min 3 man $2,080.00 2.25" GR $50.00 Single Electric Gauge $650.00 Single Quick Temp $800.00 Work String Detail: (1.5" TS) RS, KJ, 10' Stem, KJ, O J, Spangs Description of any NONE tools or debris left in the hole: Brief Summary of !Gauge Ring run & Quick Temp Survey Total Work Comleted: Total Hours Worked 12 Total Tool Cost $1,500.00 Total Hour Cost $ 2,080.00 Well Downtime Hr. Approved by: Ticket # :1 Daily Cost:I $ Glynn Brown P-566 3,580.00 I Day # '1 Cumulative Cost: $ H2S PPM Wire Test 3,580.00 Code: AFE # 143917 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: x 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or K~ Union Oil of California (Unocal) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Pt. St. 18742 P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface 8. Well number Leg 2, Slot 6, 795' FNL, 604' FEL, Sec. 12, T10N, R12W, SM An-38 At top of productive interval 9. Permit number/approval number 1460' FSL, 1009' FWL, Sec. 7, T10N, R1 lW, SM 88-0034-0 At effective depth 10. APl number 50-733-20398-00 At total depth 11. Field/Pool 1445' FSL, 798' FWL, Sec. 7, T10N, R1 lW, S.M. Middle Kenai "C" sand 12. Present well condition summary Total depth: measured 11,453' feet Plugs (measured) true vertical 10,598' feet Effective depth: measured 11,400' feet Junk (measured) true vertical 10,548' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 620' 20" 1,086 sx 620' 620' Surface 3,535' 13-3/8" 2,450 sx 3,535' 3,529' Intermediate Production 10,068' 9-5/8" 950 sx 10,068' 9,033' Liner 1,630' 7" 9,823- 11,453' 8,840- 10,115' Perforation depth: measured See attachment true vertical See attachment Tubing (size, grade, and measured depth) Long String 3-1/2", 9.2#, L-80, Buttress @ 9684' & 2-7/8", 6.4#, N-80, Buttress f/9708' to 10,375' Short String 3-1/2", 9.2#, L-80, Buttress @ 9670' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) /' RECEIVED Treatment description including volumes used and final pressure AUG '~ 0 14. Representative Daily Averaqe Production or Injection Data AlasKa 0Il ~x lies ¢j1~ll5, CullJlll~sui011 Oil-EEL Gas-Mcf Water-Bbl Casing Pressure Arlch0raf~P~ing Pressure Prior to well operation 0 68 105 90 120 Subsequent to operation (['~ ~,~¢~'~0~,'1 ~ - 447 3450 3491 15. Attachments: ~ 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~ Title: _ ~J f~,/ ~/' ~"/~1¢~'" Date: Form 10-404 Rev 0 ~ SUBMIT IN DUPLICATE Anna 38 Perforations MD TVD Subsea Zone Top Btm Top Btm Top Btm Amt Comments C-5 10,397' 10,459' 9,297' 9,345' -9,170' -9,218' 10,483' 10,578' 9,369' 9,441' -9,242' -9,314' C-6 10,663' 10,675' 9,513' 9,521' -9,386' -9,394' C-7 C-8 10,918' 10,962' 9,715' 9,755' -9,588' -9,628' 11,013' 11,031' 9,796' 9,812' -9,669' -9,685' 11,224' 11,262' 9,964' 9,994' -9,837' -9,867' 11,275' 11,295' 10,000' 10,014' -9,873' -9,887' 62' 95' 12' 44' 18' 38' 20' 8/9/01 8:55AM An-38 10-404.xls Attachment NOTE TO FILE In Re: Anna 38 (18742 #38)... PTD (188-034) Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled beginning in late April, 1988 and completed in late June, 1988. There is very little information available in the AOGCC well file. It does not appear that any of the original perforations have been altered since the original completion. A note in the file does indicate that Unocal employed a snubbing unit on the well in 1997. No information on that work is in the file. Unocal has provided a copy of the CBL run June 14, 1988. A copy of the log is not available in the AOGCC well files. The quality of the provided copy is not great. Two passes are presented one at 0 psi and the other with 1000 psi. A cement top is shown at about 10310' in each presentation, approximately 90' above the top perforation. The nonpressured pass indicates the presence of a microannulus. The initial wave arrivals are pretty consistent throughout the log run. When pressure is applied, there is improvement in the attenuation. The available information indicates there is cement present beginning about 90' above the top perforation. MI is indicated. The MIT demonstration methods and subsequent monitoring program will identify any deficiencies in isolation. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend approval to convert Anna 38 (188-034) as proposed. Tom Maunder Petroleum Engineer ~ O/t ~ - (:~ • Maunder, Thomas E (DOA From: Ruff, Christopher A [ruffc@unocal.com] ~~~~ ,~~" Sent: Wednesday, August 08, 2001 3:59 PM tlQ To: 'Tom Maunder' ~~-~ Cc: Dolan, Jeff J; Moultrie, Dan R; Dorman, Allen; Delago, Paul A; Myers, Chris S; Cole, David A Subject: RE: Step Rate Tests Results for Anna 21, 25, 37 and 38 Attachments: AN 21 Step Rate Test.xls; AN 25 Step Rate Test.xls; AN 37 Step Rate Test.xls; AN 38 Step Rate Test.xls ~~g~~~~ ~~ ~~ ~ AN 21 Step Rate AN 25 Step Rate AN 37 Step Rate AN 38 Step Rate Test.xls Test.xls Test.xls Test.xis Yes, we are. going to limit our rates as stated below, but plan to run further tests in the future that will allow us to increase the rates to the mechanical limit. "`="~' Here are better summaries of the data and the limits.. Delete the files sent previously. I have hardcopies of the files in the mail. Chris ~~~ APR 4 ~~~$ -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 08, 2001 12:58 PM To: Ruff, Christopher A Subject: Re: Step Rate Tests Results for Anna 21, 25, 37 and 38 '""'~-'- Chris, Thanks for the information. I need to look at the well drawings and refresh my memory. Only real question I have right now is with regards to An 38. Since it appears that the frac pressure was reached, will you be lowering the injection pressure to stay below it?? Tom "Ruff, Christopher A" wrote: > Tom, > Here is the data from the step rate tests on the above wells. We > didn't run > a SRT on Anna 32RD and 36 because we haven't finished the conversion yet. > The SRT's went very well. Unfortunately, due to a miss communication, > the SRT's weren't run up to the mechanical limits. The tests were > designed to run up to the mechanical limits {70% of the casing burst > strength or the maximum injection pressure for the pumps, 5000 psi). > Anna 37 and Anna 38's > tests are complete tests and this is the final submission, but Anna 21 > and Anna 25's tests were stopped early due to ambiguous instructions. > The Anna 36 conversion is on hold for at least 6 months, we want to > wait for > a response before converting this well. The Anna 32RD conversion is on > hold until we have time to analyze the casing pressure further. It > looks like there has always been some pressure on the outer casing 1 > that can't be permanently bled off. We are working on a d~gnostic plan. > Based on these tests and the casing burst strengths, the plan is to > limit the injection pressures as follows. > CONCLi3SI0NS Maximum Injection Pressure and reason for limit > An 21 3660 (Test stopped before reaching Frac Pressure or casing limit of > 4774 psi) > An 25 3400 (Test stopped before reaching Frac Pressure or casing limit of > 4025 psi) > An 37 4730 (Test stopped before reaching Frac Pressure or casing limit of > 6566 psi) > An 38 3820 (Apparent Frac Pressure observed at 3820 psi) > After we complete the temp survey's on these wells and make some > surface facility repairs we will rerun the SRT's for AN 21 and AN 25 > if we decide we > want to increase the injection pressure above the pressure which the current > tests have been run. > Chris > «AN 21 Step Rate Test.xls » «AN 25 Step Rate Test.xls» «AN 37 > Step Rate Test.xls » «AN 38 Step Rate Test.xls» > Name: AN 21 Step Rate Test.xls > AN 21 Step Rate Test.xls Type: Microsoft Excel Worksheet (applicationlvnd.ms-excel) > Encoding: base64 > Name: AN 25 Step Rate Test.xls > AN 25 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 37 Step Rate Test.xls > AN 37 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 3$ Step Rate Test.xls > AN 3$ Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 2 • i• 5000 4500 4000 3500 as a 3000 d 3 2500 a as c 2000 1500 1000 500 • SRT Data below apparent Frac ^ SRT Data above apparent Frac • Historical Data Mechanical Limit ---------- Linear (SRT Data below apparent Frac) Linear (SRT Data above apparent Frac) __ _ \\Ak-Anchorage\Groups\OOE\OOEFields\GPF1Anna\Waterflood\AN 38 Step Rate Test.xls ANNA-38 Step Rate Test Frac Pressure and Infectivity Analysis 4/3/2008 2:44 PM 0 200 400 600 800 1000 1200 1400 Rate (bwipd) .] • AN-38 Step Rate Test Frac Pressure and Infectivity Analysis 4500 4000 3500 ~ 3000 .N d 2500 N m °- 2000 as c ~ 1500 1000 500 0 Q Q Q ° ° ° ° ° o o o o o N N N N N ~ r r .- ~ O O O O O O ~ O O ~ r r N r r ~ ~ ~ r r ~ \\Ak-Anchorage\Groups\OOE\OOEFields\GPFWnna\Waterflood\AN 38 Step Rate Test.xls 1200 1000 800 ..., a .~ m 600 ~ c 0 a~ 400 ~ 200 0 Q 0 0 N O O lf) N r 4/3/2008 2:44 PM Anna Injection well test sheet Stop test when maximum allowable injection pressure is reached Well # Date /Time Rate Tbg psi Csg psi Choke Comments U1t~ll -ANNA-38 (bwpd) 13 3/8 e c o e ac 7/24/01 6:00 PM 597 3940 415 a es a er ow s a i ize or several days (Hook up chart to tbg pressure at this point) 7/29/01 2:00 PM 100 1945 378 og ac ua ra a an pressures before opening up well 7/29/01 3:00 PM 100 1948 378 og ac ua ra a an pressures r opening well up (attempt to crease rate 100 bwpd) 7/29/01 3:05 PM 210 2158 394 og ac ua ra a an pressures before opening up well 7/29/01 4:00 PM 189 2241 397 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 4:05 PM 305 2291 402 og ac ua ra a an pressures before opening up well 7/29/01 5:00 PM 285 2458 409 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 5:05 PM 407 2505 413 og ac ua ra a an pressures before opening up well 7/29/01 6:05 PM 368 2703 420 og ac ua ra a an pressures fter opening well up (attempt to crease rate 100 bwpd) 7/29/01 6:10 PM 497 2881 431 og ac ua ra a an pressures before opening up well 7/29/01 7:05 PM 481 3056 438 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 7:10 PM 613 3119 442 og ac ua ra a an pressures before opening up well 7/29/01 8:05 PM 578 3380 453 4/3/2008 \Wk-Anchorage\Groups\OOE\OOEFields\GPF\Anna\WaterfloodWN 38 Step Rate Test.xls 2:45 PM Anna Injection well test sheet og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 8:10 PM 713 3447 458 og ac ua ra a an pressures before opening up well 7/29/01 9:05 PM 691 3681 467 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 9:10 PM 798 3711 469 og ac ua ra a an pressures before opening up well 7/29/01 10:05 PM 790 3808 469 ac ua ra a an pressures r opening well up (attempt to increase rate 100 bwpd) 7/29/01 10:10 PM 902 3845 467 og ac ua ra a an pressures ' before opening up well 7/29/01 11:05 PM 907 3917 467 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/29/01 11:10 PM 1004 3947 469 og ac ua ra a an pressures before opening up well 7/30/01 12:10am 990 3977 464 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) CONTINUE SPREADSH EET IF NEEDED • 4/3/2008 \\Ak-Anchorage\Groups\OOE\OOEFields\GPF\Anna\Waterflood\AN 38 Step Rate Test.xls 2:45 PM SPUD ;~?.LL DATA Casing: ¢-~i~']~ Liner. ~] -ubin=: Hole Size '-~CF-~/~v-CAL iNTEGI{!T~' - PART Annulus Press Test: Z? ; 15 rain ; 30 man . Comments: ~C~_NiC~ i~G~~ - P~T ~2 Theoretical TOC Cemenu Bond Log (Yes or No) ~,'..In AOGCC File '~O~ CBL Evaluation, zone above perfs A~o %~% Produ=tion Log :. Ty'pe ; Evalua~±on CONCLUSIONS: Part fl: GRANITE POINT FIELD GP ADL 18742 Well No. 38 LOWER KENN SANDS PLATFORM ANNA C-8: 11224-112e2' 11275-112~5' Inl~l ~ 8-14-88 84~ BCX"I~ X 84 BIIII~ X 340 MQ~ 18742--38 A. 3 1/2" NaO eutt ,.2il ,~ B. xo 2 3v8,, 81~ x 3 1/2 B~tt 0673' 7" IJrm' a,~ · 11451' 13_3/9" 01 & 10307-10459' 10483-1057~' I0~18'--10g~2' 11013--11031' 11224-11262' 11275--11295' P1~111400' 14,53' BOROU(~H iLoo* ON COMPANY KFNAI ...--.,-% GRANITF POt 795 FNL & 604' FEL GP 18742 AMOCC PRODUCTION COMPAN¥ Z Z Co ~>~ o > All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to Clause 4 of our General Terms and Conditions as set out in our current Price Schedule. Run No. ONE Service Order No. 335451 Logging Speed 1800.0 F/HR EQUIPMENT DATA Tool Number 1 CME AT 45 Tool Number 2 CBS DA 75 Tool Number 3 CME AU Tool Number 4 CBC DB 79 Tool Number 5 AH 127 Tool Number 8 SGC SA 577 TOol Number 7 TCCA 153 TOOl Number 8 CAL YA 280 Tool Number 9 STM AA 152 Tool Number 10 TCM AB 116 Tool Number 11 WDM AA 491 Tool Number 12 :rEMARKS: TIE IN LOG USED WAS DA DENSILOG DATED 5/28/88. UNABLE TO OBTAIN COLLAR LOG DUE TO CBT CENTRLIZATION. REMARK.?.: PREMIUM CEMEHT [4ITH .2~': CFR-2, i 5~ HALAD 344, · 15X LWL.~ 15.6 40 BBL [.JATER LEAD, 125 BBL CEMEHT ;~ 6, BBL/r,IlI"~ STARTED PUMPIHG E~ t030 '6/10/88, FIHI:".:HED 1136 6/10 ......... · TS__(U&__2 ......... 400.00 800.00 (US/F) 107.00 ?.0000 GR (GAPI) 0.0 100.00 CCL -15.00 8.0000 15.000 15.000 MATH(DB/F) DATH(DB/F) 0,0 0,0 800.00 VDL 1800.0 CP 30.4 FILE 14-JUN-88 08:09 5"/100" I ~F;::.:L: .:;_.: :::;::: :t: , i '.' ~ ~ --, ,~ ~ ~ ~,-,~,- ~_~___~ ~ ~. ~,-~ ~-~:~-2~ 980 TOP 9900 10000 10100 10~00 10300 EST CEMENT '~ O'P ~o~oo 1 o5o o 10600 10;:'00 10800 10900 11000 11100 1 lEtO0 11300 FIB TD 11400 5"7100" CP 30.4 FILE 9 14-JUN-88 01:30 400.00 200.00 DT (US/F) -- 107.00 ?.0000 GR (OAPI) 0.0' 100.00 CCL -18.00 2.0000 SENSOR HATH(DB/F) 15,000 0.0 OATH(DB/F) 15.000 0.0 200.00 VOL MEASURE POINT TO TOOL ZERO TOA 0.0 LTVD 0.0 TTSM 0.0 TT3M 0.0 TT1M 1.2 TT5 0.0 TT3 0-.0 TT1 1.2 SA6M 2.6 SA4M 0.0 SA2M 1.7 DMLV 0.0 SA5 0.0 SA3 0.0 SA1 1.2 CCL 29.8 DTUM 0.0 DTUT 0.0 UATM 0,0 UATT 0.0 CCCL 20.5 FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET FEET ER 23.1 FEET UTVO 1.2 FEET TTGM 2.G FEET TT4M 0.0 FEET TT2M 1.7 FEET TTG 2.6 FEET TT4 0.0 FEET TT2 1.7 FEET MNLV 0.0 FEET SASM 0.0 FEET SA3M 0.0 FEET SA1M !.2 FEET SAG 8.6 FEET SA4 0.0 FEET SA8 1.7 FEET TENS 0.0 FEET DTLM 0.0 FEET DTLT 0.0 FEET LATM 0.0 FEET LATT 0.0 FEET PARAMETER3 NAME VALUE UNIT MAME VALUE UNIT DDEL 0 DWCO 180 SFPI 75.0000 TTFF 15.0000 FTTM 285.020 TTRA DISA DAGC ALLO FMSO 2?5 US MV US US US I1~ CSIZ 7.00000 DS 8.50000 DSIH 10 SALL .500000 MFPI 82.0000 MTTM 228.020 AVMU 190.000 DOOR DISR DGAI 100.000 VMSO 366 IN IN US MV MV US US/F US I1~ laO,O, p, r,,,-, =oo.u=u u~ MTTM 228.020 TTRA ~ISA ,~ AVMU 190.000 CBCT DB ~GDA ~AGC ALLO DGAI 100.000 FMSG 2?5 US YMSG 366 ~MSG 126 US MMSG 218 US ~WF I 400.00 200.00 DT 107.00 7.0000 i GR (GAP[> _ _ HAT~(_D~/_F2 .... o.o lOO.OO 1 . oo o.o CCL D~T~(~?F) VDL -18.00 2.0000 15.000 0.0 200.00 1200.0 CP 30.4 FILE ? 13-JI.IM-88 17:29 5"/100" i . i --LFI~ 9800 TOP OF 9900 ~ -.NAT N - lOuOO .................. ! i BOTTOM OF 9 5/8" 10100 10:~00 10300 EST CEMENT T'O P 10700 10800 10900 · · ' T * 4 .......T ~-~ _ 11000 11100 11200 TO-- 11400 5"/100 CP 30.4 FILE ? 13-JUN-88 16:56 400.00 800.00 BT (US/F) 107.00 ?.0000 GR (GAPI) 0,0 100.00 CCL -18.00 8.0000 SENSOR TOA 0.0 FEET LTVO 0.0 FEET TTEM 0.0 FEET TT3M 0.0 FEET TTIM 1.8 FEET TT5 0.0 FEET TT3 0.0 FEET TT1 1.8 FEET SA6M 8.6 FEET SA4M 0.0 FEET SASM 1.7 FEET BNLV 0.0 FEET SA5 0.0 FEET SA3 0.0 FEET SA1 1.8 FEET CCL 29.8 FEET DTUM 0.0 FEET BTUT O.O FEET UATM 0.0 FEET UATT 0.0 FEET CCCL 80.5 FEET HAME VALUE BHS CASE DDEL 0 DNCQ 180 SFPI 75.0000 TTFF 15.0000 FTTM 88S.080 TTRA DISA CBCT DB .... r'j ET rj (__~/_F2 _ _ 15.000 0.0 llATN(DB,."F) 15.000 0.0 MEASURE POINT TD TOOL ZERO 800.00 GR 23.1 FEET UTVO 1.8 FEET TT6M 8.6 FEET TT4M 0.0 FEET TT2M 1.? FEET TT6 8.6 FEET TT4 0.0 FEET TT8 1.7 FEET MNLV 0.0 FEET SA5M 0.0 FEET SASM 0.0 FEET SA1M 1.8 FEET SA6 2.6 FEET SA4 0.0 FEET SA2 1.7 FEET TENS 0.0 FEET DTLM 0.0 FEET DTLT 0.0 FEET LATM 0.0 FEET LATT 0.0 FEET VOL PARAMETERS UNIT US NV US U S NAME VALUE CSIZ 7.00000 BS 8.50000 BSIM 10 SALL .500000 MFPI 88.0000 MTTM 888.080 AVMU 190.000 BGOA DISA UNIT IH IN US NV NV U3 US/F 1200.0 ~ v ~WC~ 120 SFPI ?5.0000 TTFF 15.0000 FTTM 285.020 TTRA DI3A CBCT DB DAGC ALLD FM3G 2?5 U~ U 3 ~,~ ~m ~VVVV DSIM 10 ~ALL .500000 HFPI 82.0000 NTTM 228.020 AYMU 190.000 DGOA DI3A DGAI 100.000 YM3G 366 HMSG 2!8 400.00 ~00.00 (U3/F) 107.00 GR <GAPI) 7.0000 t ~.0000 0.0 CCL -18.00 MATH(DB/F) 15.000 0.0 DATH(DB/F) 15.000 0.0 t200. VDL O0 lEtO0.0 CP 30.4 FILE 6 13-JUN-88 17:54 5"7100' 11100 11200 .... ?- I "i ' - T ...... ~ ..... L ? ........ ..... ~- 4. ; ..(- [ ; i -;-4-: .... I~I ~ _. . -~ ...... ~_. ........ ~~ , , , ~ · I~4-. : ..... i -.- ~ ........ ..... .... ......... CP 30.4 400.00 ~00.00 DT (US/F) 107.00 7.0000 OR (GAPI) 0.0 100.00 CCL -18.00 E.O000 , SENSOR TOA 0.0 FEET LTVO 0.0 FEET TTSM 0.0 FEET TTSM 0.0 FEET TT1M 1.~ FEET TT5 0.0 FEET TT3 0.0 FEET TT1 1.2 FEET ~AGM ~.G FEET SA4H 0.0 FEET SA2M 1.7 FEET ~NLV 0.0 FEET SA5 0.0 FEET SA3 0.0 FEET SA1 1.~ FEET CCL ~9.8 FEET ~TUM 0.0 FEET DTUT 0.0 FEET UATM 0.0 FEET UATT 0.0 FEET CCCL ~0.5 FEET NAME VALUE ~HS CASE ~EL 0 11300 -- FR -- TD 5"/100 ' FILE REPEAT SECTION 13-JUN-S8 17-'4S UNIT US NATN(DB/F) 15.000 0.0 OATH(DB/F) VDL i15.000 0.0 ii~O0. O0 MEASURE POINT TO TOOL ZERO GR 23.1 FEET UTVB 1.8 FEET TT6M 8.6 FEET TT4M 0.0 FEET TTSM 1.? FEET TT6 8.6 FEET TT4 0.0 FEET TT8 1.7 FEET MHLV 0.0 FEET SASH 0.0 FEET SA3M 0.0 FEET SAIM 1.8 FEET SA6 8.6 FEET SA4 0.0 FEET SA8 1.7 FEET TENS 0.0 FEET DTLM 0.0 FEET DTLT 0.0 FEET LATM 0.0 FEET LATT 0.0 FEET PARAMETERS NAME VALUE CSIZ 7.00000 DS 8.50000 UNIT IN IN 1200.0 ~UUL ~O.5 FEET PARAMETERS NAME VALUE UNIT NAME VALUE UNIT BH3 CASE CSIZ 7.00000 IN DDEL 0 US DS 8.50000 IN DWCD 180 DSIM 10 US 3FPI 75.0000 MY SALL .500000 MV TTFF 15.0000 US NFPI 88.0000 MY FTTM 885.080 US MTTM 888.080 US MODE ALL AVMU !90.000 US/F DGAI 100.000 CBCT DB VM3G 366 US DAGC ALLO MMSG 818 US FMSG 275 U3 DWF VDL ~MSG 18~ U~ l TT8 (US ) I DT (US/F) 50 000 100 O0 I i~ ~o- ....... ~.~0~ ~" . · ~ GR (GAPI) ~A8 (MV > io.o ~oo.oo o.o ~o.ooo ~ eCL ...... SA1 (MV ) WF 1-18.oo ~.oooo --o~5 50.000 ~oo.oo 1~oo.o CP 30.4 FILE 9 14-JUN-88 08:09 10000 , 10100 10~00 10:~00 10400 10500 10600 10700 10800 10900 V 'v 11000 11100 AA A CP 30.4 11~00 11800 -- ~TD-- 11400 5"/100 ' FILE 9 14-JUN-88 01:30 400.00 200.00 ~ _ !U.._~ / F ) 107.00 ?.0000 (~API) 0.0 100.00 CCL -18.00 2.0000 50.000 100.00 ~AE (NV ) 0.0 50.000 SA1 (HV 0.0 50.000 200.00 WF 1200,.0 SENSOR MEAgURE POINT TO TOOL ZERO TOA 0.0 FEET OR ~3,1 FEET i ~i i~ ~ A ~I ........ - __ -18.00 E.O000I ~_ FO.O ........ 50.000 IEO0.O0 .~. 1:~00,0 SENSOR M,-...$URE PBINT TB TBBL ZERO TOA 0.0 LTVB 0.0 TTSM 0.0 TTSM 0.0 TT1M 1.E TT5 0.0 TT3 0,0 TT1 1.~ SA6M ~.6 SA4M 0.0 SA2M 1.7 DNLV 0.0 SA5 0.0 SA3 0,0 SA1 1.2 CCL 29.8 DTUM 0.0 DTUT 0.0 UATM 0,0 UATT O.O CCCL 20.5 FEET GR ~3.1 FEET FEET UTVO 1.2 FEET FEET' TT6M 2,6 FEET FEET TT4M 0,0 FEET FEET TT2M 1,7 FEET FEET TT$ 2.6 FEET FEET TT4 0,0 FEET FEET TT2 1,7 FEET FEET MNLV 0,0 FEET FEET SA5M 0,0 FEET FEET SASH 0.0 FEET FEET SA1M 1.2 FEET ' FEET SAG 2.6 FEET FEET SA4 0,0 FEET FEET SAE 1,7 FEET FEET TENS 0,0 FEET FEET DTLM 0,0 FEET FEET DTLT 0,0 FEET FEET LRTM 0,0 FEET FEET LATT 0,0 FEET FEET NAME VALUE DHS CASE DDEL 0 DHCB lEO SFPI 75.0000 TTFF 15.0000 FTTM E85.0EO TTRA ~ISA C~CT D~ ~AGC ALLB SMSG 126 ~WF V~L PARAMETERS UNIT NAME VALUE CSIZ ?.00000 US DS 8.50000 DSIM 10 MV SALL .500000 US NFPI 8E.O000 US MTTM EES.0EO AVMU 190.000 DGBA DISA DGAI 100.000 US VMSG 366 US NMSG ElS UNIT IN IN US MV MV US U$/F US US 400.00 200.00 DT (US/F) 107.00 ?.0000 GR (GRPI) 0.0 100.00 CCL -18.00 8.0000 50.000 100.00 SAE (NV ) 0.0 iO.O 50.000 SR1 (NV ) 50.000 i;:>O 0. O0 HF 1200.0 CP :30.4 FILE 7 13-JUN-88 17:29 5"/100' --LR 9800 9900 10000 10100 : , , J ! i : i 10200 10300 10400 10500 ! ' ,l 10600 lO?O0 10800 I i ' i ' · i i t i I 10900 11000 11100 11200 J i CP 30.4 11300 ---TD 11400 5"/'100 ' FILE .... TT2 ( US ) 4o6:b-o- ............. ? 13-JUM-$$ 16:56 CP 30.4 D"/IO0 ' · F'IL 13-JUH-88 16:56 v v 400.00 200.00 DT (US/F) 107.00 7.0000 GR (GAPI) 0.0 100.00 CCL -18.00 8,0000 50.000 100.00 SA8 (MV ) 0.0 50.000 SA1 (MV ) 0.0 50.000 800.00 WF SENSOR MEASURE POINT TO TOOL ZERO TOA 0.0 FEET OR 83.1 FEET LTVO 0.0 FEET UTVO 1.8 FEET TTEM 0.0 FEET TT6M 8.6 FEET TTSM 0.0 FEET TT4M 0.0 FEET TT1M 1.8 FEET TTSM 1.? FEET TT5 0.0 FEET TT6 8.6 FEET TT3 0.0 FEET TT4 0.0 FEET TT1 1.8 FEET TT8 1.? FEET SAGM 8.6 FEET MNLV 0.0 FEET SA4M 0.0 FEET SAEM 0.0 FEET SASH 1.? FEET SASH 0.0 FEET DMLV 0.0 FEET SA1M 1.8 FEET $A5 0.0 FEET ~A6 8.6 FEET SA3 O.O FEET ~A4 0.0 FEET SA1 1.8 FEET SA8 1.7 FEET CCL 89.8 FEET TENS 0.0 FEET DTUM 0.0 FEET DTLM 0.0 FEET DTUT 0.0 FEET DTLT 0.0 FEET UATM 0.0 FEET LATM 0.0 FEET UATT 0.0 FEET LATT 0.0 FEET CCCL 80.5 FEET PARAMETERS NAME VALUE UNIT NAME VALUE UNIT BH3 CASE CSIZ ?.00000 IM DDEL 0 US BS 8.50000 IH DNCO 180 DSIM 10 US SFPI 75.0000 MV SALL .500000 MV TTFF 15.0000 US NFPI 88.0000 MV FTTM 885.080 US MTTM 888.080 US TTRA DISA AVMU 190.000 US/F CBCT DB DGOA DISA DAGC ALLO ~GAI lO0.O00 FMSG 875 US VMSG 366 US SNSG 186 US NMSQ 818 US DWF VOL ...... V ......... :T~__{g!__? .......... 4oo.oo eoo.oo DT (US/F) ......... ~8~_~___~ ......... lO?.OO ?.oooo 50.000 lOO.OO OR (GAPI) SA8 (NV ) 0.0 100.00 0.0 50.000 CCL SA1 (MV ) WF -i8~oo e.oo~o o.o 50.000 ~oo.oo 18oo.o CP 30.4 FILE 6 13-JUN-88 17:54 5"/100 SiAl 11100 11~00 11300 i ' I -- FR-- TD !: "' , ' ~ .' /V b; ~i, S"/lOO' REPEAT SECTION CP 30.4 FILE 6 IS-JUN-88 17:46 ......... 7~_ ~ ~___ ? ......... 400,00 ST (uszr) ......... ~?__~y_~_? ......... 107.00 7.0000 50.000 100.00 GR (GAPI) ~A8 (MY ) . o.o lOO.OO o.o 50.000 CCL ..... SA1 (Hr ) ur. -~8.o0 '8.0gO0' 0.0 SO.O00 800.00 1800.0 SENSOR HEASU~E POINT TO TOOL ZERO TOA 0.0 FEET OR ~3.1 FEET LTVD 0.0 FEET UTVO 1.8 FEET TTSH 0.0 FEET TT6M 8.6 FEET TT3H 0.0 FEET TT4H 0.0 FEET TT1H 1.8 FEET TTSH 1.? FEET TT$ 0.0 FEET TT6 8.6 FEET TT3 0.0 FEET TT4 0.0 FEET TT1 1.8 FEET TT8 1.7 FEET SA6H 8.6 FEET HNLV 0.0 FEET 3A4H 0.0 FEET SASH 0.0 FEET SASH 1.? FEET SA3M 0.0 FEET DNLV 0,0 FEET SA1H 1.8 FEET SA5 0.0 FEET $A6 8.6 FEET SA3 0.0 FEET $A4 0.0 FEET SA1 1.8 FEET $A8 1.? FEET CCL 89,8 FEET TENS 0.0 FEET ~TUH 0.0 FEET DTLH 0.0 FEET 9TUT 0.0 FEET DTLT 0.0 FEET UATH 0.0 FEET LATH 0.0 FEET UATT 0.0 FEET LATT 0.0 FEET ¢CCL 80.5 FEET ! i i i i i i i PARAMETERS NAME VALUE UNIT NAME VALUE UNIT ~HS CA~E CSlZ ?.00000 IN DgEL 0 US BS 8.50000 IN ~CO 180 9SIN 10 US SFPI ?$.0000 NV SALL .500000 HV TTFF 15.0000 US NFPI 88.0000 HV FTTM 885.080 US NTTM 888.080 US MODE ALL AVMU 190.000 US/F · DGDA VM~O 366 U~ DA~ ALLO MM$~ 818 U~ FM~ 275 US DWF VDL ~M~ 1~$ US ii i ! i iii i i ii i ! i i i i i COMPANY AMOCO PRODUCTION COMPANY WELL GP 1874.2 :¢/:38 FIELD GRANITE POINT BOROUGH KENAI STATE ALASKA $CHL. FR 11368.0 F SCHL. TD 11377.0 F DRLR. TD 11400.0 F Elev: KB 105.0 F DF 104.0 F GL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~.,OMMISSION APPLICATION FOR SUNDRY APPROVALS lpe of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: )rime extension: Stimulate: Change approved program: Pull tubing: Variance:/~ Perforate: Other: 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of well: Development: X Exploratory: Stratigraphic: Service: 4. Location of well at surface Leg 2, Slot 6, 795' FNL, 604' FEL, Sec. 12, TION, R12W, s~~C--' At top of productive interval ~ --- --- L~vE.D 1460' FSL, 1009' FWL, Sec. 7, T10N, R1 lW, SM At effective depth AUG £ At total depth ~$k._~ 0i'~ & GaS ~'~ 1~5' FSL, 798' FWL, Sec. 7, TION, R1 lW, S.M. 6. Datum elevation (DF or KB) 7. Unit or Property name Granite Point 18742 Middle Ground Shoals 8. Well number Anna-38 9. Permit number 88-34 10. APl number 50- 733-20398-00 11. Field/Pool Middle Kenai "C" Sands 105' KB MSL feet 12. Present well condition summary Total depth: measured true vertical 11,453' feet 10,598' feet Effective depth: measured 11,400' feet true vertical 10,548' feet Plugs (measured) Junk (measured) DUPLICATE Casing Length Size Structural 620' 20" Conductor S u rface 3535' 13-3/8" ~ Intermediate Production 10,068' 9-5/8" Liner 1,630 7" Perforation depth: measured ':"" See Attachment Cemented 1086 sx 2,450 sx 950 sx Measured depth 620' 3535 10,068 9,823 11,453 True vertical depth 620' 3529 9033 8840 1O115 true vertical See Attachment Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Long String 3-1/2", 9.2#, L-80, Buttress @ 9684' & 2-7/8", 6.4#, N-80, Buttress f/9708' to 10,375' Short String 3-1/2", 9.2#, L-80, Buttress @ 9670' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Conversion to a Water Injector 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Name of approver Date approved Oil: Gas: Suspended: Service: Signed: Title: v ' " "~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. l Plug integrity~_ BOP Test Location clearance ,-- ,. I ,3o0 - ~ c~ Mechanical Integrity Test_~ Subsequent form required 10- Llt~. ~,~..~ ~"~,~'~\"~, ~ -- ' ' p%r'O~_,--;,~,r,,-~ ~ ;)le~{~ 9~-v 5.%9, ct cJ; ':,.?c,,c-~.cr,-ck-~$.~> ',J~'~\~' ~ I~ Approved by order of the Commissioner D Taylor Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Procedures to Obtain Variances on Packerless Wells (version 4) February 9, 2000 It is preferred that wells have been shut-in for an extended period of time. Injection fluid will normally be filtered Cook Inlet water at ~55 deg F. 1. Do a base line temperature profile from'surface to top of perfs. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the Stops used in the baseline profile are not appropriate, make approp#ate stops in this profile and use in all subsequent surveys in this well. 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the ^OGCC. GRANITE POINT FIELD GP ADL 18742 Well No. 38 LOWER KENN SANDS PLATFORM ANNA · urfooe LeooUom Leg 2 mot &, OP Plotfom: ,Mrm SN 1~. TION. RI~I~, ~ .3..~JP~3 1/2" NO0 Butt 4. C.-.5: 10387-1045~ 104&.~.1057~' C-~: 10~63--10675' C.-.7: 10918-10~62' 11013-11031' C--8:11224..-112~2" 11275-11205' A. 3 1/2" 1480 Butt e.~jl ,AqI: 0171' Ii. XO 2 3/8' ei~x 1~,/2~ 0073* 8-14-88 ~4~ ~X"1~ X 84 BWPD X 340 IK~D oe-13-.ea o&-13-..88 enl.--gr, 11373-0790' 7" IJne' N~ · 11451' 1 t013-11031' 11224-11262' 11275--11295' ~NNA ?lottorm Leg 2, Conductor 6 Tyonek Sands o.o- 2o,o' aa l .oot/ x- 2 csc J 617.3- 420.0" SHOE d 37,0 - 353§.0' 13.375" OD 61.~/ft K-SS SURF CSG ,~S3.0'- 353f0' St-E AN 38-2 Cron[Je Point Held APl 50-733-20398-00 ~ ADL 18742 Tbg,.Jd F'lng DeCh 33,70 FI, l/ox. Dev. ~A{ Perfs. 15 Deg. l~.7 - ~.7 I-{ANER CIVV DC-B Dual'lbg Hanger ,,q..l 35.1' I{MIG~ ClVV DC-B Dud lbg Hanger 3.3.7- 9~.3~i500" ~ 9.~/f{ N-80 lBG LONG SIRING ,)3.7 - 9671.f 3.500" OD 9.20~/ft N-80 ]'13G SHORI STI;UNG 9825.5 - 9852,2' R~ JOINT E~ker lielx]ck Sleeve 9823.0- 9825.5' ~ {}518.4 - 100{]6.0' 9.{}Z5" O0,53.bOt/H N-80 PROD 1~§.0 - lO06&l' SHOE 11410.8 - 11412,5' FI.COLLAR Baker 11,I00.0 - 114§3,0' ~ENT PLUG 9823,0- I1451,2' T OD ~,OOt/ft S-95 LINER ' Pumping Oil Well Spud On ¢4-/88 Lost V//O ¢8/88 KB ELEV: lO'J' PB'rD: 11400' ~: 1163' 9707.0- 9708# C~)S~OVE]{ 3{/2II 8RD X 2 7/8" BfC 9683.0 - 9684.,Y CROSSO~ 2} 1/2" 8RD x 3 1/2" BTC 9671.4 - 9672.7' CI{OSSO~ 2 3/8" 8RD x 3 1/2" B[C 9672.7 9684J' 2,375" OD 4,q/ft'lB SHORT mING ~.~~. ~"~'~ 9~J 9707.0' LJJC Kobe 3" DBL"B" Pump C~ 9/07,0 - 11~06.8' 2.875" OD 6.50t/tt ~ LONG ~11~ 9~J- 9/07.0' RJJC Kobe 3" DBL "B" Pump C~ !1m72.7-10~7I~' cRossov~ 2 7/B" m) x 2 7/J~" ~10~7m.8 10~7~,./' POEB NIPPlf Baker Pod~d Dim Sub ~"'1~2,7 11~0~.8' PBFSUEI l~ker ~11/2' P~ Guns 11,~6.8 - 11J07.5' BULLPLUC Baker leg 2, Conductor 6 AN Granite Point Field APl 50- 733-20398-00 ...~.~. AOL 1874-2 Tbg..,,ad Flng Depth 3;3,70 Ft, Max. Dev. It Perfs, 15 Deg. 982,3.0- 9825.,5' ttANCER 982,5.5 - 9&,z22' RBIT~ JOINr Boker l'iekck Slem 9707.0-97o .¢ c o e; 9~.0-9r~4.3' CB~ 51/2" 8RD x 5 I/2" BfC 9~.,3 - 9707.0' LJJC Kobe 5" DElL "B" Pump Covitf 96843 - 9707.iY RJJC Kobe,t"~"B" Pump 6518.4. - 10066.0' !).62S" OD 53.50t/ft N-80 PBD CSG 10066.0 - 10068.1' SHOE 10,37t8 - 10.]74.7' P(~D NIPPLE Ebker Ported Disc Sub 10,372.7- 10,]7,I,.8' CROSSO~ 2 7/8" 8RD x 2 7/8" Btc 10397.0 - 10,t-59.0' PBB C-5, 62', 41-1PF, 4 1/2" B~ker TCP {funs, 90 Phose, 6 10402.7 - 11,t06.It' PERBUB I~ker 41/2' Fed' I;uns 1~t0 - 1057&0' PERB ¢4, 95', 41-1PF, 4 1/2" Bgker TOP 6uns, 90 Phose, 6. 106610 - 1067,,-5.0' PBF'$ C-6, 12', 4H?F, 41/2" Bgker'l'CP Cuns, 90 Phose, 6. 10918.0 - 10962.0' PERFS 6-7, 44', 4HPF, 41/2" Boker TCP 6uns, 90 Phose, 6, 110110 - 110~1.0' PBB 6-7, 18', 4HPF, 41/2" Bgker TCP 6uns, 90 Phose, 6~ Pumping Oil ~Vell Spud On 4/24'/88 BID: 11 TD: 1163' ~..~,,~ 11262.0' PBFS C-8, 38', 4HPF, 4.1/2" I~ker TCP Cuns, 90 Phose, §~ 11295.0' P~F$ C-8, 20', 4ttPF, 4 1/2" B~ker TCP Cuns, 90 Phme, 6~ Y"~ 11~6.§- 11,]07.5' BULLPLUG Boker ~I~tA ilduorm Le9 2, Oondudor 6 Tyonek Sands 114.10.8 - 114.12.5' FLCOLLAR Boker 11~.0-11t5t0' CigVI~ PLUG 982,t0 - 1161.2' 7' OD ~.O~/fl S-95 UNER 114.51.2 - 11~-55,0' FLOAI'SHOE ~k~r Pumping (Iii Well Spud On ¢¢8 AN 58-2 Gr(]nite Point Field APl 50- 7~5- 20~98-00 BEV: PBI'D: 11400' TD: l16Y ~. ADL 18742 Tl]g.. id Flng Depth 3:3.70 Ft. Max. Dev. ~,t Perfs. 15 Deg. 10402.1- 11306.8' PERFSUB Baker 4.1/2' Peal' guns l~l,O -'10,1.59.0' PERF'S C-5, 62', ~PI:, 41/2" ~ker TCP Guns, 90 Phase, 1~:t0 - 10578.0' PERFS C-5, 95', ,filE, 41/2" B~ke~ TCP (;uns, 90 Phase, 6. 1066:].0 - 1067,5.0' PERF'S C-§, 12, ~PF, 4.1/2" i~ker TCP guns, 90 Phase, 10918.0 - 10962.0' PERF'S (:-7, ~', ~PF', 4 1/2" B~ker TCP Guns, 90 Phase, 110110 - 110:~1.0' PERFS C-7, 18', ,fltPF, 41/2" Boker TCP guns, 90 Phase, 11224..0 - 1126Z0' PERF'S C-8, 38', 41-1PF, 4.112" B(]ker TCP Guns, 90 Phase, 6~ 11275.0 - I!295.0' Pi]IFS C-8, 20', 4HPF', 4.1/2" Bak~ TCP Guns, 90 Phase, 6~ 11~6.8 - I1307.5' BULLPLUC B~ker Description Summary to Convert Anna Producers into Injectors Anna 21 Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 25 · Gage Tbg. ~li.~t" Temp Survey. · Place on injectiOn for 1 month. Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 26 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 32 · Gage Tbg.. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 37 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 38 · Gage Tbg. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. ,,, I," / \ / // / / / , / -' .v, .'/ i/ / ,, / / · il / i : / ,, ! i / i i , i ; / ,, ? / / / ' / ~ / , ,," / / / ~ ,, / / I / . / i ,' / / / / / // i / / · i ,' / / ,. ~ / / ! / / / / / / / i / / / / . / / / MICROFILMED 10/12/00 DO NOT PLACE ANy NEW MA TERiAL UNDER THIS PAGE To: Mr. Jack Hartz -AOGCC, Fm: Dan Williamson Re: Hydraulic WO Unit Well Control Piping .... Ill II .. I]ll . 11 - On August 28, 1997, Unocal Alaska will mobilize Hydraulic Well Control's hydraulic workover unit to Baker Platform to perform a pump and tubing change on Baker Well 13. Upon completion of this work the unit will be sent to Anna Platform to perform the same task on Anna Wells..~5, 2_~6, and 38. These wells are all no flow wells, having no packer or safety valve m them.'~ Our data shows that the Anna wells are extremely subnormal pressured (1,840 psi at 8,200 ft TVD), have a high water cuts and produce very little gas. The Baker well is higher pressured but will be readily killed with filtered in]et water; it also has a high water cut and produces very little gas. The hydraulic unit will be on each well for a brief time. The wells are not considered by Unocal Alaska to be a high well control risk. We respectfully request the following variances be granted: 1, TO employ the use of 2", SM, Steel Molded Lines and Fittings with 1502 Weco Unions for service as a Kill Line and Downstream Choke Line. 2 To use the production Iow pressure separator system as opposed to the · use of a "Poor Boy Degasser". .. , ~.~, (~~t~~ ~~ !C°',~ept' ~CO' - ' I ]Phone. .... ~Ph~n~' ...... I . -. ~ :' '~ "~ ~ '; ~ Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510 October 18, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Attention' Mr. C.V. Chatterton File' MAG- 125-WF Gentlemen- Well Completion Report and Log GP 18742 No. 38 Platform Anna, Cook Inlet, Alaska Attached in duplicate is a completed form 10-407, Well Completion or Recompletion Report and Log, for well GP 18742 No. 38. Included with this report is a complete list of logs run to date, a list of perforated intervals, a daily well history, and a final gyro. Please contact Curtis King in our Anchorage office, 562-2147, extension 207 if you have any questions concerning this report. Yours very truly, M.A. Gol as MAG/CAK/eam Attachments RECEIVED OCT '2 'i. 1.988 Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~ '" 2. Name of Operator ¥~cJ~iF/~-l) -t' Permit Number Amoco Production Companyj.._ .~'~'~-~: / 88-34 3. Address APl Number P. 0. Box 100779, Anchorage, Alaska 9951'0'~1.~ 50-733-20398 . 4. Location of well at surface Leg 2, Slot-6, Platform Anna, 795" FNL x 9. Unit or Lease Name 604' FEL, Sec. 12, T10N', R12W, S.M. G.P. 18742 .. ~ ' - 10. Well Number -- At Top Producing Interval 95.75' TVD 1460 FSL x 1009' FWL, Sec 7, T10N, R11W, S.M. '- 38 . AtTotal Depth 10500' TVD 1445 FSL x' 798' FWL, Sec. 7, T10N, l~.Fieldand Pool ,. RllW. S.M. ' S. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Mi ddl e Kenai 105 KBI Granite Poi nt 1.8742 Granite Poi nt Field 12. Date Spudded 13. DateT.g. Reached 14. DateComp.,Susp.°rAband. 115' Water Depth, if°ffsh°re 116'N°'°fC°mpleti°ns 4/24/88 6/1.0/88 6/21/88 77 feet MSL 17. TOtal Depth' (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11453 x 10598 11400 x 10548 YES[~ NO[] N/A feetMD N/A 22. Type Electric or Other Logs Run' ' ' See attached list 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE !TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133 X52 0 6'20 26" 5'86 sx'"G" l~_ad 500 ~× "G" i-ail 13"3/8" 61 .K55 0 3'535 17-1/2" 1950 sx "G" lead 12.7 ppg .... 500 sx "G" Tail 15.g 9-5/8" 47 N80 0 10068 12-1/4" 250 SX ""G"' Lead 700 ;x "G" Tail 7,, - 35 S,95 9823 11453 8-1/2"- . 24. Perforations open to Production (MD+TVD Of Top and Bottom and 25. TUBING RECORD . _ interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" NR0 qR72' 9707' 2-7/8'" N80 10372' See attached 1 i st 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .N/A , , 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) 08/17/88 Hydraulic Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 08/17/88 2 TEST PERIOD I~ 53.6 28.3 7. -- 528 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 110 125 24-HOUR RATE ~ 643 340 84 41©API corr. 60© F 28. ~' CORE DATA Brief descriptio.~ of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,,, Submit in duplicate~~~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,, , Beluga 4728 4340 "A" Sand 7778 7035 "B" Sand 8375 7601 "C-1" Sand 9902 9086 "C-2" Sand 10127 9307 "C-3" Sand 10245 9423 "C-4" Sand 10268 9446 "C-5" Sand 10350 9526 "C-6" Sand 10576 9748 "C-7" Sand 10835 10002 "C-8" Sand 11098 10257 I 31. LIST OF ATTACHMENTS . List of Logs, Perforations, Daily Well History, Final Gyro Survey . .. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -~ ~ .0perations Center Signed ~ ~"' Title Supervisor Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water 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- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 MD TOP BOTTOM 10397 10483 10663 10918 11013 11224 11275 - 10459 - 10578 - 10675 - 10962 - 11031 - 11262 - 11295 MD INTERVAL 62' 95' 12' 44' 18' 38' 20' PERFORATION INTERVALS G.P. 18742 #38 TVD TOP BOTTOM 9572 9657 9834 10083 10175 10379 10428 9633 9750 9845 10159 10193 10416 10448 SIZE · 5" · 5!1 · 5!I · 5I1 · 5II · 5II · 5II NO., 248 38O 48 176 72 152 76 DAILY WELL HISTORY GP 18472 No. 38 DATE DESCRIPTION 04/24/88 SPUD - DRILL WITH MUD MOTOR 04/25/88 CIRC 20" CASING TO BOTTOM 04/26/88 CMT 20" CASING 04/27/88 TEST CSG TO 250 PSI, LEAK OFF TEST, DRILL WITH MUD MOTOR 04/28/88 DRILL WITH MOTOR 04/29/88 PU MOTOR - DRILL AHEAD 04/30/88 DRILL AHEAD 05/01/88 DRILL AHEAD 05/02/88 DRILL AHEAD 05/03/88 RUN 13-3/8" CASING 05/04/88 OPERATION SUSPENDED - TO #37 05/06/88 RU TO TEST BOPE 05/07/88 TEST BOP - 3000 PSI - OK, TST CSG 1575 PSI - OK, LEAK OFF TEST 05/08/88 DRILL AHEAD 05/09/88 DRILL AHEAD 05/10/88 DRILL AHEAD 05/11/88 DRILL AHEAD 05/12/88 DRILL AHEAD 05/13/88 DRILL, REAM, ELECTRICAL PROBLEMS 05/14/88 DRILL AHEAD 05/15/88 DRILL AHEAD 05/16/88 ATTEMPT TO MOTOR 05/17/88 TURN WELL WITH MOTOR 05/18/88 DRILL AHEAD 05/19/88 DRILL AHEAD 05/20/88 DRILL AHEAD 05/21/88 DRILL, CHANGE BHA 05/22/88 TURN WELL WITH MOTOR 05/23/88 DRILL AHEAD 05/24/88 DRILL AHEAD 05/25/88 DRILL AHEAD 05/26/88 DRILL AHEAD 05/27/88 DRILL AHEAD 05/28/88 TRIP OUT/IN, DRILL AHEAD 05/29/88 CIRCULATE, RUN LOGS 05/30/88 RUN 9-5/8" CASING 05/31/88 RUN AND CEMENT 9-5/8" CASING 06/01/88 WAIT ON CMT, TEST BOP, TRIP IN 06/02/88 TEST CASING TO 2500 PSI, DRILL CMT, RUN LEAK OFF TEST 06/03/88 DRILL AHEAD 06/04/88 DRILL AHEAD 06/05/88 DRILL AHEAD 06/06/88 DRILL AHEAD 06/07/88 DRILL AHEAD DEPTH 439' 610' 688' 1038' 1583' 2341' 2946' 3356' 3535' 3545' 4212' 4732' 5466' 5890' 6423' 6641' 7323' 7685' 7717' 7814' 8106' 8416' 8605' 8733' 8861' 9046' 9402' 9620' 9801' 9921' 10068' 10078' 10160' 10268' 1O583' 10786' 10889' DAILY WELL HISTORY GP 18742 No. 38 DATE DESCRIPTION 06/08/88 DRILL AHEAD 06/09/88 DRILL AHEAD 06/10/88 RUN 7" LINER 06/11/88 CMT 7" LINER, DRILL CMT 06/12/88 DRILL CMT, TEST CASING 06/13/88 CLEAN LINER WITH 7" CSG SCRAPER 06/14/88 LOGGING 06/15/88 LOGGING, PU 3-1/2" BUTT TBG 06/16/88 PU 3-1/2" BUTT TBG 06/17/88 RUN DUAL 3-1/2" BUTT TBG 06/18/88 NU 4-WAY VALVES AND LINES 06/19/88 PERF, MONITOR WELL DEPTH 11194' 11429' 11451' 11400' LIST OF LOGS G.P. 18742 NO. 38 LOG DESCRIPTION DIL/GR/CAL DENS ITY/NEUTRON/GR DIL/DEN/NEUT/GR DEN/GR COMP. NEUT/GR NEUT/POR/GR RES/GR RES/GR/CNO/SFD DEN/POR/GR FORMATION EVALUATION CBL DEPTH 3518 - 10048' 3518 - 10048' 3518 - 10048' 3518 - 10048' 9890 - 11373' 10078 - 11450' 10078 - 11450' 10078 - 11450' 10078 - 11450' 3535 - 11451' 9790 - 11368' 10003 - 11360' COMPANY Atlas Wirel ine Atlas Wirel ine Atlas Wireline Atlas Wirel ine Schlumberger NL (MWD) NL (MWD) NL (MWD) NL (MWD) Exl og Sch 1 umberger Schlumberger DATE 05/28/88 05/28/88 05/28/88 05/28/88 06/13/88 06/09/88 06/09/88 06/09/88 06/09/88 06/10/88 06/14/88 06/13/88 . SURVEY.REPORT 'AMOCO PRODUCTION COMPANY GRANITE POINT 18742 ..~ELL NO. GRANITE POINT · .KENAI' ALASKA JUNE '14 ,' '198'8. . 38 Gyrodata Incorporated P.O. Box79389 Houston, Texas 77224 713/461-3146 June 16, 1988 Mr. Kurt Unger Amoco Production Company 4300 B Street, Suite 400 Anchorage, Alaska 99510 RE: Granite Point 18742 Well No. 38 Granite Point Dear Mr. Unger: Enclosed please find One (1) original and six (6) copies of the com- pleted survey of Well No. 38. 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 W. Uttecht Vice President - Technical Services GWU:kau' Enclosures Gyrodata Services, Inc. Houston, TX/Lafayette, LA / New Orleans, LA/Ventura, CA/Aberdeen, U.K./Calgary, Alberta A Gyrodata Directional £or Survey AMOCO PRODUCTION COMPANY GRANITE POINT 18742 WELL NUMBER 38 GRANITE POINT KENAI, ALASKA Date Run: 14-$UN-88 11:45:0 Job Number: AKO688GI05 Surveyor: AL ~UDRLE Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 58min 37sec N Bearings are Relative to TRUE NORTH Proposed Yell Direction: S 32deg Omin Osec E Vertical Section Calculated {rom Well Head Locmtion Closure Calculated from Well Head Location Horizontal Coordinates Calculated {rom Local ~orizonta! Reference ~MOCO PRODUCTION COMPANY ~RANITE POINT 18742 WELL NUMBER 38 iRANITE POINT KENAI, ALASKA ~ob Number: AK06886105 A Gyrodata Directional Survey Page 1 MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 N 00E 100.0 200.0 300.0 400,0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700,0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2S00.0 2600.0 2700.0 2800.0 2900.0 0 10 S 7 26%; 0 8 N 85 34 %/ 1 43 N 52 33 W 0 58 N 84 49 %/ I 56 S 62 7 %1 3 45 S 55 27 %1 5 39 $ 48 50 %1 6 14 S 38 48 %1 6 31 S 26 OW 6 22 S 5 24 W 8 I S 21 21 E 11 39 S 27 59 E 11 21 S 36 21 E 12 39 S 44 29 E 15 55 $ 45 25 E 19 5 S 44 52 E 21 7 S 43 27 E 21 38 S 43 8 E 22 19 $ 43 4 E 22 47 S 42 39 E 23 25 S 42 53 E 23 52 S 43 38 E 24 17 S 43 1 E 24 42 S 42 41 E 25 21 S 42 35 E 26 1 $ 42 30 E 26 55 S 42 21 E 27 12 5 42 31 E 27 8 S 42 6 E DOG-LEG VERT VERT C L 0 S U R E SEVERITY DEPTH SECTION DISTANCE BEARING' de91100' ft ft ft deg min .00 .0 .0 .0 N 0 0 E MD REF TO PLAT ANNA RKB ELEV 105 FT MSL MULTISBOT SURVEY RUN IN 9 5/8" C$G AND 7" LINER .16 I00.0 .1 .20 200.0 .1 1.61 300.0 -1.1 1.04 ,400.0 -3.0 1.24 499.9 -3.9 1.84 599.8 -3.9 1.98 699.5 -3.1 1.19 798.9 -.6 1.45 898.3 4.2 2.30 997.7 11,7 3,69 1096.9 23,0 3.80 1195.4 40.0 1.69 1293.4 59.9 2.13 1391.2 80.4 3.29 1488.1 104.5 3.17 1583.5 133.8 2.09 1677.4 167.4 ,53 1770.5 203.1 .67 1863.2 239.8 · 49 1955.6 277.5 .65 2047.5 316.0 .54 2139,2 355.4 · 48 2230.4 395.4 .43 2321.5 436.1 ,67 2412.1 477.6 · 65 2502.2 520.3 .92 2591.7 564.1 · 29 2680.8 608.8 .20 2769.7 653.8 HORIZONTAL COORDINATES feet .Oo. .oo -) .1 S 7 26 %1 .14 S .02 %1 .3 ,5 34 46 W ,28 S .20 %1 1,7 N 80 23 W .29 N 1.69 %1 4.0 N 73 38 %1 1.13 N 3.85 %1 6.3 N 84 13 W 10.7 $.79 38 %1 18.4 S 67 46 %1 28.1 S 59 11%1 38.3 S 51 42 %1 47.8 S 43 49 %1 56.3 5 33 51%1 66.9 5 21 17 W 80.3 S 9 48 %1 95,0 S 0 7 W 113.7 S 8 42 E 139.1 S 16 5 E 170,2 S 21 32 E 204,5 S 25 20 E 2,.30.4 S 28 3 E 277.6 S 30 4 E 316.0 S 31 38 E 355.4 S 32 56 E 395.6 S 34 0 E 436.6 S 34 50 E 478.6 S 35 32 E 521.6 S 36 7 E 565.9 5 36 36 E 611.2 5 37 2 E 656.7 5 37 24 E .64 N 6.30 1.93 $ 10.53 6,95 5 17.00 14.41 5 24.15 23.77 S 30,09 34.51 5 33.11 46.79 5 31.39 62.31S 24.27 79.17 S 13.66 94.98 S .20 112.43 5 17.22 133.64 S 38.54 158.30 S 62.49 184.84 $ 87.49 212.16 S 113.05 240.26 5 139.13 269.06 S 165,76 298.27 S 193.25 327.95 S 221.24 358.34 $ 249.43 389.46 S 278.08 E 421.40 S 307.39 E 454.30 5 337,46 E 487,88 $ 368.15 E 521.65 S 398.89 E MOCO PRODUCTION COMPANY RANITE POINT 18742 WELL NUMBER 38 RANITE POINT KENAI, ALASKA ob Number: AKO688G105 A Gyrodata Directional Survey Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ~t deg min deg min de9/lO0' 3000.0 27 19 S 42 18 E 3100.0 26 51 $ 42 36 E 3200.0 27 2 S 42 49 E 3300.0 26 36 S 42 22 E 3400.0 26 27 3500.0 26 0 $ 41 24 E 3600.0 26 4 S 41 32 E 3700.0 27 18 S 40 57 E 3800.0 28 45 S 40 31E 3900.0 30 7 S 40 20 E 4000.0 31 50 S 39 18 E 4100.0 33 21 $ 38 51 E 4200.0 34 29 $ 37 57 E 4300.0 35 50 S 36 25 E 4400.0 36 41 S 35 57 E 4500.0 36 33 S 35 30 E 4600.0 35 58 S 34 26 E 4700.0 35 29 S 34 27 E 4800.0 34 43 S 34 8 E 4900.0 35 3 S 34 21 E 5000.0 34 30 S 34 17 E 5100.0 34 7 S 34 31 E 5200.0 33 2 $ 33 43 E 5300.0 31 37 S 33 47 E 5400.0 29 42 $ 33 23 E 5500.0 29 16 S 33 15 E 5600.0 28 56 $ 32 34 E 5700.0 28 44 $ 31 35 E 5800.0 28 54 S 31 15 E 5900,0 28 58 $ 31 26 E VERT VERT DEPTH SECTION £t ft .20 2858.6 698.8 .48 2947.7 743.5 .20 3036.8 788.1 .48 3126.1 832.4 · 22 3215.6 876.4 .52 3305.3 919.9 .09 3395,1 963.2 1.27 3484.5 1007.5 1.46 3572.7 1054.0 1.37 3659.8 1102,6 1.80 3745.6 1153.5 1.53 3829.8 1207.0 1.24 3912.8 1262.4 1.63 3994.6 1319.8 · 89 4075.2 1378.8 · 31 4155.5 1438.3 · 86 4236.1 1497.4 · 48 4317.3 1555.7 .78 4399.1 1613.1 .36 4481.1 1670.3 .55 4563.3 1727.3 .42 4645.9 1783.6 1.16 4729.2 1838.9 1.41 4813.7 1892.3 1.94 4899.7 1943.3 · 43 4986.7 1992.5 · 48 5074.1 2041.1 .51 5161.7 2089.4 · 23 5249.3 2137.6 .il 5336.8 2185.9 CLOSURE DISTANCE BEARING ft deg min 702.3 S 37 43 E 747.6 S 38 0 E 792.8 $ 38 16 E 837.8 S 38 30 E 882,4 S 38 41E 926.5 $ 38 50 E 970,3 $ 38 57 E 1015.2 $ 39 3 E 1062.2 S 39 8 E 1111.3 S 39 I1 E 1162.8 S 39 I3 E 1216.6 S 39 12 E 1272.4 $ 39 10 E 1329.9 S 39 5 E 1389.0 $ 38 58 E 1448.6 S 38 50 E 1507.6 S 38 41 E 1565.8 S 38 31 E 1623.2 S 38 22 E 1680.2 S 38 14 E 1737.1 S 38 '6 E 1793.4 S 37 59 E 1848.6 $ 37 52 E 1901.9 S 37 45 E '1952.8 S 37 39 E 2001.8 S 37 32 E 2050.3 S 37 26 E 2098.3 S 37 18 E 2146,3 $ 37 10 E 2194.4 S 37 3 E HORIZONTAL COORDINATES £eet 555.53 589.12 622.42 655.63 688.71 721.70 754.59 788.35 823.95 861.36 900.89 942.71 986.42 1032.30 1080.04 1128,46 1176.93 1225.08 1272.59 1319.88 1366.99 1413.50 1459.28 1503.75 1546.22 1587.35 1628.18 1669.05 1710.19 1751.50 460.34 491.07 521.59 551.58 580.97 610.03 639.63 670,29 702,16 735.11 769.06 803.71 838.51 873,43 908.26 942.1q 975.16 1007.56 1039.74 1071.90 1103.75 1134.76 1164.47 1192.68 1219.71 1246.13 1271.74 1296.86 1322.03 ~MOCO PRODUCTION COMPANY iRANITE POINT 18742 WELL NUMBER 38 iRANITE POINT KENAI, ALASKA 'ob Number: AKO688G105 A Gyrodata Directional Survey Page 3 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY £t deg min deg min deg/lO0' 6000.0 29 30 S 30 56 E 6100.0 29 29 $ 30 51 E 6200.0 28 56 S 29 50 E 6300.0 28 54 S 29 52 f 6400.0 29 4 S 29 11 E 6500.0 28 54 S 28 43 E 6600.0 27 56 $ 27 20 E 6700.0 27 6 S 27 29 E 6800.0 26 23 S 27 32 E 6900.0 25 34 S 26 47 E 7000.0 25 2 S 26 7 E 7100.0 23 33 S 24 54 E 7200.0 22 24 S 24 33 E 7300.0 21 9 S 22 16 E 7400.0 20 32 S 20 18 E 7500.0 19 16 S 16 19 E 7600.0 18 17 S 12 32'E 7700.0 17 40 S 11 55 E 7800.0 18 15 S 25 36 E 7900.0 19 5 S 26 51 E 8000.0 19 12 $ 24 34 E 8100.0 18 52 S 22 22 E 8200.0 18 14 $ 19 46 E 8300.0 17 57 S 16 47 E 8400.0 17 14 S 14 28 E 8500.0 16 12 S 6 19 E 8600.0 15 35 S 1 14 W 8700.0 14 58 S 9 40 W 8800.0 15 15 S 15 28 W 8900.0 13 54 S 2 55 E VERT VERT DEPTH SECTION ft ft .59 5424.1 2234.8 .05 5511.2 2284.0 .75 5598.5 2332.7 · 04 5686,0 2381,0 · 38 5773.5 2429.4 ,28 5860,9 2477.8 1,17 5948.9 2525.3 · 84 6037.6 2571.4 · 71 6126.9 2616.2 · 89 6216.8 2659.9 · 59 6307,2 2702,4 1,57 6398,3 2743,3 1.16 6490,4 2782.0 1,51 6583,3 2818,7 · 93 6676.7 2853,7 1.85 6770.7 2886.7 1.57 6865.4 2917.4 .64 6960.5 2946.4 4.25 7055.6 2976.4 .91 7150.4 3008.2 · 76 7244,9 3040.8 ,79 7339.4 3073.1 1.04 7434.2 3104,3 · 97 7529,2 3134.5 1.00 7624.6 3163.5 2.56 7720.3 3190.2 2.15 7816.5 3214.0 2.31 7913.0 3234.9 1.54 8009.5 3253.5 4.80 8106.3 3273.2 CLOSURE DISTANCE BEARING £t deg min 2243.0 S 36 55 E 2292.0 S 36 47 E 2340,4. $ 36 39 E 2388,5 $ 36 31 E 2436,6 $ 36 23 E 2484.6 S 36 14 E 2531.7 $ 36 5 E 2577.4 $ 35 56 E 2621.9 S 35 47 E 2665.2 $ 35 38 E 2707.4 S 35 30 E 2748,0 S 35 21E 2786.3 $ 35 12 E 2822,7 S 35 3 E 2857,3 $ 34 53 E 2889.9 S 34 41 E 2920,1 $ 34 28 E 2948,7 $ 34 14 E 2978,4 S 34 5 E 3010.1 S 34 0 E 3042.5 S 33 54 E 3074.6 $ 33 48 E 3105.6 $ 33 40 E 3135,6 5 33 31 E 3164.4 S 33 21 E 3190.9 S 33 9 E 3214.4 S 32 54 E 3235.1 S 32 37 E 3253.5 S 32 17 f 3273,2 S 32 ! E HORIZONTAL COORDINATES feet 1793.28 S 1347 31 1835,51 S 1372~59 1877.62 5 1397.23 1919.55 S 1421.29 1961'71 $ 1445.17 2004.11S 1468.62 E 2046.12 $ 1490.98 E 2087.13 5 1512.25 E 2127.04 S 1533,03 E 2166.00 $ 1553,03 E 2204.26 S 1572.06 E 2241.40 $ 1589.78 E 2276.86 S 1606.11 E 2310.91 $ 1620.86 f 2344.07 $ 1633.77 E 2376.39 S 1644.47 2407,56 5 1652.48 2437,72 $ 1659.02 2466.85 $ 1668.91 2495.56 S 1683.05 2525,10 5 1697.27 E 2555.02 S 1710.26 E 2584,71 $ 1721,70 E 2614.20 S 1731.44 E 2643.32 $ 1739,58 E 2671.58 $ 1744.76 2698.92 $ 1745.97 2725.12 $ 1743.48 2750.55 $ 1737,81 2775,45 5 1735,07 MOCO PRODUCTION COMPANY RANITE POINT 18742 WELL NUMBER 38 RANITE POINT KENAI, ALASKA ~b Number: AKO688G105 A Gyrodata Directional Survey Page 4 MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 9000.0' 13 32 S 6 54 E 9100.0 12 54 $ 031 E 9200.0 12 51 S 2 43 W 9300.0 12 37 S 7 41 W 9400.0 12 4 S 13 47 W 9500.0 11 48 S 21 0 W 9600.0 11 26 S 27 10 W 9700.0 10 47 $ 29 46 W 9800.0 10 37 S 33 46 W 9900.0 10 10 S 40 56 W 10000.0 10 43 S 45 48 ~ 10100.0 10 55 S 51 33 W 10200.0 10 40 S 57 59 W 10300.0 I0 42 S 64 12 W 10400.0 10 41 S 70 41W 10500.0 10 33 S 72 40 W 10600.0 10 56 S 76 47 W 10700.0 11 37 S 81 47 W 10800.0 12 34 S 86 12 W 10900.0 13 18 S 88 58 W 11000.0 13 37 S 89 51 W 11100.0 14 48 N 87 30 W 11200.0 14 59 N 86 43 W 11300.0 15 17 N 85 3 W 11350.0 15 31 N 82 59 W 11451.0 15 31 N 82 50 W DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' £t ft 1.01 8203.5 3294.3 1.59 8300.8 3314.4 .72 8398.3 3333.1 1.12 8495.8 3350.6 1.41 8593.5 3366.3 1.52 8691.4 3379.7 1.29 8789.3 3391.0 .82 8887.4 3400.5 · 76 8985.7 3408.7 1.37 9084.1 3415.0 1.04 9182.4 3419.6 1.10 9280.6 3422.6 1.23 9378.9 3423.7 1.15 9477.1 3422.7 1.20 9575.4 3419.7 .39 9673.7 3415.3 .86 9771.9 3409.9 1.19 9870.0 3402.8 1.33 9967.8 3393.7 · 96 10065.2 3382.6 · 39 10162.5 3370.5 1.35 10259.4 3357.1 · 26 10356.1 3342.4 · 53 10452.6 3327.0 1.20 10500.8-' 3318.8 .O4 LAST STATION PROJECTED 10598.1 3301.8 CLOSURE DISTANCE BEARING ft de9 min 3294.3 S 31 49 E 3314.5 S 31 38 E 3333.2 S 3i 26 E 3350.9 S 31 12 E 3366.8 S 30 58 E 3380.6 S 30 42 E 3392.3 S 30 25 E 3402.3 $ 30 9 E 3411.0 S 29 52 E 3418.0 S 29 36 E 3423.4 S 29 18 E 3427.4 S 29 0 E 3429.4 S 28 41 E 3429.6 $ 28 23 E 3427.7 S 28 4 E 3424.7 S 27 46 E 3420.7 S 27 27 E 3415.1 S 27 9 E 3407.6 S 26 49 E 3398.4 S 26 28 E 3388.3 S 26 7 E 3377.1 $ 25 45 g 3364.9 S 25 22 E 3352.1 S 24 59 E 3345.3 5 24 47 E 3331.1 5 24 23 E HORIZONTAL COORDINATES feet 2799.07 S 1737.10 2821.88 $ 1738.57 2844.16 S 1738,14 E 2866,10 S 1736.15 E 2887.09 $ 1732.17 E 2906.81 S 1725.99 E 2925.18 S 1717,78 E 2942.11 S 1708.60 E 2957.89 S 1698.82 E 2972,21 S 1687.89 Z 2985.38 $ 1675.45 E 2997.77 S 1661.37 E 3008.56 S 1646.08 E 3017,52 S 1629.87 E 3024.64 S 1612.74 E 3030.43 S 1595.25 3035.34 S 1577.27 3038.97 S 1558.07 3041.16 S 1537.26 3042.10 S 1514.90 3042.35 S 1491.63 E 3041.84 S 1467.08 E 3040.55 S 1441.40 E 3038.67 S i415.37 E 3037.29 5 1402.17 E 3033.95 S 1375.34 E Final Station Closure: 3331.1 feet South 24 de9 23 min 8 sec East ION '! iST~ ~2: } I N.t-I '~ ~,ENF! I ;-:- ION -7: 'ii t t' ' 42 ~ NUP1BER ~IIB I .. '. !. I ............. l .... EENR I ," ~ !: . _;_~ .. _L__ i ......... ' "i · . I~ ' . _Li~.! :5_i.i - "'i 'i.~ ...... L.i. ' .I ''1 :-' ' 7-i .I .... '-'~ ........ 1 : . I . . : i I - , ' : . ..' i .... :,.. ~ 1 i ' ''i t - , . !ii .. , ~ ..... ................ r±ldol Sec±ilon{f~] i ,"'- DirecTIon: 5 .32 13 '13 E : : -~' 'i~- ...... -rT'~'~'- '-~n~T-l~!~' ":'I'~''i '~ ~'~'t'I , ~l,i,~ ,l~i~r- ' ~'-~-'.~-'--~~--,--.~? --' ~"~'~di. ,,, J~-~''' '-~?-~ ,,,, ,''' '~'' ',~ ~,,,.,, ~,~.. ,. ", ' ~ nT~-w ~-~~'', ,, ' ~!~T ~~ ~%P ~ ~ -~-~-T:~- ....... '' . .... . i ,, , i i ':::.;.:"i-:'z:-:-~_JGRRN[1E POINT ]8742"iNELE.NUHBER. 38.. :~:;-z~i;;:-::;.l:z:;::zj-z.L-;.;:.j;;rJt::-LJ~7:z~:L~_~;j.-~4;.:;-;~;;12L.L :~;.;:::7_.j-:-Tt-zJ-~.~(:.-~-:i;_;~~ .~ . ~ -~ ... i-- I ~RRNI~E--POIN7 ..... KENRI;-tRLRSKR'~ --'~ [--~--~-~~=~ : ---~~ .... ~-~v~~ .................. : ........ ............................ = ....................... ; ......... t ........ '- ........... ~ .... =-~ ~- :-. - m-~- t ........ : ...... t ............ ~ - -~ ...... : - ....... ~ ...... ~ ............. ~~t~ ........ , ........... i '. ..... I ........... :-- .2 ........ : . .: ..... I .... J . . '...' . . 7.7_i 7'LiZLZiZiZ;!TL-Z ....... l : ..................... ~ZZ';ZT~.:iT.-.ZZ7~ .......... .............. Z~ L'ZZZ Z'Z: Z L. T__-_'.-_'ZZ'L , , ' ZZ'Z_-ZE ............. ~ ...................... Z ~A.Z.;Z;Z 7.7 t ............... -::':-:-'!'-!-:FIHOCO. PRODUET ION CO~PFINT , , , ~ , : , , , -~:.--:- 1 ~z'.~ ERRN [IE :~PO l NT __ .187.42;"! NELL :.NUMBER_ 138 TT'T-T- / ; . ..--J - - : '1 '' ' ......... · :: :"-!' -: · i: '::-'-'.:i:: :':'i': ::::-:-:x:'-'-':].-':-i::~:~:-'-'~:~- :--i::::: I .~ ' ""-" '"~ ' · i ' -~, ....... i ............ ; ~ -: - . i' '-:]':.~':"i ........ i -:-': ..... :'_..' .~ ]]..!] ] ] '.-.]!__] ~, ......... , ....... -. iii .']''' ~ ] ]-"']']?T]]]T'~ .... ; ' ]"]' . '-' ].' ]-'; ........... .! ]- ']"-./" '. ...... ......................... ]T'-]-_-?T--~-'T']-~TT-_]']-'~¥- ]-]-: ......... ;-.'"7' I---¥]-T--"T."-'--; .... . .... ]' '] ..... I .J TO: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: C. V. Chatterton DATE: June 22, 1988 TRANS#: 886004-AK RE: MWD Formation Evaluation Logs For Well GP-38 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning .a copy of this transmittal letter to NL -'MWD, Anchorage Alaska to the attention of Mr. E. A. Opstad.~ .Measured Depth 2" & 5,, Presentations le 1 EWR/GR/CN~/sFD' 1 EWR/GR / 1 CNO/SFD/GR ' 2. 1 Folded Sepia (each) Digital D.ta 2. 1 LIS Varification Listing Received By: NL MWD/NL Industries, Inc. 8537 Corbin Drive, Anchorage, Alaska 99507 Tel. (907) 522-3254 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: QUANT I TY DESCR I PT I ON DA TED: Copy sent to sender YES RETAIN THIS SECTION FOR YOUR RECORDS RE GP 18742 NO. 38 (OPEN HOLE) I:J I FL 2&5I' ~ 1 PRINTS 0 NEG. DIFL/CN/CD 2" '~- 1 PRINTS 0NEG. 6N/CD 2&5" '~ 1 PRINTS ,ONEG. CD LOG 5" 1 PRINTS ONEG. PRINTS NEG. 1 SEPIA 1 SEPIA 1 SEPIA 1 SEPIA SEPIA SEPIA SEPIA SEPIA ~'lasl~l~ill~, ~s Coi~s. Commission Anchorage DATE MEMO RANDUM , State Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith /~¢~'~-~"3 DATE: ? May 13, 1988 Commissioner mbENO: D.HRH.37 THRU: Michael T Minder '/~¢¢'~-'¢'~' Sr Petroleum Engineer TELEPHONE NO: SUBJECl BOP Test AMOCO Gr Pt St ~38 Permit No. 88-34 Granite Pt Field FROM: Harold R Hawkins Petroleum .~hursday, May 5, 1988: I left Anchorage at 3:15 p.m. by EP~A to Kenai ~o witness' a-BOP test on Platform Anna, Middle Kenai, Granite Point Field. I arrived on the platform at 5:00 p.m. Friday, May 6, 1988: I witnessed the BOP test on well #38. There were- ~-o--~ai lure's; " I filled out an AOGCC report which is attached. In summary, the BOP test on Platform Anna well #38 was performed by the Parker crew satisfactorily. Attachment , 02-00IA(Rev. 8/85) O&G #4 5/$4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well Operator /½ /~ ~,£'C~ !~/."{g~i~ij~%~/~h 3 Location: Sec / ~ T/~'/~';R Dri!lin~ Contraator/~/~]zj/~? Ri~ Location, General ~ ff Well Sign~,~/~ ACCUMULATOR SYSTEM General Housekeeping ~ [i~ Rig Reserve Pit ~/~ P!ud Systems Trip Tank Pit Gauge' Flow Monitor Gas Detectors Visual Audio ROPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Representative,/~VL5~/~/9/~;~/? iS?Ca g 3. b't ,, ~ h°A£p Full Charge Pressure Pressure After Closure .__ psig/~z3 Pump incr. clos. pres. 200 psig / mind,sec. Full Charge Pressure Attained: // min/9 sec. Controls: Master, Remote ~/% Blinds switch cover~/~ Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves /~ No. flanges ~ ~ Adjustable Chokes Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure.~ Hydrauicatly operated choke 6,~/[~ ~$00 Test Results: Failures Repair or Replacement of failed equipment to be made within'---'--- days and Inspector/ Cor~m~ssion office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspectcr;' ~ ~ '/ April 18, 1988 Mr. M. A. Golas District Operations Supervisor Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510-0779 Telecopy: (907) 276-7542 Re: Granite Point State 18742 No. 38 Amoco PrOduction Company Permit No. 88-34 Sur. Loc. 795'FNL, 604'FEL, Sec. 12, T10N, R12W, SM. Btnkhole Loc. 1200'F~L, 1600'FSL, Sec. 7, T10N, RllW, SM. Dear Mr. Golas: EncloSed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. 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. ~,~ere 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. ~r3~.~ tru~yfy~ r~ ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF %"dE COFR~ISStON dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Amoco Production Company P. 0. Box 100779 Anchorage, Alaska 99510 April 8, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Attention: Mr. C. V. Chatterton File: MAG-O56-WF Gentlemen: Application for Permit to Drill Grnaite Point 18742 Well No. 38 Platform Anna, Cook Inlet, Alaska Attached in tripicate is a completed State of Alaska Form 10-401, Application for Permit to Drill for Granite Point 18742 Well No. 38. We propose to directionally drill this well from Platform Anna, utilizing Leg 2, Slot 6 to a target location at the top of the Middle Kenai Sand C-5 zone, -9470 feet subsea, 1600 feet FSL, 1200 feet FWL, Section 7, TION, R11W, Seward Meridian. This well is to be completed as a producing well to recover reserves from the east flank of the Granite Point field. Also attached is our Company draft No. 364503 dated April 8, 1988 for $100.00 to cover the filing fee. The proposed directional program, surface plat, drilling program, drilling time curve, and drilling fluid program along with sketches of the BOP equipment and diverter system are also attached. Amoco requests an exception to Regulation 20 AAC 25.050 for only the 8-1/2" hole section (9900-11600'). Due to previous problems surveying the 8-1/2" hole section, we do not wish to run directional surveys in this interval. This will minimize the exposure to stuck pipe/fishing operations. With the wellpath as currently ~lanned, we anticipate a maXimum deviation in the 8-1/2" hole of 9-10 . A continuous gyro survey will be run at lO0-foot intervals from total depth to surface when drilling operations are concluded. RECEIVED Alaska Oil & Gas Conservation Commission April 8, 1988 Page 2 This is the first well to be drilled in the southwest quarter of Section 7. There are no affected operators. Drilling operations are scheduled to commence on April 18, 1988. Please contact Kurt Unger in our Anchorage office, 562-2147, extension 211 if you have any questions concerning this application. Very truly yours, M. A. Golas District Operations Supervisor Attachments KWU/s 1 s '~-'~ STATE OF ALASKA ' ALASKA O~. AND GAS CONSERVATION COn ISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Amoco Production Company 105 feet Middle Kenai 3. Address 6. Property Designation Granite Point Field P.0.Box 100779, Anchorage, Alaska 99510 ADL 18742 4. Location of well at surface Leg 2, Slot 6 7. Unit or property Name 11. Type Bond(see 20AAC25.025) Platform Anna, 795'FNL, 604'FEL, Sec. 12 GP 18742 Blanket T10N, R12W, S.M. ' At lop of productive interval C5 Top 9575TVD- 8. Well nu,mber Number 1200FWL x 1600FSL Sec. 7,T10N,R11W, S.Mo 38 Surety - 599481 At total depth 10894TVD - 1200FWL x. 1600FSL, 9. Approximate spud date Amount Sec.7, T10N, R11W, S.M. April 18, 1988 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line C5 Top-CPI8742 #1~ 1600 feet 1500 feet 5060 11600 'MD 10894'TVPeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle 33 0 Maximum surface 2552 ps,g At total depth (TVD) 5891 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD '-'-AC (include stage data) 26 20 133 ~-52t~§-~ 600 0 0 600 599 To surface 17-1/2 13-3/8 61/68 <55 BTC 3500 0 0 3500 3323 To surface 12-1/4 9-5/8 47/53.5 N80 BTC 9900 0 0 9900 9215 500 sx 8-1/2 7 35 ~95 BTC 1950 9650 8969 11600 10894 To cover entire length 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 Intermediate Production Perforation depth: measured Alaska Oi~ & Gas true vertical * .... ~---',,-,-,*'.'~ 20. Attachments Filing fee [] Property plat [] BOP Sketch)E~ Diverter Sketch,El Drilling program [] Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21.1 hereby,~.l..certify that the~oreg/~oi~///ng is true and: correct to the best of my knowledgee Signed ~/'~, ~,.~~ mitleDistrict Operations Supervisor Dat Commission Use Only Permit Number I API number I Appr(~a~t~ I See cover letter ~--~/¢ 50--7'..,~ - ~ ~ 88 for other requirements Conditions of approval Samples required ~Yes [] No Mud Icg required ~ Yes [] No Hydrogen sulfide measures [] Yes J~..No Di.rectional survey required ~ Yes [] No Required working,,cf~sure ~r Bj;~pI,~'} Ej;;],~t4; .~' 3¢vl; [] 5M; [] 10M; [] 15M Other: ~ 2~-~// /~~/,~' ' ' by order of Appr°vedbyk S, /, ~ '' ~"'~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 iplicate GRANITE POINT 18742 NO. 38 GENERAL DRILLING PROGRAM 1. Nipple up 30" riser. Clean out 30" piling. 2. Drill 17-1/2" hole to 600'. Open hole to 26". 3. Run and cement 20" conductor casing to surface. 4. Nipple up 20" riser and 10" diverter system. Function test all components. Perform formation leak-off test below 20" casing. 5. Drill 17-1/2" hole to approximately 3500'. 6. Run and cement 13-3/8" surface casing to surface. 7. Nipple down diverter system. Nipple up BOP's and test to 3,000 psi. Perform formation leak-off test below 13-3/8" casing. 8. Drill 12-1/4" hole to approximately 9900' to top set the C2 zone. 9. Run open hole logs. 10. Run 9-5/8" casing and cement with 500 sx. 11. Drill out 9-5/8" casing. Perform formation leak-off test. Drill 8-1/2" hole to total depth (approximately 11600'). An MWD resistivity and porosity log will be run to replace wireline logs. 12. Run 7" liner 9650-11600' and cement over entire length. 13. Perforate zones of interest. 14. Run hydraulic BHA and dual strings of 3-1/2" tubing. 15. Set back-pressure valves, nipple down BOP's, nipple up tree. Test tree to 5,000 psi. Pull back-pressure valves. 16. Place well on production. NOTE: Ae Mud loggers will be used from 4000' - TD. Casing design factors of 1.125, 1.0, and 1.8 will be used for collapse, burst and tensile strengths respectively. GRANITE POINT 18742 NO. 38 Mud Proqram Interval' SFC - 3,500 Feet (26" x 17-1/2" Hole Sections). Mud Type' EPA Mud Type No. 5 - Spud Mud. Mud Description- Prehydrated Gel - Seawater We i q h t P_~V Y__~P F~L 9.0 10 10-20 NC Interval- 3,500 - TD (12-1/4" and 8-1/2" Hole Sections) Mud Type' EPA Mud Type No. 2 - Lignosulforate Mud. Mud Description' Dual Polymer - Freshwater Weight P_~V Y__~P HTHP FL 9.0* 10 10-15 15 *Mud weight will be increased as required to control formation pressures. GRANITE POINT 18742 NO. 37 ANTICIPATED FORMATION PRESSURES ANTICIPATED PRESSURES BASIS' GP 18742 No. 36- 12 ppg EMW was required in C4 section while drilling - 9842' MD (9441' TVD). High pressure waterfl ood water. Calculated Maximum Formation Pressure- 9441 x .052 x 12 ppg = 5891 psi e e Maximum Surface Pressure' If 20% of the wellbore is evacuated with 8.5 ppg sea water in the well, the maximum surface pressure is' Psmax : 5891 - (9441-(.20 x 9441)) x .052 x 8.5 Psmax : 2552 psi Maximum Anticipated Mud Weight' The maximum anticipated mud weight is 12.0 ppg. VERT!CAL ~ ~-I !49 RELS S~C~,ON AT DEG - w W o? 10 2000- 5000-~ ................... ~°°°1 ....................................... i . · ' ! ' 5000 .................................................. ; ......................................................... : · 6000 ' ' ' 7OOO 8000 9000 10000 11oooi 0 ................................................ v~ ~E ~-'-~5 '~' '~' -:.:a-t~ .......... .................................................................. : ......... w -~- ~G{I~- ~:" ....... ; ........ . _., ~ aa= . 500 1000 15()0 2000 2500 3000 SECTION (FEET) 3500 PLAN VIEW OF PROPOSED GP 18742 N0.38 ,, . -1000-- ................................................ i ..... -2000 -' ..... :.~ ..... · -3000 ' ' -100 9()0 1900 (FEET) 3 3 6 6 5 5 6 215~ 219 6 217 muc I ~14 13 .8 2.29 10 9 ~o ANNA: ~P 23'7 CBRPORA'TE 'IIMESI~f~RI~C CERTER CM~ ~:P4.2 [19/11/87 Pfii;E F!LE~AtIE: gP-]Oy TRADXTIDXi)L UHiTS 1988-04-88 13:30 .UERTICAL ~ECTIDN DR CLD~URE I)IRECTIO),( IS' 149.00 I)E~REES MEA.R. ~URUEY I) EPT)-} t~CL. [~IR. )eLI. O,,Ll i. 50 ~45. 400. O0 4. O0 700. O0 i. O0 800.00 8.00 ~20. ?.O0. O0 ~.00 ~ 5. OOE I[~88. DO ~,.OO ~3O. OOE I!00. O0 6.00 F~3. OOE i200. O0 7.50 S52.8BE 1~80. O0 ~,OO S52.50E 1~00.00 10.50 ~52.20E 1500.00 12.00 SSi. l~O0. O0 13.50 SSI. IOE 1700.00 15.00 1800.00 18.00 SSi. OOE l~OO. OO 17.08 ~50.70E 2008.00 18.00 SSO. 4OE 2100.00 1~.80 ~50.10E 2200.~D 20.00 S4~.80E 2]80.88 21.00 S4~.SOE 2400. e~ 22,00 ~49.28E 2500.~21 23.00 S48.90E 2600.00 24.8B 2?t[tLO8 ~7.08 ~47.7DE 30DO, OD 28.00 ~47.40E MO0. OO 2~.08 3200,00 30.00 ~. 3308.00 3i. OO SqO. SOE .3480.00 32.08 S~6.2OE 3500.00 3].00 S~5. gOE 3800. L!0 32.58 ~45.68E 3700.00 ~,~2.00 ~-4a. 3800.00 31.50 S45.00E 4~00.0() )0.50 5:44.40E 4100.00 30.00 ~44. fOE 4200.00 29.50 S43.80E q)OO. O0 2f. O0 ~q3.50E ~400.00 28.~0 ~3. OOE 4590.00 2~.00 ~42.50E DEPTH ;~[;RTH EAST UERT. (IUD) -SUL{TH -}~EST SECI I UN 25(). O0 O. O0 O. O0 O. O0 2YY. 9~ -O. 44 -8.46 O. 16 399.87 -). 86 -3.84 i. 32 qYT. q9 -I0.02 -t0.02 3, q3 ~8, ~A -17. A1 -tF. 4I ~. ~ 797.8~ -3~. 55 -30.37 13.1I 897.2? -43.83 -M.73 2I. 23 ~6.7~ -~3.72 --28,~1 31. )1 10F6.20 -6I. 4Y -21.73 ql. 52 1195.50 -68.58 -12.35 52.43 I294.46 -77.2~ -O. 95 65.76 139~. 02 -87.63 12, 46 8I. 53 149i. 09 -99.63 27.84 99.74 1588.62 -113.2} 45.18 120. ]8 I781.91 -145.40 85.24 168.5) 1877.79 -163.33 107.26 195.24 1~73.1~ -~82.43 13L1. ~8 223. ~8 2067.99 -202.72 154.88 25~. 54 2i~2.25 -224.20 180.43 285.1I 2255.92 -246.88 207.12 318.29 2348.96 -270.75 234.92 35]. 07 2{{i. 3~ -295.83 243.8) 389. ~4 2533.85 -]22.12 2~3.8I ~27. ~3 2624.04 -349.63 324.84 446.9~ 2714.30 -378.35 35~.91 508.13 2883.7~ -q08. 30 38~.99 558.83 2~80.37 -~7I. 85 ~5}.0} ~q8. gO 30~7.4i -585.46 495.08 688.25 3153.57 -540.30 531.98 737.12 32 38.83 -576.37 589.79 787.51 )32~.i7 -613.66 888. q7 839, 39 3q07.27 -~I. ql 6~7.22 8~I. Fl 3491.85 -688.84 ~85.25 Y43.38 ~1576.88 -?25.95 722.55 9~4.48 37'I8.31 -799.17 795.0i 1094.48 39~I.~1 -810.98 gSq.~O ii91.87 ~008.78 -YO6.33 898.~3 123~.~ ~09~.~ -gqi. ~7 931.28 1286.~ ~18~.~2 -978.12 983.41 13~2.8~ CLOSURE DIET. DIR. 0 NOE 1 S45~l 5 S45t,{ 25 S45~ ~35 S45~ 45 ~ 421.1 54 65 70 SlOW 77 8~ S 8E 183 ~16E I22 S22E 144 ~27E 14~ S 30E 1~ ~33E 224 2~ S 37E 288 322 S4OE 358 ~41E 3~6 S42E 436 S42E 477 520 S43E ~6~ S44E 411 S4~E 4S8 S44E 788 S44E F~8 S45E 810 S45E 864 YI8 SqSE 972 ~4,~E I024 ~45E 107~ ~45E 1127 ~45E t178 ~45E I227 ~45E 1276 ~45E 1~4 ~45E 1 ~71 ~45E LEG 0.0 3.0 2.5 2.0 0.0 2.~ 2.~ 2.~ 2.4 1.5 1.5 1.5 1.5 1.~ 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1. O 1.0 1.0 1.0 I0 10 10 10 10 10 10 05 0.5 0.5 0.5 0.5 0.5 PAgE O00O2 4~00. O0 27.50 4700.0£1 27.00 "%880. O0 27.00 490l).00 27.00 5000.~ 27.00 5100.00 27.00 520[L00 27.00 5300.00 27.00 5AO0.00 27.00 55~ ~' 27 ~ u u. O0 . OB 5600.00 Z~.O0 5700.00 2~.00 5800.00 27.00 5~00.00 27.00 ~000.00 27.00 6200.00 26.50 ~]OO. O0 26.00 &~O8. O0 ~5.50 ~5~0.8D 25.00 ~600.08 24.50 6700.00 2~.08 6800.0g 2~.50 ~O0. OO 2~.00 7800.00 22.50 7180.00 22.00 7200.00 21.50 7~00.08 21.00 7qOO. OO ZO.50 7500.00 20.00 ?znq O0 1~.50 7708.00 i~'.00 7800. O0 18.50 7~00. O0 18.00 8000. g0 17.50 8100.00 17.00 8200. O0 1~.50 8~00.00 16.08 8~00.00 15.50 8500.00 15.00 8600.00 14.50 8700.00 1~.00 8800.00 13.50 8~O0. O0 i~00 ~80O. O0 12.50 ~IOO. O0 i2.OO ~200.00 11.50 ~4OO. Ofi tO. OO 9700.00 i6.08 9880.00 I8.00 ~$00.00 10.00 10000. O0 i0.00 ~;42. OOE/ 4273. 02 -I010.59 .~94.72 ,S41.5~ 4181.91 -1044.75 1025.28 S4I. OOE 4451.01 -1078.88 1055.14 ~4O. SOE 4540.II -ii1L27 1084.77 ~40. OOE 462~.2i -1147.9] Ili'1. I0 ~39.50E 4~18.30 -1182.8~ I143.13 ~39.00E 4807.40 -1217.99 I171. ~8.50E 4896.50 -125). ~9 I200. ~38.00E 4~85.60:1.289.0A 1228.38 ~37.58E 5074.70 -1324.. ~4 I256. I? S]7. OOE 516~.79 -i~6~. 08 S]8.5OE 5252.89 -1197.45 1310.82 S]6. OOE 5~41.99 -14~4.07 S]5.50E 5411.09 -1470.9I I]~4.18 S]5. OOE 5528.18 -1507.99 !]90. S]4.58E 5809.28 -1545.29 14i6. ~4.00E 56~8.58 -I582.49 i4~i. S]].50E 5788.28 -1619.27 14~8.16 S~].OOE 5878.3] -1655.~0 S]2. SOE 5968.77 -1691.47 i513.06 ~t2.0OE 8059.58 --1728.88 I~]~.40 ~]l. SOE 6150.76 -I781.81 t557.0I ~I.O~E 6242.29 -I7~6.2,1 1577. ~30.50E 63B4.16 -1830.18 I~98.0~ S]O. OOE 6~26.]8 -I8~]. 57 ~617.57 ~29.50E 6518.93 -1896.44 S29.00E 6611.81 -1928, 77 I654. S28.20E 6705.0i -1%8.59 I~7I. ~z7. qOE 67?8.52 -I99I. 9] 1688. S26.60E 689~.~-2022.77 1704.05 ~25.80E ~986.45 -205~. 09 1718.97 S25.00E 7080.8~-2082.8~ i7]].11 ~24.20E 71~q,..~qq -2112.10 174~.4~ S23.40E 7270.52 -2140.75 175~, ~22.~0E 7]~5.7~ -21~8.81 177I. ~21.00E 7557.0I -222]. 10 17~2. S20.20E 7653.02 -Z24.. 30 1802.~0 ~l~.40E 774~.2~ -2274.83 1811. ~18.80E 7845.7~ -2299.70 I820. ~17.80E 7~42.44 -2~23.89 1828. Sl?.OOE 8019. ]6 -~347. 38 1815.87 S16.20E 8136.4~-2~70.1~ I842.46 ~15.40E 82~3.83 -2392.21 1848.70 o, 1854.41 S13.80E ~42Y.08 -2434.10 I~57 62 ~13. OOE a52~ .... 98 -2453.91 ~°A4~, .34 ~i_. 20E 8~2.,. 08-~,~"'~'~. 95 SIO. 68E 8821.86 -2507.8~ ,I875. S 9.8OE 8?28. ]~ ...252~. 92 ~ 8. OOE .0t~.~2 -2S~2.07 ~ 7.20E ~I17.~0 -2557.2Y ~ 6. OOE 9215.78 -257~.54 t885. S 5.50E 9314.26 -2593.81 1887.42 I378.56 142]. 54 1468.22 I512. % 1557.77 1602.84 1647.57 1737.5~ 1782.87 1827.80 i872.97 1918. I8 1%]. 42 2008.8~ 2054.08 2098. ~ 218~. 52 222~. i6 227I. OI 27~2.08 2~9I. ~] 2~0.5~ 246~. ~5 2~41 68 2576 ~7 2611 50 2645 17 2~77 78 270~ ~3 274I 00 2F7~ 1? 2800 4~ 2828. ~I 2883.04 2~08.78 2957.54 2980.56 3002.67 3023.8~ 3044.20 306~. 6i 3082.12 3147. Y? 317Y. 72 1418 1484 I509 ~44E 1554 S44E i600 ~44E I845 ~44E 1890 ~44E I735 g44E i781 ~44E 1826 ~43E 187I S43E 1961 200~ S4]E 205I S43E 20~6 S43E 2141 ~42E 2184 R42E 2227 S42E 2269 S~2E 23~ 2351 ~41E Z~Yi ~41E 24~0 2468 ~4IE ~541 ~4IE 2577 ~4[~E 2611 ~qOE 2645 S40E 2~78 S40E 2710 2741 S40E 2771 2800 2828 285~ 3 ~gE 2882 2 ~08 2~33 S38E 2957 S38E 2980 S38E 3002 S 38E 3023 3044 3882 S 3lDO S 37E 3II6 ~37E ]112 SiTE 3147 ~]TE ]16] S]TE 3288 0.5 0.5 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.8 0.8 0.8 0.~ 0.~ 0.8 0.5 0.5 0.5 8.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0. I 0..t 0.3 0. I FILE' ?~EgP38 Dfil~ fi CI]RPDRt~TE ]I~IE~H~RINg ~NTE~ C~1~ ~:Pq.2 0~'/11/87 PAgE 0000 3 18100.00 10.00 ~: 4.00£ 9412.74 -2611.12 t888.86 3211. O0 3223 ZO20O. O0 ~.OO g 1.DOE ~011.37 -Z62T. 60 lBBY.60 ]ZZD. Oq 323r 236E 10300.08 9.00 g O. OOW 9610. I3 -2643.24 1889.86 3239.05 3249 !040~.00 ~.OO S I.50W 9708.90 -2458.88 i88~.6S 3252.35 32~2 S35E 10~00.00 ~.00 ~5.00~ 9906.43 -2~0.12 1887.88 3278.2I 3286 18800.00 9.00 S 8.00~ 10103.97 -2~I. 20 I884.34 3303.03 3310 S3~E 11000.00 ~.00 Sl1.00~I0301.50 -2752.05 187~.1~ 332~.BI 3332 11200. O0 ~.O0 S14. OOW 104?9.04 -2?82.5~ 18~2.40 334?. 51 3354 11400.00 9.00 S17.00~106~6.57 -2812.74 186a.04 3371.04 3374 ll40O. O0 V.O0 ~28.00{ 108~4.i1 -2842.4I 18~.12 33fI. 34 33~4 S33E 0.3 0.2 0.2 0.3 0.2 0.2 0.2 0.2 0.2 i i'Pj~I)IT IDNC~L U~IT,% UERTICAL [>EPTH 100. 508. i100. i ~0~. 1400. 1500. I600. 1700, 2100. 220~. 2500, 2600. 2708. 2800. 2900. 3100. 3700. 3900. 4080. 418[1. ~208. 4300. 440~. 4500. 4600. 4~F a3~ ~ORTH EAST -7Y5. -795. -7~5. -7Y8. -805. -812. -819.94 - 828.77 -83.9. i0 -848.97 -856.77 -863.98 -872.87 -883.4~ -895.88 -910.09 -926.15 - ?43.78 -962.78 -?83.18 -1005.02 -! 028.34 -1053. I9 '-i077.6! -i 107. 85 .-t 137.36 -i 168.80 -1202.03 --1237.23 -!274. q3 -13i3.44 -I 354.94 -i 3.°,8.41 -'-1443.14 --i 487.40 -I 5.~0. ?0 -i573.69 --* ~'~ 76 -,.i &57. I3 -I -::,97.78 -1737,77 _, -_,~,7 15 -i 854.34 -1892.79 --I 931.57 -I 970.68 -2 DIE 07 -204% 79 O0 -684. O0 O0 -604. O0 O0 -604. O0 46 -604.46 86 -607.86 06 -614.06 4? --621.47 -628.8? -834.40 -635.64 -632.38 -$25.37 -615.83 -604.19 -590.44 -574.57 -556.57 -538.45 -514.61 -4~I. 33 -4~. ~i -440.45 -412 81 -383 7I -3~3 II -~2i 08 -287 36 -252 t7 -215 41 -178 95 -136 77 -.94 96 -51 43 -4 i6 · ~9.87 84.82 128.45 170.84 252.06 290.94 328.58 364.89 397.97 434. O0 4~7.43 580.47 533.i7 565.47 597.38 TD(~P74229 ) FR[}t't ~l]. I FT 7~. ~2 S58~ 80. I4 258~ f~O. 57 ~58W 81.65 7]. 04 2~2W 64. 51. I~ ~8iN 50.76 R88~ 59.05 R76N 65.22 72.3& N72N 78. ~O N70N 84.22 89.70 ~¢7. I4 N53~ ~4.27 ~5.03 98.26 N42~ 104.43 113.30 i24.27 I37.41 152. ~5 171. ~5 I9~. 85 220.88 250.31 283.87 320.51 356. ~4 426. ¢4 461.58 529. O0 54i. 54 624.07 654. lO ~40~ 683. ~O 714.18 N40~ 745. O0 77~. 45 N4O~ f~OO, 22 N4O~ ~P 'fH(6P7421~ ) rf~uM )~,[!. 1 80. Ii 88.19 79.95 ~¢7N 78. ~5 ~¢7~ 75, 01 ¢7.71 58.7~ 4~. 80 41.1~ ~8~ 30, 0i 28. ~5 3I. 10 S82~ 3~. 05 ~3, 23 83. Ol 87.72 i85, 76 SOIN I2,1. I0 S85~ 145.82 S87~ i¢~. 54 if/5. 85 N87~ 222. I8 250. ~2 N83N 281. ~ ~81~ 38& 20 425.77 N75N 467. 5I N7~N 5~1. ¢4 557.8& N71N 605. 07 694. 84 779.29 ~99.42 738.04 974. O1 lO06. ~2 N67~ I040.26 1074. 27 1183. 43 ~P "36 TO(gP74236 ) FROM FT DIR. 9.22 N?TE 8.85 NT¢E 8.1~ N?SE &. 98 N7~E 8.47 N56E 12. &4 N55E 18.8B 28. O] NTOE ~8.2& N72E 51.5~ 55.78 60.76 67.4& ~tE 74.86 ~57E ~2.42 ~52E 90. ~4 ~47E ~O0.24 ~42E ~24.42 ~SE ~54.80 ~SE ~72. O0 ~89.5t ~¢E 207. OI R2?E 224.8I N27E 243.11 NSAE 263.38 R22E 319.91 R15E 354. ~9 N1]E 390.98 NIOE 429.42 N 8E 47~. 14 512.2~ N 4E 595.75 N 2E 6~6.44 ~ 2E 7~3.87 ~ 2E 750.57 ~ 2E (~57.90 ~29.84 ~ 5E 967.02 X 5E 1004.93 N 6E 1043.3~ ~ ~E 1082.50 TRUE t~E.RT~C~L I~EFT~ 200, O0 ~. 01 ~00. O0 ~. 51 ~O0.0[~ 12.92 700.08 19.12 800. O0 25, 3~ 900. O0 30.69 I000. O0 ~2.54 i~O0. O0 ~0. ~2 ~200. O0 2& 8~ l~O0. O0 25.98 ~qOO. O0 ~J. 28 ~500. O0 4~.59 1608. O0 ~I. ~2 1700. O0 83,83 1800. O0 109,03 1900. O0 13~, 16 2000,00 1~7.25 2100. OO 196~ 9~ 2200. OO 225.79 2~00. O0 253,6I 2400. O0 280.50 2500.08 306, 56 2600. O0 3 ~i. 16 2700. O0 35~.61 2800. O0 ~7~. ~7 2~00. O0 ~9]. qO ~OOO. O0 ~09.70 ~]00. O0 q ~0.5] 3200. O0 454, 68 3]00. O0 482.45 3400.00' 512.~7 ~500.00 54~.02 ~00. O0 ~02.~8 ~800.0~ ~I.45 qO00. O0 ~8~. 2I qlO0. O0 705.70 q200. O0 72~.4q 4~00.00 7~7.~5 4qO0. O0 750.12 4508.08 742. ~2 4400. O0 F75.84 4700. O0 789. t2 ~800.80 803.47 ~988. O0 819.58 5008. O0 8 35.58 TI]( ) TI]( > TH( ) FROM RI]. 1 FROM NO. 1 FROM Nil. 1 FT 1>It'4. FT DIR. FT DIR. UNIT -775 - -80O t-- -825-, ......... 0 Z -850 -875 -95o-~ ............ ! .......................... i ........ \'"i .......................... ::- .... _.x ...... !...:.~:,~ i--- ,, ~ ~ -I000 ~ ~ i j -7< )0 -675 -650 -6Z5 -600 -575 -550 -525 -500 -475 WEST EAST Legend 0 gPSBPSS(~F~zc,?o~-i~ C-~P A GP74229 ('c-,'p ~'Zg') 'T- 0P74219 19') X GP74236 (C-~P ~ ~ GP74217 ~P ~- SUBJECT Amoco Production Comp~ ENGINEERING CHART Sheet No. File Appn Date ,,7000 - Amoco Production Comp~ File Of SUBJECT {0 ENGINEERING CHART Appn I : i , :' ; i I i i 'j :i ; . I ! i i i i ' t ' j - :. ] ' : T : i I 000 : · · ~EAO PLATFORM ANNA DRILLING STACK 30.25' \ / 123" I I _ PITCHER NIPPLE--16"ID W/ 10" FLOWLINE ANNULAR BOP "NL SHAFFER" 13 5/8" 5000 PSI BX--160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SHAFFER" ---13 5/8" 5000 PSI BX--160 ASSY WT. 16,500 LBS. __MUD CROSS-- 13 5/8" BORE W/ 4" 5000 PSI VALVES ~ CK __i_SGL GATE BOP "NL SHAFFER" 1,~ 5/8" 5000 PSI BX--160 ASSY WT 9100 LBS. RISER 18"0D 13 5/8 5000 FLG -~W/ GREYLOK CLAMP RING (AX) "ClW" P/N 41700--13 LOWER RISER 11" ID .... W/ 1.0" 5000 PSI FLG (RX--54) i 11 ]4. 12 SEWARD MERIDIAN ALASKA I SCALE: I" = 1,000 TION 13 7 18 LEG. NO. I LEG. NO. 2 LEG. NO. 3 LEG. NO. 4 LAT. 60°58'37.56'' LAT. 60°58' $6.96" LAT. 60058'36.53" LAT. 60°58'57.12'' LONG. 151°I8' 4 6.00" LONG. 151° 18'45.28" LONG. 151°IS'46.S2'' LONG. 151° 18'47.48" ¥ = 2,551,413 Y= 2,551,352 Y : 2,551,310 Y= 2,551,371 X = 266,816 X = 266,850 X = 266,774 X = 266,742 FROM N.H. COR. FROM N.H. COR. FROM N.H. COR. FROM N.H. COR. 729' SOUTH 8, 790' SOUTH 8, 834' SOUTH a 774' SOUTH 636' WEST 600' WEST 676' WEST 709' WEST CERTIFICATE OF SURVEYOR · ~.?' ~ , , I hereby certify thet I mm properly registered to prmctice lend surveying in the store of Almskm end thet this pier represents e Iocetion survey mede by me or under my supervision end thet ell dimensions end other deleils ere correct. Date Surveyor NOTE The Io¢otion of plotform legs wes occomplished by using triongulotion stotions Dud, Trinity, end Tyonek Offset. (-en~r o.~ ~.K'~- '7~'3'FICI.- ~ (~'FEL FINAL PLAT OF TYONEK PLATFORM "A' LOCATED IN NE I/4, NE I/4, PROTRACTED SEC. 12,TION,RIZW, .S.M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. P.O. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY 8~ ASSOC. LAND SURVEYORS a CIVIL ENGINEERS 32OI ARCTIC BLVD. ANCHORAGE, ALASKA CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) mdmin.~~ ~/}'~. 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~.~. (14 thru 22) (23 thru 28) (6) OTHER _~~ (29 thru 31) Company ~/~O Lease & Well No. ~,[~ /~7~'~ ~ YES NO REMARKS Is the permit fee attached .......................................... ,~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ /~ ,. , Will surface casing protect fresh water zones ....................... ~ 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 ............................ ~ 23. 24. 25. 26. 27. 28. 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. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ...... ~ .......................... For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... 31 If an offshore loc., are survey results of seabed conditions o mm (S) Add: ~,~?'d< //-///-~ 32. Additional requirements ............................................. B~: Engi~n~erin~: WWB LCS BEW ...... rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~2~ i~o ~EV - i o/c ~zo ~ OFF: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , ~ REEL HEADER ** EEL NAME : ~Tm : ~IGIN : FSYS ERVICE NAME: 51TLIS EEL CONTINUATION NUMBER: 01 REVIOUS REEL NAME : 3MMENTS: DRESSER ATLAS -LIS CUSTOMER TAPE --- CREATED BY SDS PROGRAM ~ 2.0 =NGTH: 132 BYTES ~ TAPE HEADER ** ~PE NAME : ATE : qiG!N : FSYS 5RVICE NAME: MAIM ~PE CONTINUATION NUMBER: qEVIOUS TAPE NAME : S~MENTS: :NGTH: 132 BYTES * =ILE HEADER # I ** ILE NAME: M~IM .001 ~RVICE NAME: ~SION # : 1 ~TE: 85111120 AX RECORD LENGTH: 13~4 ~YTES ILE TYPE: LC :R5VIOUS FiLE N2ME: . iNFORMATION RECORDS ** MNEM CONTENTS CN : AMOCO PROD. CO. WN : G~ 1~7~2 N0.38 :N : GRANITE POINT COUN : KENAI STAT : AK LOC : 150.00 FORMAT ** UNITS ENTRY 5LOCKS TYPE ENTRY DESCRIPTION 9 11 0 1 DEPTHS DECREASE 60.0 FRAME SPACING .lIN FRAME SPACING UNITS 21 MAXIMUM FRAMES/RECORD TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE NAME ?TI l~ REPR CODE SIZE SAMPLE UNITS IIII Ii--m CURVE NAME RECEIVED JUN 1 4 1988 011 & r.~ Cons. Commission Anchorage REPR CODE SIZE SAMPLE UNITS lImm ImmI Iliml R 65 4 1 TEN 65 4 1 LBF CQ 68 4 I ~IM =OC 68 4 1 CHMM !LD 68 4 1 OHMN * :ORMAT ** CAL SPD AC RILM ~/~ ~$/: OHMM ENTRY BLOCKS YPE ENTRY CESCRiPTION 4 1 DEPTHS DECREASE 8 6C~0 FRAM~ SPACZNG '~ ,lIN =RA~E SnaCING UNITS 11 21 M~XIMUM F~XMES/~ECO~S 0 TERNiNATOR -O.5OO LEVEL SD~CING -ATUM SPECI:iCATION BLOCKS 5URVE REPR .~ME COSE SZZE SAMPL~ UNITS immm --m--m --mmmm -iLD 68 4 1 ~R 68 4 1 apl TTEN 68 4 1 ~C~ 68 4 t ~i~ ~FOC 68 4 I CHMM qZLD 68 ~ I ..~HM DATA ** 3r-'PTH 13063.C00 FT 3067.238C M CtLD d4,87S S° TTEN 3891.411 SDD RFOC 17.038 RILM 109.6e7 ~ ~97 15.359 DF-PTM lOOO0,O00 FT 3048.0060 Iq C ~LO 68.9eP Sm TTEN 5465.9~0 S~D RFOC 16.241 RILM D:PTH 9gOO.CO0 FT 3017,5260 M CILD 52.8?0 SD TTEN 5~78.637 SPD RFOC 24.462 RILM 103.o36 27. ,~97 18.217 DEPTH 9800.C00 FT 29~7.0~6,0 M CILD 188.223 SP TTEN 5357.~7 ~¢PD RFOC 5.251 R~ ~LM 102.406 25,027 5.123 DEPTH 9700 ~¢0 CT 2056 5660 M CILD 175.730 SP TTEN 5308.359 SPD RFOC 6.197 RILM 9~.707 41.955 6.136 DEPTH 9600.000 FT 2926.0860 M CURVE N~MF-_ SP C&L ~C RILM GR ACC RZLO SR ~CQ GR RiLD G~ ~C~ RILD GR RILD REFR CODE 6~. 68 4 4 4 &2.091 C.O00 15.414 ~.407 u.OCC 1L.497 33.727 O.000 18.914 4C.981 0 nO0 5.313 43.380 0.000 5.691 CAL C ~ L AC CAL ~C C;~L SAMPLE 1 1 1 i1 C~L ~C UNITS MV IN F/MN US/F O~MM 12.772 ~ 17~ . ~. 12.o95 0.172 16.t83 0.172 13.116 0.172 t2.~25 0.172 CiLD 154.07Z SP S9.268 GR 44.081 C~L 11.772 TTEN 5257.496 SPD 41 .319 ~.CQ 0.000 aC 0.172 R;OC 6.561 RILH 7.124 RILD 6.4.~0 DEPTH 9500.000 FT 2895.6060 CILD 193.753 SP 99.081 GR 53.166 CAL 12.651 TTEN 5151 .$59 SPD 41 .~22 ACQ 0.000 AC 0.172 RFOC 8.485 RILM 5.801 RiLO 5.161 OEPTH 9400.000 FT 2865.1260 M m--mmmmmmmmmmmmmm. CILD 67.254 SP 65.251 GR 64.951 C~L 13.430 TTEN 5073.590 S~D 42.543 AC~ C.OOC AC 0.172 ~;OC !3.621 RILM 14.325 R~LO 14.869 OEPT~ 9,_'200.000 r--T 2,~04.15b0 M CZLD 8;0.294 SP ~1.!55 GR 69.'~1 C&L 12.070 TTEN 502'~. 234 SPO 42.698 '~CQ 0.000 AC 0.172 RFOC 1~. 4~6_. . RiLM 12 . ~., ~ ,~ ~ILD 1~_. 454 DEPTH 9100.330 =T 2773.6~C. 0 M DEPTH 9000.000 FT 2743.2060 M C~LD~ m~, ~..054 SP 35.305 GR ~0.~2~ C&L 12.934 TT~N 4870.9!8 SPD 42.111 ~CQ 0.000 ~C 0.172 R~OC 13.059 RILM 12.857 RILO 13.688 DEPT CILD TT=N RFOC H 8900.6'00 FT 2712.7260 M 120.678 S,~ 36.576 Gq 4!.025 C~L 12.418 4762 641 S~D 41 ........ : u. OOO ~C 0.1 '7'~ 7 2nl RiLM DEPTH 8~00 nO'~ FT '>552 24=¢ CILD 20.5~4 S~ :1 :'21 'R 79 t~u C~L 15.n53 TTEN 464o.555 SPr~ 42.73n,~ ~C,7 n,~.O0o. aC 3.1?~,- RFOC 57.43.8 RiLt, i 41.3~9 - ,~ILD 4.~.748 OEPTH 8700.000 FT 2~5!.7650 M ClLD ~7 ~ SD 4n TTEN 4575. ,~ .~A4 S~n~ ~ 4~. ~OC 10.~27 ~ZLM 1~ DEPTH 8600.000 FT 2521,2850 M ClLD 103,300 SP TT;N 4573.352 SPD RFOC 11,112 RILM .7~3 GR 58,193 C&L 11 .9~0 .3;J4 ~C: C,OOO AC 0,172 .;81 R!LD 10,274 44.1~2 GR 75.319 C~L 12.82~ 42.960 ACQ 0.000 AC 0.172 ~.573 RILD 9.681 DEPTH 8500.000 FT 2590.8050 M ZLD 98.075 SP TEN 4447.898 SPD c-OC 11 .640 RILM 48.'~47 43.5~9 10.268 EPTH 8400.000 FT 2560.3250 M ZLD 103.185 SP TEN 4382.160 SPD FOC 11.233 R!LM k3.6,r:2 EPTH 8300.00 ZLD vn.= TF.N 430,7.4 FOC 12.5 "i L,3 41 .6!5 S~ TTEN 4~43.277 SP-'3 ~F-OC 20.2:~3 RZLM 44.554 J[PTM SIOO.OCO FT 24~g.885S ~ 21L0 48.232 Sm 53.4~8 TTEN 417~. 6~5_ S~D, 44 . 5~,.~ ~. ~=OC 21.1~2 RZLM 23.130 DEPTH $C00.000 FT 24~$.4050 ~ CILD g7.474 S~ TTEN 4091.33~ SPD RFOC 29.741 RiLM q9 17~ ;~.555 14.74! 3;PTH 7900.C00 mT 24.37.;'250 M CILD 79.321 SP TT;N 4058.103 SPD RFOC tl .976 RiLM 4~ I ~ 13.311 DEPTH 7800.000 FT 2377.4~$C h~ ~ILD .C~ TTEN 3937.256 RFOC 17.5~4~ RILM 51 ..~73 45.~.13 14 ~71 DEPTH 7700.CC0 FT 23~-6.9650 ~ CILD 75.~31 TT;N 3747.276 RFOC 10.264 i DEPTH 7600.000 FT Spn R!LM g2 ~20 ~3.~6~ 13.026 231~.4350 ~ ~ CILD 117.251 SP TTEN 3691.509 SPD RFOC 7.942 R!LM 94.762 42.529 8.672 DEPTH 7500.000 FT 2286.0050 M CILD 48.386 SP e3.707 TTEN 3674.312 SPD 42.729 RFOC 19.658 RILM 21.654 DEPTH 7400.C00 FT 2255.5250 M ~m~mm~mmmmmmImmmmm!m--mmmmmmmmi GR' ,~CQ RILD GR ~CO, RILD ~iL3 RILD ,gR RTL],. ACQ GR A C2, R!LD ~iL2 GR RILD GR 84.026 0.000 10.195 CAL ~C 57.573 ~ nCO 9.6~1 CfiL ~C C~L aC 41.296 O .0C~ p4.~'~~' C 4 L C.00C ~0.733 C~L 34.347 C .C, CC C&L ~C 1 ~ ,~r. 7 CAL & C 47.732 C.OCC C,~L ~C 73.647 C .0C,~ 13.187 90.259 C.OOC 8.529 CAL AC 74.129 0.00C 2C.567 C4L 4C 12.177 0.172 12.548 0.172 9.954 2.172 11.531 0.172 10.756 0.172 10.096 0.172 12.303 ,2. 172 1_~.163 0.17~_ 14.20~ 0.172 12.114 D.172 10.9.05 0.172 'ILO 129.429 SP 95.952 'TEN 3403.~8 $P2 42. 293 -~=OC 7. 295 RiLM 7.773 '.~EPTH 7300.C00 ET 2225.0440 M *--iml/IimmmmmmmImmmmmmml -iLD 101 .509 SP 73.263 -TEN 3563.285 SDD C2.285 ~FOC 12.494 RILM 10.968 3:PTH 7200 COr' FT 21o4 c640 M 'ILD 74.632 SP 107.663 TTEN 3499.9~3 SPD 41.626 ~OC 10.1G6 ~IL;~ 13.C2~ EPT~,, 71~, uu.~'~CO :T m15~_ .3~i&C,.. M CILD 77 7m · · ul SP $1 $~1 TTEN ~8 4~6 SPD 47 ~F'OC 12.336 RILM 13.4'~5 2EPTH 70CO.CCO FT 2133.5C4C M 'iLD 05 7~1 S~ 109 ~ I ~' , · , TTEN 3483.093 SPD ~3.C75 ~FOC 10.~22 RILM 9.98~ ]EmTH, 6900 .000 FT 210=~. 1240 M lilIillllIIlIIllIliiIlilIlIlI! · -ILD 112.6'13 SP 117.073 TTEN 3313.91:~ SmD &3.4~1 RFOC 8.937 RiLM ~:PTH 65n0~ .COO FT ,~07~,.64~0 M CILD 120.240 SP TTEN 3239.783 SP3 ~FOC 6.E38 RILM 121 .6~7 44.240 7.754 ~EPTH 6700.CC0 ST 2042.16cC M "iLD 1'~.~ 1~-1 Sm FTEN 31 94.807 S~D ~.:OC 7 237 m 1 25.694 45. 245 7 · 076 CEPTH 6600.000 FT CiLD 159.244 S TTEN 3128.63.5 S RFOC 5.779 R 2011.6540 M P 121.~14 PD 44.402 ILM ~.743 OEPTH 6500.00 CILD 109.736 Sm TTEN 3040.062 SPD ~OC 5.~10 RILM 0 FT 1981.2040 M 114.220 44.667 8.379 DEPTH 6400.000 FT 1950.7240 M CILD 158.480 SP TTEN 3062.754 SPD RFOC 6.127 RILM 128,136 43.535 6.082 DEPTH 6300.000 FT 1920.2~4C M GR ~iLO GR ~C~ R!LO ~iLD GR ACQ RILO GR ACQ RILD GR ,~C~ P!LD OR RILO GR RILD ~R ~CQ RILD GR R!LD GR ~C~. R!LD C.OCO 7.726 62.507 O.OOO 79.916 C.OCO 13.3~9 52.462 C.OCC 12.870 87.420 C.3OC 10.L44 ,,.,, ~ .342 C. 0 C, C, 62.243 O.O00 5.317 56.~14 O.OCC 7.738 65.241 6.280 63.796 C.O00 9.113 43.882 O.OCO 6.310 CAL AC CAL AC C~L AC C4L CAL AC CAL AC C~L ~C CAL A C C~L AC CAL AC CAL AC 12.012 0.172 12.282 0.172 10.9~1 0.172 10.874 0.172 10.§06 0.172 9.9~6 0.172 9.39C 0.172 7.845 C.172 6 · O,J9 0.172 6.471 0.172 7.692 0.172 ~LD TEN F-OC , . 137,063 SP 126,301 2991,464 SPD 43,942 5,994 RILM 6,S05 _, GR AC~ RILD 41 .741 0.000 ?,29~ . ~., C~L ac 7,022 0,172 ,. :PTH 6200.C00 FT 1559.7o40 M mmmmmmlmmmmm. iLO 113,099 SP 121 ,871 TEN 2876,943 SPD C5,516 =OC 8,250 R!LM 8,290 RiLD 61,478 0.000 8,842 C~l 6,954 0,172 EPTH 6100.000 FT 165~.2S4G M ILD 69.946 SD TEN 2879.445 SPD FOC 12.276 RZLM 117.544 44.~70 11.C~5 GR ~CQ RILD g4.228 0.000 14,297 C~L dC 7.702 C.172 'iLD 69.S08 S~ 115,6~3 'T~N ~77 ~0 S°D ~5 ~14 =OC 15,283 RILM 14.102 GR ~C~ R!LD 44.460 14,325 CAL ~C 6,732 0.172 .EmTH 5900.C$0 FT 1798.324C M ~LD '~ 3.031 SP 131.~P9._ rTEN 2819,224 S~O 45,557 c:.~OC 15,5~9 RZLM 14.325 AC q RILD 5/- 3~¢' C.OOO 13.593 CAL ~C 7.552 0,172 ,', E P T ~ 5800.000 FT 1767.84,40 -iLb 12_2,830 SP ..'-TEN 2595,115 S~D ~FOC 6,~67 RiLM 132.242 45.752 7,751 C-.~ RILD 50.597 "'" ~. 1 41 C~L 3~PTH 5700.C00 FT 1737.3640 M CiLD 80,196 SP TTEN 2661,~06 SPD ~FOC 9,101 RILM 45,~37 12,244 GR ~CQ ~ILD 82.761 C.OO"~ 12.Cd' Ca, L ~C 5.411 0,172 ]~PTH 5600.000 FT 1706.8840 M 'SILO 106,591 SP 142,794 TTEN 2652,b57 SPD 45,983 ~FOC 7,919 RILM 8,.~61 G~ ACC RiLD 61.258 u,COO 9,373 C4L ~C 5,6~5 0.172 D;PTH 5500.000 ~T 1676.4030 M CILD 7~ ~=3 SP 147 ~. ...... ~43 TTEN 255~,~22 SPD 45,152 R~OC 9,261 RILM 11,691 DEPT CILD TTEN ~FOC H 5400,000 FT 1545,9230 M 84.206 SP 123.403 2576,900 SmD 4~.963 9.036 RILM 10.795 GR RILD GR RiLD 75.355 O.OCO 13.825 46.419 O.OOO 11.876 C4L XC CAL AC 6,339 0,172 5,273 0.172 DEPTH 5300,000 FT 1615.4430 M CILD 138.202 SP 130.064 TTEN 2433,742 SPD 47,134 RFOC 6,546 RILM 6,~59 GR R!LD 65,068 0.000 7.236 CAL AC 5,169 0.172 DEPTH 5200.000 FT 1584.9630 M il--l!!liIiliIlllilllIlll iLD 95.c32 'TEN 2441.845 FOC 9.424 SP SPD RILM 128.207 47.051 9.477 GR RILD' 77.320 C.O00 10.468 C.~L 4.959 S.172 ~EPTH ILD 135.2~3 "FEN 2327.535 .~OC 6.325 1554.4830' M SP SPD RILM 134.010 47.760 6.701 GR ~ILD 63.614 0.000 7.392 C~L $,C 5.052 0.172 ;~PTH 5000.000 FT 152~.303C M iLD 123.642 SO 157.315 TEN 2330.016 SPO 47.&31 · :OC 6.923 RiLM 7.770 GR RILD 38.094 0.000 8. C',~.8 C~XL AC 5.797 0.172 E · S I TT PTH 4900.C0g FT 14~3.5230 M LD 83.570 SP t63.950 EN 22L8.201 SPO 48.906 OC 10.703 RILM 15.952 GR ~C ~Q RZLD 4~.029 11.~6 CAL AC 0.172 3EPTH 4800.CC0 FT 1463.0430 M *ILD 57.775 SP TTEN 2203,856 SPD R:OC !1.5,39 RILH t58.772 ~8.286 1~.376 O~PTH 4700.000 FT 1~32.5630 M GR R ILD 62.~=6 3.OOC 14.755 C~.L 4.~77 0.172 ~ILD ~1 .=02, S*~ TTEN 2197.041 SmD RFOC 44.403 RiLM 16~.380 52,315 GR ~iLD 35.545 0 &6.5C7 C~L .,~ C '~. 553 0.172 ,.95PTH 4500.600 FT 14.02.L'383C M CILD 50.~50 Sm TTEN 2087.~50 SPD R=OC 17.922 RiLM 166.19':. 49.2~7 1E.940 O;PTH_ 4500.C'30 ,~T 1~71.,, ,60~0_ M ~ILD S2.269 ~ r, CC 16.431 C~AL &C 4,932 0.172 CILD 73.050 SP TT;N 2052.207 SDD RFOC 12.3t7 RiLM DEPTH 44~..,, C!LD TTEN 2312 RFOC 12 DEPTH 4m00. mIIllIIllIII CiLD 98 TTEN 1933 RFOC 7 164.051 11.541 ¢,OO FT 13'41,123C M :~1 S~ 19~ 116 2~9 S~D 46.~7~ · 722 ~ILM 15.192 O00 FT 1310.6430 .757 SP 203.797 .570 SPD 46.425 · 292 RILM 7.928 GR ~ 'LO GR ~CQ RILD RiLD 66.5CQ 0.00O 13.6..~ 5e.591 14.372 56.085 C.000 10.126 CAL ac CAL /~C CAL 4.970 '3.172 5.962 0.172 7.619 0.172 DSPTH 4200.00 IIIIIlIIIIIII! CILD 117,5 TTEN 1917.~ RFOC 7.6 i DEPTH 4100.00 f. 0 FT I 280.1 630 M lmIIiIIIIIiItIII $3 SP 204,46~ 56 SPD 47.195 80 RiLM 7.861 0 FT 1 249. 6830 M SR ~CQ RiLD 58.313 0.0O0 ~ 505 C~L AC 8.797 0.172 - !LD 68,605 SP 2~ 6'.-625 TTEN ' 1903.594 SPD 46.608 -:~ FOC 9,747 RILM 13,663 GR RILO 3EPTH 4000.CC0 FT 121g.2020 M __mmmmmmmmmmmmmmmmmmmmmmmmmmmmm '!LO gl .255 SD 230.$06 TTEN 1843.629 SPD 46,876 ~FOC 7.9Q2 RILM 9.'~44 GR ACQ RILD ]EPTH 3900.000 FT 1188.7220 M 'iLD 54.646 SD 2~7.892 TTEN 1832.690 SDD 46.3n~ , q=OC 13,774 RILM 17,6~7 GR RtLD ~EPTH 3800.C00 FT 1158.2420 M CILD 88.522 SP 221 .297 TTEN 1733.709 SPD 46.~72 ~FOC 9,&92 RILM GR RILD ~EPTH 37~0.CC0 FT CZLD 103.274 TTEN 1770.910 qFOC 8.389 1127,7~2C M SP 230,344 SPD /.,..$. 6/,8 ~.ILM 8..$1 4. GR RiLO SEPTH 3600.C00 FT 1097.2620 M IimIlIllIIl, CZLD 64,~67 SP 235,128 TTEN 170g,367 Sm~ 47.665 q:OC 1~,917 RILM 13.~56 GR RILD 2EPTH 3500.000 ~T 1056.8020 M CILD -12.232 SP 107./'28 TTEN 1629.893 S~D R:OC 0.660 RiLM 100CO.OO0 G~ RILD DEPTH 343~.500 FT 1048.3620 M IlIiiIiIll CILD -12.3t2 SP 1t6.10~ TTEN 1622,~3~ SPD 47.995 RFOC m 677 RILM lmCO0 RiLD STARTING DEPTH :10n63,., .u,,m'qO FT ENDING DEPTH : 3439.500 FT 3067.2080 104S.3520 =2 5=8 ~ m ~ 0.000 14.576 42.912 0.000 10.958 54.350 C.OCO 18.300 59.928 C.OOO 11.2m7 ~7.28Z O.OOO 9.683 6 n. -~ 7,,3 0.000 1~,~18 32.6~9 10000.000 31.886 0.000 lOOOC.O00 CAL AC CAL ~C C&L AC' C~L AC C.~L ~C C~L AC C~L '~C CAL 10.251 0.172 10.680 0.172 10.3Z6 0.172 12.249 C.172 11.027 '~ 172 g,074 0.172 10.232 0.1'/2 9.464 0.172 ** FILE TRAILER ** FILE NAME: M~IM .001 SERVICE N~ME: VERSION # : 1 D~TE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT ~ILE NAME: ** FILE HE~OER # 2 ** FILE NAME: MAIN .002 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 ~LE TYPE: LO qEVIOUS FILE NAME: * !NFORMATZON R:CORDS ** MNEM CONTENTS CN : AMOCO PROD, CO, WN : GP 18742 N0.38 FN : GRANITE POINT COUN : KENAI STAT · AK LCC : 1 50,00 * FORMAT ** UNITS ENTRY BLOCKS 'YPE ENTRY C 1 5 6g.O 9 11 12 0 -0. 500 DESCRZPTiON DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS NAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING DATUM SPECIFICATION BLOCKS SURVE R NAM: C SSD LSN T EMP S~D ~ORR '~NC SR1 ~C ~ILM EmR ODE SIZE SAMPLE UNITS 68 4 1 CPS 68 4 1 iN 68 4 1 CPS 68 4 I DEG: 58 4 I F/NN 68 4 1 G/C3 68 4 1 % 68 4 1 .AP1 58 4 I US/F 68 ~ 1 O~MM ** FORMAT ** CURV: N ~ ~',., ~ LSD SSN GR TTEN. DEN- CN SP CALt RFOC RILD REPR CODE 63 68 58 6~ 68 S~?E 4 S~MPLE 1 1 1 1 1 1 1 1 1 1 UNITS CPS CPS L~F G/C3 % MV OHMM ENTRY BLOCKS TYP:, ENTRY 4 1 8 60,0 9 .lIN 11 12 0 -0.500 DATUM CURVE NAME .SSD ~ESCRIPTION mmmmlmimImImImmlmli DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING SPECIFICATION BLOCKS REPR CODE SiZE SAMPLE UNITS 68 4 I CPS CURVE NAME LSD · . . REPR CODE SIZE 4 SAMPL= 1 UNITS CPS ~N 68 ~ 1 -HP 68 4 1 ~D 68 4. 1 3RR 68 4 1 · ir., 68 4, 1 3 68 4 1 ~LM 68 4 1 CPS DEG; F/MN G/C3 % API US/r- OHMM GR TTEN DEN C N rr, L1 ',., . RFOC RILD 68 68 6~ 68 68 68 68 LBF G/C3 % MV IN OHMM OHMM 10 DATA ** EPTH 1006&.000 FT 3067,513C M SD 488,951 LSD SN 62,~94 GR 12 ~D 29,997 DEN NC 1 9.000 SP C 0.000 RFOC 10000.000 FT 3048.0060 M 8.958 7,418 2.503 ~ rO0 9.000 CAL TENP CORR GR1 RiLM 5.990 147.~85 -99~99.000 SSN TTEN CN C~,L1 RILD 170 .~$2 3842.616 15.000 SD 389,43~ LSD 23 SN 5.1,954 GR PD 29,327 DEN NC 30,550 SP ~C 0.172 RFOC I 2.~24 2.427 4,871 6.241 C&L TEMP C3~R GR1 RZLM 13.124 1~7.745 0.098 16.357 SSN TTEN CN CALl RILD 174.S59 5731 ,492 26.350 12.695 14.~97 ?:PTH 9900.000 FT 3017.526C M ]SD 546,836 LSD 469.224 _SN 37,721 GR 3~D 29,841 DEN 1.S71 ]NC 63,369 S~ 103.~36 &C 0,172 RFOC 24.4¢2 3-.=PTH 9500.000 FT 29.87.0460 M SSD 409.934 LSD 271 .740 LSN 78,~09 GR 42.36~ SPD 29.307 DEN 2,354 CNC 34.787 SP 1 02.4C6 AC 0,172 RFOC 5.261 C~L TEMm CG~R ~ILM CAL TE~P CORR GR1 R!LM !7,379 I 48,u 0,157 33,727 18.217 13.778 0.012 43.~81 5.123 SSN TT~N CN C$LI RILD SSN TTEN CN C$L1 RILD 143.863 _~670.039 59.3O9 16.183 1B,914 209,897 55~6.1~5 $0.787 13.116 5,313 3EPTH 9700.C00 FT 2956.5660 M SSD 426.800 LSD 295,582 LSN 73.245 GR ~3,211 SPD 30,682 BEN 2,432 CNC 20,776 SP 94.707 ~C 0,172 RFOC 5.197 DEPTH 9500.000 FT 2926.0860 M mmmmm--mmlmmmmm SSO 393.040 LSD 247,663 LSN 73,533 GR 42.659 SPD 30,591 DEN 2.484 CNC 22,495 SP g9,268 AC 0.172 R~OC 6,561 C~L TEMP CORR GR1 RiLM CAL TEMP CORR GR1 RiLM 13,394 147,E40 0.090 6.156 13.732 147.229 0,116 44.081 7,124 SSN TTEN CN C~L1 RiLD SSN TTEN CN CALl RILD 202,811 5&86,2Bg 16,776 12.32~ 5.691 209.825 5397.875 18.495 11,772 6,490 DEPTH 9500.000 FT 28~5.6060 M SSD 342,335 LSD 175.672 LSN 87,889 GR 59,777 S~D 29,997 DEN 2,432 i CNC 32,863 SP .~9.£:-31 C~L TEMP CORR GR1 14,020 146.559 0,130 53.16~ SSN TTEN CN CALl 252.652 5344.262 28,863 12,651 9~PTH 9400,000 ~T 236¢,1260 N $30 53.1.503 LSD 434.9~4 LSN 49.893 GR 55.559 SPD 31.129 D~N 2.114 CNC 51. 366 S~, 65 .~ 1 AC 0.172 RFOC 13.621 C4L TEMP CORR GR1 RILM 15.482 146.129 0.232 64.951 14.325 SSN TTEN CN C4L1 RILD ~I tN., I 175.191 5277.676 47.366 13.480 14.869 ll ~EPTH 9300.000 FT 2834.6460 M SSD 431.493 LSD 267.96~ LSN 54.821 GR 84.285 SmD 30.832 DEN 2.627 3NC 32.305 SP 64.772 AC 0.172 RFOC 5.944 CAL T~MP CORR GD, 1 Ri L~,~ 13.947 t45.~24 0.188' 82.885 SSN TTEN CN C~L1 RILD 177.622 5233.875 28.305 12.¢$0 5.702 D~PTH 9200,000 ~T 280~,1660 ~ immlmmmlimlmmmmImmmmmmI--m~.Imml SSD 36Q.4~7 LSD 21 8.934 LSN 49.247 GR 71.165 5PD 31.797 DEN 2.488 CNS 28.533 SD 61 .15~ ~C 0.172 R=OC 13.446 CAL CORR GR1 PILM 14.133 145.1~4 C.1~1 69.931 12.523 SSN TTEN CN C&L1 R~LD. 170.557 5127.309 24.533 12.070 12.454 DEPTH 9100,000 FT 2773,585C M SSO 3Q4.900 LSD 247.252 LSN 82.831 ,SR 3~.920 SPD 31.933 SEN 2.398 CNC 22 ~5 SP 17 &C C 172 C&L RILY 17,517 1£~,081 0,118 3 '.:, 47. C SSN CN C~L1 ~iLC 22¢.283 499¢.027 18.8~5 11.~s7 l&.O?O D~PTH 9000.030 FT Z7~3.706C M SSD 499,012 L$3 &51,o23 LSN 30,7;~ SR SPD 3!,603 DEN 2,&95 CNC 34,88.2 Sm 35,305 &C "17~ R~0C 13. C'~L T E,~IP CORR SR1 !3.69c 14&.1'~.~ 12.$57 SSN TTEN CN CALl RILD 131.157 5031.12o 12.o34 13.638 ~EPTH 8900,0C0 FT 27t2.7260 M SSD 527.C96 LSD 415.19~ LSN 70.564 GR ~4.231 SPD 32.1'a7 .D=N 2.324 CNC 26.4,$3 SP 30.575 ~C 0.172 RFOC ?.2~.1 C~L TEMP CORR GR1 RZLM 14.193 143.597 0.293 /.1.025 ~.153 SSN TTEN CN ~L1 RILO 207.570 493~.664 22.4~3 12.413 8.286 DEPTH 8800,000 FT 2682,2450 M miIIIImIIIimIiii SSD 604,800 LSD 737,772 LSN 24.882 GR 31 .942 SPD 32.220 DEN I .586 CNC 64. 685 SD. 51 . ~21 ~C 0.172 RFOC 57.408 DEPTH 8700.000 FT 2651.7650 M CAL TEMP CORR SR1 RILM 21 .307 142.814 C.045 29.120 41.559 SSN TTEN CN CALl R!LD 118.683 4913.980 60.a55 15.058 48.748 SSD 384.941 LSD 243.846 LSN 33.697 GR 56.262 SPD 30.124 DEN 2.506. CNC 34.996 SP 48.743 4C 0.172 RFOC 10.027 CAL TEMP CORR GR1 RILM 14.144 141 .849 0.072 55.193 10.981 SSN TTEN CN CALl RILD 140.145 4762.977 30.996 11.940 10.274 mmmmmmmmmmmmmmmmmm. SD 41,3.200 LSO 263.348 C~L SN 43.8Q0 GR 61 .440 TEMP PD 30.197 DEN 1,~33 CO~ 'NC ~3.115 ~P 44,192 G~I S ~,172 RFOC 11 .112 ~ILM EPTH 8500.C00 FT 2590.8050 M :~SD 364,929 LSD 218.649 C~L S,N 49.349 GR 86.504 TEMP ~D 30.870 DEN 2.574 CCRR NC 33,$80 SP 48.947 ,C 0.172 RFOC 11.64G RILM EPTH 8400.000 FT 25b0.3250 N ;SD CPO.- .656 LSD 291.~13 ~*AL _SN 47.099 GR 54.537 TE~m ~PO 31.311 DEN 2.456 CORR 'NC 35.17~ SP 45.~99 :C 0.172 R$OC 11.233 ~ILM bEPTH 8~n0 COO FT 2529 ~SO 378.006 LSD 253.8~ CAL LSN 68.584 G~ 63.599 T~MP SPD 31.8~4 DEN 2.552 CORR ~NC 28.230 SP 32.411 G~I &C 0.172 R~OC 12.6~0 RIL~ DEPTH ~P~ .... ~_ud. OOO FT 249Q 3050 $SD 363.198 LSD 225,12~ CAL LSN 136.387 GR 37.991 TEMm SPD 31 ~07 D.=N 2 54:~ r ,, .... ,..., ,~OPR CNC !4.015 S~ 6c.0~8 GR1 AC 0.172 R;OC 20,2'~0 ~ILM DEPTH 8100.000 FT 2468. :.'.'.5850 !,4 SSD 393.134 LSD 261.251 CAL LSN 105.470 GR 43,Ss5 TSMP SPD 32.123 DEN 2,407 COP~ CNC 22.876 SP 53,488 AC 0.172 RFOC 21,1~ R!LM 3EPTH 8C00.CC0 ¢T 2435.4350 M 5SD 414.~17 LSD 2~-. . ~17 r~L-~ LSN $3,699 GR 31 .~85 TSMP SPB 31 .997 DEN 2.~1~ CORR CNC 21.780 SP 39.173 GR1 AC 0.1~Z R=OC 2~.?~1 ~ZLM DEPTH 7900.C00 ~T 2407.~253 M $SD LSN SPD !CNC ~C !DEPTH ,~n 438.511 LSD 274.6~2 CAL 46,154 GR 60.201 TEM~ 32.235 DEN 2.434 CORR ~8,95~ SP 87.495 GR1 0,172 RFOC 11.976 RILM 7800.000 FT 2377.4450 M 1/.,+.778 141.411 0.073 75.319 ~.=73 .., 13.873 14C.635 0.097 ~4.026 1,3.268 15.473 140.127 C.032 57.573 9.912 139.911 0.158 15.232 14.744 1391724 0.020 41.29a 31,38g 14.~12 139,205 C.314 43,214 23.130 13.187 13~.738 C .0~2 34.347 14.741 13.754 1~8¢ . 141 0.170 59.799 13.311 SSN TTEN CN CALl RILD SSN TTEN CN CALl RILD SSN TTEN CN C,~L1 RILB SSN TTEN CN C;~L1 RILD SSN TTEN CN ~'~AL1 ~!L~ SSN TTEN ~N C:.L1 ~ZLD SSN TTEN CN C~L1 RILD SSN TTEN CN CALl RILD 153.58& 4703.027 59.t15 12.a29 9.681 170.562 ~731 .711 2.9.~80 12.177 10.1~6 157.744 4607.355 31.172 9.691 204.50~ ~451 24.230 9.~54 14,1~4 312.045 4410.46~ 10.015 11.531 24.030 262.124 4303.!33 18.876 10.736 20.733 224.0~5 4304.363 17.780 10.096 10.259 156.031 4231.770 24.955 12.303 12.607 12 _SN 0.8 6 GR SPD q2_ .~q4~ unSN '-NC 23.570 SP ~C 0.172 RFOC 37,644 2,318 51,873 17,649 TEMP 137,565 TTEN CORR -C,043 CN GR1 42,732 C~.L1 :LM 1 4,871 RiLD 41 3C, 075 ].3 19,570 12,163 10,985 3EPTH 7700.C03 FT 2246.9~50 !4 SSD 456,342 LSD 293.799 LSN ?? All G~ ~ ~21 ~ --I ~ ~ · .',, SPD 2~,~97 DEN 2,513 ~NC ~3 ~5.~ ~ ~2 82~ ~C 0,172 R=OC 10,264 3E~TH 7500,~C~ FT _ 1~. ~n CAL TEMP CORR RILM 20,553 SSN 135,548 TTEN 0,~.2~.. CN 73,547 CALl 13,026 RILD 204,120 4170,973 29,368 14,205 13,187 3S0 3~2.163 LS3 123,123 SN 5¢.$62 G~ 0! .73-~ SPD 20,409 DEN 2,62~ CNC 34. 20~ S~ P~,. ~x~.~ AC 0,172 RFOC 7.9~'2 3ESTH 7500.000 FT 22~6... .00~r¢~ M S,SD 35~.£67~ L~3~ 10~, _,.~7~ SN 6~ C41 GR ~ ~74 SPD 2~,7¢1 DEN 2.565 -NC 25,3n5~ SP ~$. .~nT. ~ ~C 0.1 7;: q;~C=, I ~.x55 .... C$L TF-"~ CORR GR1 RZLM C~L TEM= RiLM I '~.347 SSN 135,6.61 TTEN 3,t37 CN 90,25C C~L1 8,672 RTLD 15,753 SSN t35,703 TTEN 0,025 CN 74,12~ C$L1 21,654 RILD 208,~42 43~5.9B6 30,208 12,114 212,~09 3952,371 21,305 10.905 20,0-~7 5SD $C?,351 LSO SNC 37.042 SP ~C ~-.~ 17~ ~FOC 61 .~73 2,5~2 7,~95 C~L GRI RiL" 15.94~ SSN 1~A.7C8 TTEN ~ 0~7 ~N ~,.,.~ ..... C~~ 7,773 RiLD 2~7.303 3335.9;5 33,047 12.012 7.726 DEPTH 7300.C,30 FT 2225.04~C iq SSD ~70.57~ i qq SPD 25,791 DEN CNC 27,543 S¢ ~C 0.172 RFOC 231,142 52,~69 2,434 78.263 12.494 DEPTH 7200.CC0 FT 2194.5640, M CAL T~MP C~ RILM 16,091 SSN 134,153 TTEN ~' 01 ~ CN 62.507 C~L1 1~,~6~ ~ILD 209,159 375~,335 23,543 12.2~2 9.851 SSO 396,655 LSD LSN 77.323 GR SPD 27.077 DEN CNC 29.400 SP AC 0.172 RFOC ~26,441 2,562 107,663 10.106 3:PTH 7100.CC0 FT 2164.0840 IiIIIIIiIIIlIIIIIIilIIlIIlIIII SSD 433.585 LSD 29 LSN 81,465 GR 5 SPD 27,360 DEN ,3NC 26.058 SP 8 AC 0,172 RFOC I M 8,898 2,995 2,401 1,881 2,336 CAL TEMP CORR _ GR1 RILM C&L TEMP CORR GR1 RILM 17,~35 SSN 133,519 TTEN 0,074 CN 79,916 CALl 13,428 RiLD 14.806 SSN 132,861 TTEN 0.090 CN 52,462 CALl 13,435 RILD 246.786 3:,$15,325 25.400 10,041 13,399 225,6~8 3532,342 22,058 10,874 12,870 DEPTH 7000.000 =T 2133.6040 M SSD 369,253 LSD 21 LSN 54,826 GR 8 9,952 6,694 ~ ~0 CAL TEMP 15,966 SSN 132,241 TTEN 187,190 3586,021 . NC 30.475 SP 10~.444 GR1 C 0.17'2 RFOC 10.022 RILM :PTH 6900.000 FT 2103.1240 M SD 383.766 LSD 226.854 CAL SN 58.381 GR 65.115 TEMP DD 28.300 DEN 2.530 CORR NC 34.957 Sp 117.073 GR1 C 0.172 RFOC 8.937 RiLM =PTH 6800,000 FT 2072,6440 M 3D 368.457 LSD 222.354 CAL SN 52.310 GR c3.431 TEXP DD 28.568 D~N 2.518 CORR '~C 34.610 $~ 121.687 '~ 0. 172 R=OC ~.~. 83 EPTH 6700.000 FT 2042.1640 SD 378.9~7 LSD 232.576 C&L SN 57.352 GR 56.753 TSNP PD 28.9~7 D~N 2.498 CORR NC 28.602 SP 12~.6~4 GR1 C 0.172 RFOC 7.237 RILM EPTrl 6500.000 PT 2011.684..'3 H SD 377.771 LSD 225.332 CAL SN 47.490 GR 62.265 TEF;P PO 28.997 DEN 2./,83 CORR NC 41.693 SP I 21 .9t 4 GR1 C 0.172 RFOC 5.77~ RZLM :PTH 6500.0 · m--mmmm, m mmmmm SD 422. ~SN 33. ~PD 29. "NC 63. C,O FT 1981.2040 M m i i I I i I i I I ! I ii i I -- I 563 LSD 305.163 C4L 625 GR 64.719 T~M~ 071 DEN 2.CC5 CORR 543 SP 114.220 G~I 172 RFOC 5.~10 RILM -EPTH 6400.000 FT 1950.7240 M .:,SD 410.901 LSD 278.83.8 CAL _SN 61.488 GR 38.926 TEMP ~D 29.258 DEN 2.512 CORR ~NC 24.760 5~ 12~ . 13 ,'3 GR1 · ,C 0.172 RFOC 6.127 RILM "EPTH 6300.000 FT 1920.2446 M ;SD 421.597 LSD 305.139 CAL .,SN 54.674 GR 39.595 TEMP $PD 29.750 DEN 2.314 CORR ~NC 32.~05 SP 126.301 GR1 ~C 0.172 RFOC 5.994 RILM ]EPTH 6200.000 FT 1889.7646 M $SD 478.079 LSD 'SN 47.031 GR SPD 29.953 DEN $NC 38.549 Sm 349.539 C~L 62.430 TEMP 2.445 CORR 121.871 GR1 87,420 g,988 16.571 131 .868 C.117 65.342 8.580 17.624 131.376 0.032 62.243 7.754 17,823 130.803 0.116 ~A 8,14 7,,375 17.664 130.278 ~.1~6 65.2~1 5 .7~,3 I? ~27 129.722 -0,073 ~3,7~6 8.379 17.640 t2~.675 0.164 43.8~2 6.052 16.919 128.987 -0.026 41 .741 6.8C5 15.683 128.472 0.178 61.478 · CALl R!LD S SN TTEN CN CALl RILD SSN ~TEN CN C~L1 RILC SSN TTEN CN C~L1 RILD SSN TTEN CN C~L1 RILO SSN TTEN CN CALl R!LD SSN TTEN CN C~.L1 RILD SSN TTEN CN CALl RILD SSN TTEN CN CALl DTI ~ 10.~08 10.~44 201.~66 3539.9~7 30.957 9.9B6 185.642 3~42.J63 30.6!0 g.390 8.317 1Q9.512 3345.$49 24.632 7.~45 7.238 177.950 3371.068 6.009 6.250 153.192 3380,834 ~.471 1E6.527 3231.30~ 20.760 7.592 6.310 183.414 3209.234 28.905 7.622 7.296 165.237 3248.125 34.549 6.954 14 DEPTH 6100.CC0 FT !859.28fl0 M $SD 426.902 LSD Z;5.59~ LSN 35,324 GR 96.147 SPD 29.997 DEN 2.172 CNC 55.022 SP 117.544 40 0.172 RFOC 12.276 DmOTH 6COO C~O FT I~m~ eO&C M IIlIlIIlIlilIII/IIilI SSD 39~.391 LSD 27~.309 LSN 72.492 GR 4~.113 SPD 30.~57 DEN 2.433 CNC 21 .~50 5P 115.593 .DEPTH 59C0.CC~ r-T 17-$~,32~C M SSD 621.5~2 LS3 LSN 21.;77 GR 3~.~97 SPD ~0.~5 D=N 1.63~ CNC 5~,670 S? 131.~2~ AC 0.172 D--~TH,- 5800,~rc~ FT 1707. ,..~44r:. M $SD 3~6.407 LSD 255.028 LSN 57.814 GR SPD 2~ 8°4 ~'.' ~ S~C 32, C~9 S~ 1 3~, ~C 0,172 ~FOC 6,~67 OSmTH_. 5700.000 FT 1~7,_, llilllliilIIIllIllIIlIiilIIlII SSD 381 .250 LSD 235 .~6~ LSN 46,547 GR 74,11~ SPD 30,052 DEN CNC 33.187 S~ 143.34~ &C O. 1 ~2 RFOC 9. 101 OSmTH 5500, nnO I I ! ! I i I i ! I i ! I I i I i I ! 5SD 381 .570 LSD 233.101 LSN 60.857 GR 75.6/'5 SPD 30,361 DEN 2,474 ,~NC ~2.4,~7 SP 142.794 ~C 0 1~2 . , ~ r . ,19 ]EPTH 5500.CC0 FT 1676.~03C M IIIlIIi ill iIll iii i ii! lllIiliII $SD 435.695 LSD 2~30.135 LSN 5Z*.258 GR 77.624 SPD 30,894 DEN CNC 34,3.00 S~ 147,343 &C 0,172 RFOC 9,2~1 DEPTH~400.000 FT 16~5.9P30_ M SSD 381.713 LSD LSN 65.225 GR SPD 31.567 3~N CNC 27.499 SP AC 0.172 RFOC 252.292 45,803 2.3~9 123.403 , .u36 CAL TEMP OR1 ~iL~ CaL TEMm CORR GR1 PlLM C.AL TEMP C'OR~ R ILM ~AL TEMP COR~ RILM C~L T~P RILM CAL TEMP CORR GR1 I C~L T~MP CORR GR1 RILM CAL TEMP CORR SR1 RZLM 15.077 127.851 ~.075 94.228 11.086 13.8~8 127.253 0,012 44,450 1~ 1'~2 15.793 126 ~,2~ -0.077 54.30C 14.325 17,747 125,351 5,3.697 7,7CI 125.813 C.253 ~2,751 12,244 1 S .446 125.152 0.162 18.292 124.669 C.138 75 3~ 5 11.691 19.088 123.989 0,018 4~.419 10.795 SSN TTEN CN C~L1 RILD SSN TTEN CN C~L1 RILD SSN TTEN CN C~L1 ~LD SSN TTEN CN C$L1 R!LD SSN TTEN SN C~L1 RILD SSN TTEN CN C~L1 ~iLC SSN TTEN CN C~L1 RiLD SSN TTEN CN CALl RILD 145.643 31~3.673 51.022 7.702 14.297 215.456 3070.122 17.650 6.732 14.i25 117.370 2?70.363 54.670 7.662 13.6~3 I 90 o .3 '* 2990.835 28.099 6.5~1 ¢ 141 ' m 176.~58 299.o.715 29.137 5.411 12.469 200.~54 2935.160 28.477 5.665 9.373 176.639 2838.757 30 .'300 6.339 13.825 211.910 2729.572 ~ 49~ 5.273 11.876 15 $2 369.1 09 LSD 206. 338 CAL 20,082 3N 67.$22 GR 57.9c. 5 T-:MP 123.~,a4 PD 3~.241 D~N 2.465 CORR 0.1 20 NC 39.~94 SP 130.064 GR1 65.068 ~ 0.172 R=OC 6.~46 RILM 6. ~59 =PTH 5209.£00 FT 1584.9630 M SD 383.552 LSD 239.659 CAL 20.107 SN 55.101 GR 74.353 TEMP 122.726 ~O 29.747 DEN 2.500 CORR 0.079 NC 31.601 SP 128.207 GR1 77.320 C 0.172 R=OC 9.424 RILM 9.477 ~PTH 5100.CC0 FT 1554.4830 N SD 387.990 LSD 249.652 C~L 19.654 SN 57.6~2 OR 61.334 TEMP 12Z.237 mD 30.003 DEN 2.4~5 CORR 0.094 NC 39.169 SP 134.010 GRt 63.6.14 C 0.172 R~OC 0.3,25 RILM 6.701 EPTH 5000.000 FT 15Zc.0030 ~ mmmmmmmmmmm--mm~ SD 423.109 LS3 2~S.07~ C~L 17.874 SN 66.~16 GR 35.862 TEM~ 122.003 ~D ~ 9~ D;N 2 ~5~ ~O~R C 095 ~ 0.172 R=3C ~.9~3 ~':LM 7.770 ~PTH 4890.009 ~T 1453.043'3 M SD 3~7,.$~:~ LS3 ~25. .0133 C&L 1~.516 SN 109.379 GR n6.1~5 TENP 120.617 ~D 30.29~ DSN 2.471 'ORR 0.062 NC 33.1:5 SP 158.772 GR1 ~2.530 C 0.172 RFOC 11.509 RILM 14.375 ==TH 4700.000 FT 1432.553C M SD 334.922 LSD 1~8.72e CAL 14,626 SN 262.636 GR 32.~53 T=MP 12C.504 PD 31.027 DEN 2.683 CORR 0.079 NC 1Z,005 S? 166.3~0 SR1 36.546 C 0.172 RFOO 44.403 RILM 5~.315 EPTH 4600.000 FT 1402.0830 M ;SD 405,218 LSD 233.748 C~L 19.790 ,SN 90.660 GR 45.494 TEMP 120.188 .}PD 31 .214 DEN 2.721 CORR 0.163 'NC 23.831 S~ 166.199 GR1 52.2~9 ,C 0.172 RFOC 17.922 RILM 18.940 'iEPTH 4500.000 FT 1371.6030 M SSN TTEN CN CALl RILD SSN TTEN CN CALl RILD SSN TTEN CN C~IL1 RILD SSN TTEN CN C&L1 RILD SSN TTEN CN C~L1 RILD SSN TTEN CN C~L1 RILD SSN TTEN CN C&L1 RILD SSN TTEN CN CALl RILD 234.451 2699.882 35.0~4 5.169 7.236 189.203 2615.717 27.601 4.959 10.468 193.425 2535.724 35.169 5.0~2 7.302 Z05.51~ 2535.083 22.~57 5.797 S.088 235.215 ~466.177 1' ~ I ~' 5.045 11.966 296.610 2451 .712 29.155 4.677 14.755 407.671 2351 .478 8.005 5.583 46.507 ,~44.728 2316.023 19.831 4.932 16.431 16 LSN 66,585 GR SPD 31.826 DEN SNC 33.874 SP AC 0.172 RFOC 2.465 164.061 12.317 DEPTH 4400.C00 FT 1341.1230 M SSD 420,215 LSD LSN 57.473 GR SPD 31.129 DEN CNC 28,334 SP AC 0.172 RFOC 2§1,365 59.627 2,445 196,116 12.722 3EPTH 4300.C00 F'T 1310.643C M SSD 433.~23 LSD LSN 36.129 GR SPD 31,821 DEN CNC 42,207 SP aC 0,172 R:OC 293.567 63,.795 2.335 203.7(~7 7.292 DEPTH 4200.CC0 FT 1280.1630 SSD 468.022 LSD LSN 36.380 GR SPD 31,997 DEN CNC 32,473 SP dC 0.172 RFOC 337.131 52 2.434 2O4.465 7.550 DEPTH 4100.CC0 FT 12~9.6830 M SS] 471.495 LSD LSN 28.492 GR SPD 32,420 DEN CNC 36.681 SP ~C 0.172 R=OC 416.707 50.933 2.~51 226.625 9.747 DEPTH 4000.000 FT 1219.2020 M SSO 441.014 LSD LSN 57.121 GR SPD 32.404 DEN CNC 31.805 SP ~C 0.172 ~FOC 34~.~33 3~.670 2.272 230.806 7.~92 DEPTH 3900.000 FT 115~.7220 N SSD 403.423 LSD 231.4C5 LSN 50.7~1 GR 53.401 SPD 32.~81 DEN 2.429 CNg 33,684 SP 227,8~2 hC 0.172 RFOC 13,774 OEPTH 3800.000 ~'T 1155.242C M mmmmmmmmmmmm--m mmmmm# SSD 439.103 LSD 328,059 LSN 35.278 GR 00.251 SPD 28,997 DEN 2,262 CNC 46.962 SP 221 .297 AC 0.172 RFOC 9,892 DEPTH 3700,000 FT 1127.7620 M SSO 430.297 LSD LSN 42,133 GR 290.991 60.679 TEMD CORR GR1 RiLM C~L TEMP CORR GR1 RILM C~L CORR GR1 RILM CAL TEMm CORR GR1 RZLM C~L T:MP CORR GR1 RiLM CAL TEHP CORR GR1 RiLM C~L TEMP ~ORR GR1 RILM CAL TEMP CORR GR1 RILM C~L TEMP .. 119' ~21 0.079 65. 5"9u 11.67,1 16.221 119.507 C.097 5R.$91 15.192 11g.27~ 0.120 66.085 7.928 ~C.1;,.,""~ 11~.67~ C.180 58.313 7,861 20.5E6 117.936 5~,53f !3.66.3 ~ 4~3 117.1~6 C.065 ~2.912 9,944 2'3. 640 115.763 0.055 54.369 17.607 20.678 116.444 0.037 59.928 8,956 20.732 116.047 TTEN CN C~L1 RILD SSN TTEN CN C~L1 RZLD SSN TTEN CN C~L1 mILD S~.N TTEN CN CALl RIL3 SSN TTEN CN C~L1 RZLD SSN TTEN CN CaLl R!LD SSN TTEN CN CALl RILD SSN TTEN CN C~L1 RILD SSN TTEN 2169 9 29. 874 4.970 1 3.6,39 198,443 2360,476 24,334 5.962 14,372 146.703 2154.077 38.207 7.519 10.12~ 141 .714 8123.202 28. ~,73 8.797 8.505 135.832 2,335. 597 '~2. c,~I 10.251 14. ~-76 178.435 2032.520 27.505 10.683 t0.95S 174.017 2308.875 29.684 10.326 18.300 150.829 1968,082 42.962 12.24~ 11.297 145.252 1951 .438 -41 1'7 NC 3=~..'~92 SP 230. 344 S (].172 RFOC 8.389 OR1 R ILM EPTH 3600.000 F-T 1097.2520 SD 3E'2,753 LSD 262,202 SN 50.7.~1 GR 53.691 ~O 27.871 DEN 2.523 NC 31.758 SP 235.125 C 0.172 RFOC 13.917 PAL TEMm CORR OR1 R:LM EPTH zSO~ ~ ~-,gSO FT 1066,8020 M SD 110.9~9 LSD 05,993 SN 19.133 G~ 30.656 PD 24.9~'~ DEN 1.954 NC 55.164 Sm 107.~2~ ~C C.172 R$OS C~L TEMP RILM -:PTH ~456., .500 ,:T 1053.5436 'SD 110,98'9 LSD .SN 22,998 GR PD 24,99~ CEN 'NC 56,117 S~ ~C 0.172 RFOC 65.9~3 C&L 25.330 TEMP !.9~8 CORR 11~.10~ GR1 0.677 R!LM T~RTING D:PTH :1G064.000 FT :NDiNG DEPTH = 3455.500 ~T 3067.5130 1053.5430 6 .2~2 ~.814 1.8.586 115.654 0.067 60.570 13.856 12,717 115,407 -1,124 ~2.~.69 10000.000 12.717 115.451 -1.124 28.792 1 0CCi]. C~L1 RILO SSN TTEN CN C~L1 RILD SSN TTEN CN C~L1 RILC SSN TTEN CN C~L1 RILO 1,0 9.683 1~7.~3,5 1912.674 27.758 9.074 15.&16 107,869 1854,215 61,164 10,232 1C000,000 112,~$9 1~54,215 52,117 9,603 10000,000 18 "* FILE T~a, ILE~ ** :-iLE N~ME: ~$ZN .002 SERVICE N~ME: /ERSION $ : 1 3~TE: S5/11/ ',!~ X I MUM LENGTH: 1024 ;iLE TYPE: LO ;WEXT FZLE NAME: ** =ILE HE~SE =ILE NAME: RE SERVICE NA~E: VERSION ~ : 1 2ATE: 55/11/? MAX RECORD LE :iLE TYPE: LO :REVIOUS FILE ~* INFORMAT "03 m ~.~ 0 NGTH: 1024 NAM E: I~N~ RECORDS ** MNEM CN W,N FN COUN STAT LCC CONTENTS : AMOCO PROD, CO, : GP 18742 N0.38 : GRANITE POINT : KEN~I : ~K : 150.00 ** FORMAT ** BYTES UNITS TYPE ENTRY DESCRIPTION 4 I CEPTMS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 21 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEL SPACING OATUM SPECIFICATION BLOCKS CURVE REPR N&ME CODE SIZ: SAMPLE UNITS -ILO 68 4 I MMHO ~R 6~ 4 1 AP1 TTEN 68 & I LBF ~C~ 68 4 I DIM RFOC 68 4 I O~MM qlLD 88 4 I OMMM ** FORMAT ** CURVE REPR NAME CODE SIZE SAMPLE Sm 55 C 1 C~L dS 4 1 SPD 68 ~ 1 AC 58 4 1 RILM 68 4 1 UNITS MV IN m/MN US/F OPMM 19 ENTRY BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTHS DECREASE 8 6~.0 F~AME SPACING 9 .1TN, ,;,R'~, _ Sm-~rZN.r-: ~ .~ UNITS 11 21 MAXIMUM =~AMES/RECDRD 0 TERMINATOR -0.500 LEVEL SP~CINS S~TUM SP$C!FZrATION ~'LnrKq CURVE REPR NA~E CODE SiZE S~MPLE UNITS l--Ii mII-- '-ILD 68 4 1 MMMO $R 68 4 1 ~PI TTEN 58 ~ I L~= zCQ 68 4 I DiM ~FOC 68 4 1 3HMM ~iLD 65 4 I OHMM DEPTH 10062.000 FT 3056.9040 M mmlmImmmlmlmmmimmmlmiimmmmmmII C!LD 64.974 SP 112.473 TTEN 3574.242 SPD 24.998 qFOC 17.275 RiLM 15.274 DEPTH lOO00.CCO FT 3048.0060 M IIIlIIlIIlIIlIlIlIIiIIlllllIIll CILD 69.07? SP 108.713 TTEN 5473.801 SmD 27.629 qFOC 16.283 RILM 15.~42 DEPTH 9900.C00 FT 3017.5260 M 'ILO 51.458 SP · 106.807 CURVE REPR N~ME CSC. E SIZE mmmI SP 68 4 CAL 6B 4 SPD ~ 4 .~C ~ & 4 R!LM 68 4 GR ACQ R!LO GR ACQ R!LD GR 74.628 0.000 15.391 65.968 0.000 14.477 36.690 CAL AC CAL' CAL SAMmLE 1 1 1 1 1 UNITS NV iN US/; OHMM I 2. 846 0.172 12.574 0.172 16.416 . >,FOC 28.835 RILM 22.~01 R!LD 2]PTH 9800.000 ~T 2987.04~0 H CILO 183.486 SP 105.557 TTEN 5385.273 SRO 27.871 ~FOC 5.152 RILM 5.295 GR R!LD 3E~TH 9742.500 FT 2969.5200 M --m----m--mmmmmmmmmmmmm. 'iLD 189.247 SP 105.275 TTEN 5416.262 SPD 27.997 ~FOC 5.590 RILM 5.712 GR ACQ R ~ ,,LO -TARTING DEPTH :10062,000 ~T 3065.9040 M :NDING DEPTH : 9742,500 FT 2¢69.5200 M 1947.~ 40.498 O.O00 5.450 27.816 C.O00 5.284 CAL ~C C~L AC 13.070 0.172 12.496 0.172 2O ~* FILE TRAILER ** :ILE NAME: REPT .003 SERVICE NAME: VERSION ~ : 1 DATE: ~5/11/ 'qAXiMUM LENGTH: 1024 =iLE TYPE: LC NEXT FILE NAME: ** FILE HE&DER # 4 ** =ILE N~ME: REPT .004 SERVICE NAME: '¢ERSICN ~ : ! DATE: ~5/11/20 ~AX RECO~D LENGTH: ~IL~ TYPE: LO PREVICUS ~ILE NAME: 1024, BYTES INFORMATION RECORDS ** MNEM CONTENTS CN : AMOCO PROD, CO. WN : GP lmT42l- NO. 3 FN : GRANITE POINT COUN : KEN~Z STAT : AK LCC : 1SO.JO ** FORMAT ** UNZTS ENTRY BLOCKS TYPE ~NTRY C 1 8 60.0 9 .liN 11 18 0 -0.500 DESCRIPTION lImImmmimmmmimtmImi DEPTHS DECREASE FRAM~ SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING DATUM SPEC!FIC~TION BLOCKS ~ME CODE SIZE SAMPLE UNITS SD 68 4 I CPS aL 68 4 1 ZN SN 68 4 t CPS EMP 68 4 I gEGF aD 68 4 1 F/MN ORR 68 4 I G/C3 NC 68 4 1 % * FORMAT NAME CODE SIZE -- ~,, I m Ii.i.m LSD 68 4 SSN 68 4 GR 68 4 TTEN 68 4 DEN 65 4 CN 68 4 SAMPLE 1 1 1 1 1 1 UNITS wmmmm CPS CpS ApI LBF G/C3 % 21 ENTRY YPE ENTRY ~ESCRiPTION III IIIImIIIiIlI--I--IIII 4 1 DEPTHS DECRE&SE 8 60.0 FRAME SPACING 9 .lIN =RA~E SPACING UNITS 11 18 MAXIMUM FRAMES/RECORD 0 TERN!N~TOR -0,500 L=VEL S=ACING ~TUM SPECir--ZC&TTON. ~LO~KS..., .~ URVE REmR .~ME COD: SIZE SAMPLE UNITS IIiI lmlI IIIII SD 68 4 I CPS AL 68 4 1 IN .SN 68 4 1 C~S '=MP 68 4 1 DEGF PD 68 4 1 F/MN ORR 68 4 I G/C3 'NC 68 4 1 DATA =PTH 10074.000 ST 3070.5620 M SD 472.953 LSD .SN ~5.903 GR iPD ~8.907 D~N :NC 19.000 399.960 o~ 71~ 2.500 EPTH lO~nn . . ~ . uu~,.O00 FT 3n48 O06u M )SD 372.871 LSD ,.SN 48.107 GR ~PD 29.397 DEN 'NC 36.636 214.158 77.381 2.111 'EPTH 9900.C0 . I ! I I ! I I I I I I ! I ~SD 460.9 _SN 41.5 SPD 29.4 'NC 57.5 0 FT 301 7. 5260 M 99 LSD 313.709 85 GR 39.264 41 DEN I .496 26 3EPTH 9800.000 FT tmIIIIIIIIIIIiII ~SO 416.70B _SN 79.696 SPD 29.644 2987.0460 M LSD GR DEN 272.083 40.855 2.424 CURVE REPR NAME CCDE SIZE Iiii --Ii! LSD 68 4 SSN 68 4 GR 68 4 TTEN 68 4 DEN 65 4 CN 68 4 CAL TEMm CORR CAL TEMP _CORR CAL TEMP CORR CAL TEMP CORR · 5.858 147.185 ,~ .000 lC.035 147.310 0.206 20.697 147.698 0.036 14.000 147.469 0,053 . .. SAMPLE 1 1 1 1 1 1 SSN TTEN CN SSN TT:N~ CN SSN TT~N CN SSN TTEN CN UNITS CPS CmS LLF G/C3 188.981 3257.075 15.000 163.005 5729.113 32.036 160.869 5566.859 53.526 217.887 5521.96Q 24.g64 .) "~TH 9738.500 FT 2968.3010 M ~D 375. 962 LSD 244.'~75 -N 88.991 GR 42.217 ~D 29.997 DEN 2.408 JC 22.146 C~,L TEMP CORR TARTING DEPTH :10074.000 FT WOING DEPTH : 9738.500 FT 3070.5620 M 2968.3010 M FILE TRAILER ** ZLE NAME: REPT .004 -].~VICE NAME: ~RSION N : 1 ~TE: 35/11/ ~XIMUM LENGTH: 1024 ZLE TYPE: LO ~XT FZLE NAME: 14.799 147.285 0.015 SSN TTEN CN 226.977 5489.453 18.146 22 , TAPE TRAILER ** ~PE NAME: ~RVICE NAME: REPT ~TE: R!GIN OF DATA: FSYS APE CONTINUATION # : 01 5XT TAPE NAME: OMME~TS: ~ REEL TRAILER EEL NAME: ~ERVICE NAME: B!TLIS AT~ · q~GIN~ 0:, DATA: ~SYS EEL CONTINUATION # : 01 ~EXT REEL NA~E: 'OMMENTS: DR=SSER ATLAS LIS CUSTOMER T~P~ --- CREATED BY SCS PROGraM ~ 2.0 ~EL HE~DER - 1 ~APE HmADER - 1 -ILE H:ADSR - 4 'NFORMATION - 4 :ORMAT - ~ .)~T:~ - 1802 TABLE DUMP - 4 ':T'E.- TRAZLER - 4 T~P~ TRAIL:R~ - 1 ~EEL TRAILER - I 'TOTAL RECORDS: 1830