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Home My WebLink About168-083 • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 b -ms1 ) `s - S Q Mobile 907 223 0128 ! `l Fax 907 263 7897 n %0--0 Email jzager @chevron.com --05_ 14Cs -` -V November 16, 2011 V _�� c -O' — \y \ NOV I' 7 ?i) -'a l ,S0 -- �� s Oil GEC �® ° UIC Manager t iChrb 9Ss p® Thor Cutler, OCE -082 ' ` b � U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 „ 6 4t Seattle, WA 98101 ' " ` Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I iniection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 UIC Manager US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivan(@chevron.com or 263 -7685. I Regards L John ager i Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of2 • • OMB No. 2040 -0042 Approvel Expires 12/31/2011 i United States Environmental Protection Agency 4 i EPA Washington, DC 20460 Application To Transfer Permit Name and Address of Existing Permlttee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat • 640 Acres N Surface Location Description 17 tt 1 t 1 4 II I , SC 114 of ne 1/4 of SW 1/4 of 5W 1/4 of Section j_ Township $n Range 13w - .4 --1^- --F - - 4 - t- -I- -- Locate well in two directions from nearest lines of quarter section and drifting unit I Surface -- r - r - - - - - 4 - I-4 - - - I-4 - I Location 754 f1:. frm (NIS) S Line of quarter section 1 I I 1 I I I 1 and jl Vt. from (E!W) w Line of quarter section. w j 1 I I 1 I I Well Activity Well Status Type of Permit 1 - - �' - - ` X Class I X Operating _. Individual I I I -r -T I I I I - r 1 - - r -, r Modification/Conversion - r - _ _ Class 11 _�_ Area R I 11 Brine Disposal �c Proposed Number of Wells ' 1 — --t 21-4 — - - -I- --I- - t _ Enhanced Recovery I I I I I I i ____ Hydrocarbon Storage S — Class Ill Other Leas. Number See Attached Well Number See Attached Name(s) and Addresses) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; . Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. • Certification 1 certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those Individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and Imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please typo or print) Signature Date Signed John Lager, General Manager 11/15/2011 EPA Fonn 7520 -7 (Rev. 12 -08) • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class 1 wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9RD 50- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 - 974 FNL/ 531 FWL 33 9N 13W M -30 50 -733- 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50 -733- 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 11006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 1I006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. Agreement to Transfer UIC Permit No. AK-11 006-A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 11006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK- 17006 -A 1 • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263-7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK -1 1006 -A • . 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer UIC Permit No. AK- 1I006 -A • • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By: 1! ..�.. a By: o- ---- -- Name: V Z cr Name: -la -r., 4 4tA•S• Its: __ uh f-ey' -i r - « 1` Its: V 1 Date: ___.th i. t a+ '�c '(( Date: N °V 1S 1 2 _o 1 1 5 Agreement to Transfer UIC Permit No. AK- 11006 -A Regg, James B (DOA) From: Regg, James B (DOA) ~`'~~ /~ Sent: Wednesday, December 26, 2007.5:23 PM t To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA) Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys ~2 Larry -Each of the listed admin approvals did not establish a forma! anniversary date for determining when to perform compliance temperature surveys. There has been same confusion that has resulted. Based on what I have read below and our conversation earlier today, !believe using the effective date (signature date} of the administrative approvals is consistent with your request for nearly all veils accomplishes what you are after (efficiency}. The wells you reference below are (with a due date for the next temp survey}: Granite Pt State (Anna) 19 - AIO 6.008 (3/29/2005); next temp survey due 3/29/2009 Granite Pt State (Anna) 21 - AIO 6.009 (3/29/2005}; next temp survey due 3/29/2009 T8U G-11 - Ai0 5.009 (12/15/05); next temp survey due 12115/2009 ,ya=p suggested 9;2009} TBU G-22 - AIO 5.006 (9/14/2005); next temp survey due 9/14/2009 TBU G-23RD - AIO 5.004 (6/30/2005); next temp survey due 6/3012009 ;yo~~ suggested 3/2009] TBU G-27 - AIO 5.003 (3!29!2005}; next temp survey due 3/29/2009 TBU G-29RD - AIO 5.007 (9123/2005); next temp survey due 9/23/2009 TBU G-40 - AIO 5.002 (3/29!2005}; next temp survey due 3129/2009 TBU K-11 - A10 5.011 (2/6/06); next temp survey due 2/6!2010 TBU K-24RD2 - A(O 5.010 (2/6/06}; next temp survey due 2/6/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells). This does not affect any admin approvals that have anniversary dates specifically listed in the conditions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~, ~~C ~ ~ 2007 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing for me to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3!29x`05 -last compliance temp survey 10x3!06. ~f~louid like to slide 10108 temp survey to 3!09 to get an AA anniversary date cycle, An-21 - AA signed 3129x`05 -fast compliance temp survey 1014100. Would like to slide 10108 temp survey to 3!09 for the AA date reason. K-11 - AA signed 216;0E -last compliance temp survey 12111!07 lust seat to you}. Would like to slide 12109 temp survey to 2110 for the AA date reason. 12/26/2007 K-24RD2 - AA signed 216106 -last compliance temp se.~rvey 12121;07 ~wtili send to you soon}. Would like to slide 12f09 temp survey to 2110 for the AA date reason. The Grayling wells have some other things going on. We have wells with AA anniversary dates in every quarter. i sure wou{d like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RD forward from June to March and G-11 forward from December to September. This way only two wells get off the AA anniversary date cycle and we'll have three wells due for temp surveys each visit. G-11 - AA signed 12f15/05 -last compliance temp survey 6/25r"07. Would like to slide to 6109 temp survey to 09;09 for efficiency. G-22 - AA signed 9f14105 -last compliance temp survey 4126!07. Wound like to slide 4;09 temp survey to 9109 for the AA date reason. G-23RD - RA signed 6130105 -last compliance Temp survey 4/19107. Would like to slide 4109 temp survey to 3/09 for efficiency. G-27 - AA signed 3129;05 -last compliance temp survey 9121106. Would like to slide 9108 temp survey to 3/09 for the AA date reason. G-29RD - AA signed 9f23i05 -last oompNance temp survey 6;24!07. Would like to slide 6,'09 temp survey to 9J09 for AA date reason. G-40 - AA signed 3!29!05 -last compliance temp survey 9{21x'06. Would like to slide 9108 temp survey to 3109 for AA date reason. I hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. Larry 263-7661 12/26/2007 ----, ~~~~~~i' l~~~L~~~ 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these wells did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L. Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. Options Next Temp Survey Due, Based on AA Date1 AA Date2 Last Survey 3/29/2007 3/29/2009 10/3/2008 3/29/2007 3!29/2009 10/4/2008 12/15/2007 12/15/2009 6/25/2009 9/14/2007 9/14/2009 4/26/2009 6/30/2007 6/30/2009 4/19/2009 3/29/2007 3/29/2009 9/21/2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2/6/2010 12/11/2009 216/2008 2!6!2010 12/21/2009 last update: 12/26/2007 Well PTD AA Anniversary Date AA Date Last Surve GP State An-19 168-006 6.008 3/29/2005 10/3/2006 GP State An-21 176-049 6.009 3/29/2005 10/4/2006 TBU G-11 168-043 5.009 12/15/2005 6/25/2007 TBU G-22 175-016 5.006 9/14/2005 4/26/2007 TBU G-23RD 179-014 5.004 6/30/2005 4/1912007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2!6/2006 12/21/2007 Next Survey Due (Chevron Proposed) Next Survey Due (AOGCG) Which. -0ption? 3/29/2009 3/29!2009 AA Date 3/29/2009 3/29/2009 AA Date. 9/30!2009 12/15!2009 AA Date 9/30/2009 9/14/2009 AA Date 3/30/2009 6/3012009 AA Date 3/30/2009 3/29/2009 AA Date 9/30/2009 9/23/2009 AA Date 3/30/2009 3/29/2008 AA Date 212$/2010 2/6/2010 AA Date 2128/2010 21612010 AA Date GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) King Salmon Platform Well No. ~ Injector AIO Administrative Approv~AIO 5.011 - Compl... Page 1 of 1 Regg, James B (DOA) From: KRAMER, TED E [TED.KRAMER@chevron.com] ~ ~~'~`,~.~ Sent: Thursday, December 20, 2007 8:42 AM ~~1~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Johnson, Wayne E ~. Subject: King Salmon Platform Well No. K-11 Injector AIO Administrative Approval AIO 5.011 -Compliance Temp Survey Attachments: Compliance Temp Survey 2007.zip ]irrt Tom, A compliance temp survey was conducted for King Salmon well numbewr K-11, IO 5 {PTD 168-1383) on . , 11/07. The previous compliance temp survey vvs conducted on 12/21/05. The attache temp plots ~ and TVD) contains overlays of the test two to perature surveys '~'" for K-11 (12/11/07 and 12/2./05). These two surveys are al ost a perfect rnatch in shape with the 12/11/07 survey being slightly cooper than the 12/21/05 survey. This is nrtost likely due to a slightly shorter a aunt v" of SI tune prier to rennin the 12/11/07 survey. oth surveys indicate do n hole containment of the injected fluid ith all fluid gout into the ~,,.. laerforated intervals. Please call a to discuss if you have any questions. ~~~ ~ ~}~,~ ~ ~ .~od~ Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7960 Cell 907-382-0059 Fax 907 263 7847 ted.kramer@chevron.com «Compliance Temp Survey 2007.zip» 12/20/2007 • Chevron Well: K-11 Field: King Salmon 12!11/2007 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 :-- .::- _ Pressure-Temaerature Profile 1000 - :_- 1. Going in hole _ - ----- 2. Well Shut-In --._... 2000 -..--__-_-_ _ 1 _ _. _. 3000 _ __ ._- - _ ._. _...... - -. _ _ - -.} - ._..__._.._........L_....`-_........_---_.-......__........._-_____.-......._........__......._...-....__.._..._-__...------ -___.. 4000 ____........_ --_._......._ ....................._....._---...............___.._............_........ _ ............. 5000 - _ _ _ ._ -- - ~ ._ _ ~ w _ ._ ... .... _ v - -- - - - r-- -- _. D _. _ 6000 _ _.._ _. _ _ a ,. _ - _ _ __ m ~- _- -_ p 7000 - - - -- - - - soon __- --..._.._ ... _._ __ - - -- - __ _ - 9000 - _......- - -----------r ___.___.... - ----..._....._ ...... _ ._.... _ .. _._ _ _ i ---- --- - 10000 - - _.._...._ f..__ _ __ .................. _.....- 11000 --~ - _ - __ - _. - -I - ~ ---- -~__ -_- -_ - 12000 ~ 50 60 70 80 90 100 110 120 Temperature (Deg. F) 12-11-07 Pressure - Perfs 13-3/8" 9-5/8" ---- TBG" 12-11-07 Temp 12-21-05 Temp 0 • • Well: K-11 Field: King Salmon 12/11/2007 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 1000 2000 3000 4000 ~. 5000 D H +_.+ 6000 Q 7000 ii i 8000 9000 10000 11000 ~~ ~ 50 60 70 80 90 100 110 120 Temperature (Deg. Fj 12-11-07 Pressure - Perfs 13-5/8 Casing 9-5/8 Casing TBG 12-11-07 Temp -12-21-05 Temp J i ~{ ~ ~ t ~ ' I~ ~ i ~ ~ :~ i ~ ~, r j 1 AI.ASSA ®Il, A1QD GAS C®lYS~R~AaI®1~T C®rii•IISSI®~ ADMINISTRATIVE APPROVAL AIO x.011 1VIr. Hal IVlartin Optimization Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 333 W. 7TM AVENUE, SUITE 100 ANC!-IORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~a~~ JAN 4 ~ 200 RE: TBU K-11 (PTD 168-083) Request for Administrative Approval Dear Mr. 'Martin: Per Rule 9 of Area Injection Order 5, the Alaska Oil and Gas Conservation Commission ("AOGCC") hereby grants Unocal Alaska ("Unocal")'s January 24, 2006 request for administrative approval to inject water in Trading Say Unit ("TBU") K-11. Unocal notified the Commission on August 1, 2005 that TBU K-11 exhibits tubing- casing pressure communication; the well was shut in at that time. Approval to continue injection for the purpose of performing well integrity diagnostics was granted by sundry number 305-312 on October 13, 2005. Unocal has elected to perform no corrective action at this time on TBU K-11. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations and monitoring has shown that pressures are contained within the wellbore. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. The Commission's administrative approval to inject in TBU K-1 1 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record tubing, inner annulus, and outer annulus pressures and injection rate daily; FRANK H. MURKOWSKI, GOVERNOR 3. Unocal shall submit to the Commission a monthly report of well pressures and injection rates; • • ~1r. Steve Rossberg February 6, 2006 Page 2 of 2 4. Unocal shall perform a temperature survey every 2 years in lieu of the mechanical integrity test as outlined in Rule 5 of AIO ~ to demonstrate continued production casing integrity; Unocal shall immediately- .shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. after well shut in due to a change in the well's mechanical condition, Commission 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 considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. id dated February 6, 2006. athy P Foerster Commissioner "'ls~. ' l I 1 \ ` ~ ~~ t I "' ' ~ t- ~ ~ ~~ ~ ~ _, 1 ~ .~{ j ~ \ s , ~ V ~ " ^ ~~ . ~. 'O!,\; ) ) Chevron III J. Hal Martin Optimization Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907263 7847 Email martinh@chevron.com R',: ,E, C', E1 ~\fE', D' ¡ ,I ' ¡ ~ 'i~,: I,! January 24, 2006 .JAN 2 5 2006 Aias~Œ em & ¡Gas Cml$.. Gmnmjssåoó1J A«1lchorage Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 rLL:; \ ~'b" V<J Attn: Tom Maunder REQUEST FOR ADMINISTRATIVE APPROVAL UNDER AREA INJECTION ORDER 5 WELL NO. K-11 INJECTOR KING SALMON PLATFORM TRADING BAY UNIT McARTHUR RIVER FIELD ~CANNE\\) ~_~?j~N 3 1 2Güf1 Dear Tom: Union Oil Company of California requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for King Salmon Platform Well No. K-11 Injector (Permit # 1680830) in Trading Bay Unit, McArthur River Field. To support this request, Unocal submits the following information and documentation: 1. Form 10-404 (attached). 2. Schematic (attached). 3. MD and TVD plot of temperature surveys (attached). 4. Maximum allowable injection ,pressure calculation in graphical form (attached). 5. Brief/relevant well history (below). The King Salmon Platform Well No. K-11 was drilled and completed as an injector in 11/68 in Hemlock Benches (HB) 2-6. Workovers were conducted in 5/69 and 9/70. The well was shut-in in 3/87 due to tubing-to-casing communication. In 3/88, Well No. K-11 was worked over to repair the leak and HB-6 was squeezed (unsuccessful) and HB-1 was added. Well K-11 passed standard MITs in 4/92, 2/97, 12/01, and 7/05. On 8/1/05, a few weeks after passing an M'IT, Well K-11 was shut-in due to tubing-to-casing communication. In 10/05 (after running a baseline temperature survey on 8/3/05), Union Oil Company of California submitted a plan to restore waterflood injection to the AOGCC. Injection was restored from 10/15/05 until 12/20/05 when the well was shut-in for a follow-up temperature survey on 12/21/05. On 12/22/05, after Union Oil Company of California I A Chevron Company http://www.chevron.com ) ) Tom Maunder AOGCC January 24,2006 Page 2 reviewing the results of the follow-up temperature survey with the AOGCC and in consideration of process limitations on the King Salmon Platform, the AOGCC granted Union Oil Company of California permission to return K-11 to injection provided monitoring standards were maintained. As discussed with the AOGCC, the Union Oil Company of California does see any anomalous cooling on the temperature surveys betwe~n the surface a~d the Hemlock intervals of injection. As depicted on the attached maximum allowable operating pressure (MAOP) graph, the MAOP for K-11 is 2318 psi for the casing immediately outside of the tubing. Union Oil Company of California will operate this well within the MAOP. Union Oil Company of California will 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. Please note also that McArthur River Field has an aquifer exemption per EPA 40CFR147.102b2ii. Please call me at (907)263-7675 if you have any questions. Sincerely, d~/l;ttL - Hal Martin Optimization Engineer Union Oil Company of California JHM:jll Attachments Union Oil Company of California I A Chevron Company http://www.chevron.com "'1-\1'4 tJ V LUUO STATE OF ALASKA Alaska Oil & Gas Cons. Commission ALA~ )OIL AND GAS CONSERVATION COMM )ON Anchorage REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 8100 0 o 9000 1520 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California (UNOCAL) Name: 3. Address: P. O. Box 196247 Anchorage, Alaska 99519 7. KB Elevation (ft): 100' RT above MSL 8. Property Designation: Trading Bay Unit / King Salmon Platform 11. Present Well Condition Summary: Total Depth measured 11094 feet true vertical 10376 feet Effective Depth measured 11036 feet true vertical 10318 feet Casing Length Size Structural 378 24 Conductor Surface Intermediate 2470 13.375 Production 11 081 9.625 Liner Perforation depth: Measured depth: various 10499-10935 True Vertical depth: various 9817-10226 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze:summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Temp Surveys Daily Report of Well Operations Contact Hal Martin Printed Name JI Â LM A ~TI "I Signature #.f ~ ~ ' Form 10-404 Revised 04/2004 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other ~ Return to Inj Test I Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 168-083 Service 0 6. API Number: 50-733-20148-00 9. Well Name and Number: K-11 10. Field/Pool(s): McArthur River/Hemlock Pool Plugs (measured) 11036 Junk (measured) none MD TVD 378 378 2470 2402 11 081 10383 Burst Collapse RECEIVED JAN 2 6 2006 c Alaska Oii & Gas Cons. Commissian Anchorage 41/2 11.6# N-80 10412' Otis 9 5/8 "WD" WD Permanent Packer Camco TRDP 1-A SSSV RBDMS BFl .IAN 3 1 2006 Tubing Pressure 1525 1820 Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 305-312 Title Optimization Engineer Phone (907)263-7675 Date 1/24/2006 Submit Original Only , ^ ~I 'J n ')nnr. 'ARCO Alaska, Inc. I k .1ding Bay Unit .. King Salr~ h Platform W ell ~K~11 API#~ 5()" 733-20148-00 td Date: 9-27 -68 Completion Date: 3..26..88 .~.~ ginal RKB: 100' MSL Hanger Type: FMC 4-1/2" BTC ~..bp of Hemlock: 10500· Maximum Hole Angle: z¡o Annulus Fluid: Sea water Last Revised.: 12"()5-89 All Depths are RKB MD to Top of Equipment" Well Type: Water Injector New 0 Workover ri] RKB to Hanger: 33.75' Angle at Perforations; 20Q Reason: New Fill Level -- - ~ 1 2 3 4 5 6 Jewelry 326' 10373' 103751 10404 r 10411' 10412' Cameo TRDp·IA SSSV nipple: ID = 3.812'* Otis seal assembly (17.04 + (l.ll + 0.65) locator +1.0 space out) Otis WD 9-518'· pennanent pa.ck:er wI seal bore extention Cameo 08·6 nfpple~ ID = 3.7S" . Otis Shear-out wI wireline re-entry guide . 4-\/2'· tubing tail 1 ~I ¡~ Castng and Tubing Sll..t W.tJohl Or~, rbre~ul I..fuI. fJottom pe~cr'P11£þ'n 7 13-318" 61# J-55 BTC 34· 2470' Casing 8 9-518'· 47# N·80 & P-ll0 ' 34' llOSr Casing 9 9 4-1/2'· 11.6# N-SO HD Lock..it 34· 10412J Tubing ,& g 2 3 ,;,...' < . ~ : i --J 4 Fill Level Data: - 1B ~ J&mh . CorruT1~IUS ,~\ 5 In.,6/87 2,2414 10970- Tagged fiU 6 9/13188 3.714 1098?! Tagged fill 3-4-89 PL 11023' Tagged fiU ì/I~/q3 3.611 IOJQ6&' 10 Bench I Perforation Data · DIL depths 861 J ZI.u T'UJ.·PdD.lSS Perf Interv~t f.I .s.u a t 1050019717 10499-10509 10 4 B-2 2 1054019755 10550-10675 125 4-8 B..3 J 10 3 1068419889 10695-10733 38 8-12 8-4 J 4 10733,9939 10733·10850 117 4-12 B·5 ] 5 10854/10052 10865-1 093S. 70 8-12 B~6 -- }.{)93S·100S1 16 SQZD 6 10951/10142 10951-11030 79 SQZD 7 11034/10219 NO( Perforated ~ PBTD = 11030' ~ TD = 11094' fvID 8 Datum ;:: ~350' 55 = 9450· TVD :: 10106' MD 4000 - - (1) J! 5000 -- ci :æ I .c - 6000 Q. (1) 0 7000 10000 11000 50 1 Fîeld:IKlng o o Pressure (psia) 1500 2000 2500 3000 3500 4000 500 1000 1000 Pressure-Temperature Profile 2000 3000 8000 9000 60 70 80 90 100 110 120 130 Temperature (Deg. F) 12-21-05 Pressure TBG" Perfs 12-21-05 Temp 9-5/8" 13-3/8" -8-5-05 Temp I I 4500 140 o o 1000 2000 3000 4000 - .... CÞ ~ 5000 - C > i- I .c 6000 .... Q. CÞ C 7000 8000 9000 11000 50 I 1 Field:IKi 500 Pressure (psia) 1500 2000 2500 3000 4000 1000 3500 60 80 70 90 100 110 120 130 Temperature (Deg. F) 12-21-05 Pressure TBG Perfs 12-21-05 Temp 13-5/8 Casing -8-5-05 Temp 9-5/8 Casing 4500 140 1.000 K..11 Maximum Allowable 0 rating Pressure Gra o 3,000 Pressure (PSI) 4,000 5,000 6,000 7,000 8,000 9,000 10,000 1,000 2,000 o Size Weight Grade Yield Top Bottom 9.625 47 38.2 40.0 2,000 9.625 8452.9 9.625 47 P-110 9440.0 8452.9 11037.2 9.625 11037.2 11039.1 9.625 47 P-110 9440.0 11039.1 11078.4 9.625 11078.4 11081.0 13.375 61 J-55 3094.0 39.1 2426.9 13.375 61 J-55 3094.0 2426.9 2428.5 13.375 61 J-55 3094.0 2428.5 2468.6 3,000 13.375 61 J-55 sl.Imptions nominal with fluid weight of 0.433 #/ft of nominal with fluid weight of 0.433 #/ft 4,000 5,000 - C ¡:: :; 6,000 ... a. <I> C 7,000 - 8,000 9,000 10,000 11,000 12,000 sis @70 percent 20060124.)(ls Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% -Outside Containment for Production casing -MASP (production casing) -Intermediate CYP @ 45% - Outside Containment for Intermediate casing -MASP (Intermediate casing) . Current Pressure Readings , Disclaimers (fine D . Casing yield values taken tr ished sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD e e rF Iz=¡ J! i1::: FRANK H. MURKOWSKI, GOVERNOR A1tASKA. ORAND GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Hal Martin Optimization Engineer Union Oil Company of California (UNOCAL) P.O. Box 196247 Anchorage, Alaska 99519-6247 .\ I,jrtlfð·<t ~ANNEb Nmf 0 [i 2005 Re: Trading Bay Unit K-11 Sundry Number: 305-312 Dear Mr. Martin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Jo Chair DATED thisbday of October, 2005 Encl. (I IYI / STATE OF ALASKA Gr'~~··i2~Dj ALAe Oil AND GAS CONSERVATION COMM.ON o~ APPLICATION FOR SUNDRY APPROVALYcI /1) 20 MC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: RECf:IVËrf- OCT 11 2005 '~r;} Suspend Repair well D Pull Tubing D Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of Califomia (UNOCAL) 3. Address: 1. Type of Request: Perforate Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ~~¡, Development Stratigraphic D D 6. API Number: 50-733-20148-00\/'" Exploratory D o Service P. O. Box 196247 Anchorage, Alaska 99519-6247 7. KB Elevation (ft): 100' RT above MSL 8. Property Designation: Trading Bay Unit / King Salmon Platform 11. Total Depth MD (ft): 11094 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): various 10499-10935 Packers and SSSV pe: 9. Well Name and Number: K-11 10. Field/Pools(s): McArthur River/Hemlock Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10376 11036 1031811036 Junk (measured): none Length Size Burst Collapse TVD 378 24 378 378 2470 11081 133/8 95/8 2470 11081 2402 10383 Perforation Depth TVD (ft): various 9817-10226 Otis 9 5/8 "WD" Permanent Packer Camco TRDP 1-A SSSV Tubing Size: Tubing Grade: 4 1/2 11.6# N-80 Tubing MD (ft): 10412 10375 / 326 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: .¡ 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D Plugged D WAG D GINJ D WINJ 0 WDSPL Service 0 .,p. Abandoned D D upon approval of this sundry Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hal Martin 263-7675 Printed Name Hal Martin Title Optimization Engineer Signature /J? 0." ~ Phone 263-7675 Date 10/10/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~-:!51 ~ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Wfè;\\' o~~,c,,~ ()..~ ~~~SC"c~ ú.~C(:) ~<"'-I:4..,?·\o..VJ \v... ~~. ~\ \ ~ """~~~"( «:.~c~\ " ~ . RBDMS 8FL 0 C1 1 4 2005 COMMISSIONER APPROVED BY THE COMMISSION Date: ORIG'~JAL V Form 10-403 Revised 07/2005 Submit in Duplicate e e Chevron === J. Hal Martin Optimization Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email martinh@chevron.com . _.AfØ \~ .... October 11, 2005 RECEIVED OCT 11 Z005 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Alaska Oil & Gas Cons. Commission Anchorage Re: King Salmon Platform Well No. K-11 Injector Return to Injection Test Dear Tom: Union Oil Company of California would like to propose the process below to qualify and obtain administrative approval from the AOGCC for the King Salmon Platform Well No. K-11 (Permit # 1680830) as an injector under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids. The King Salmon Platform Well No. K-11, a waterflood injector, developed tubing to casing communication on 8/1/05 and has been shut-in since that time. A base line temperature survey was run on the well on 8/3/05 and no indication of injection outside the zones of interest is evident. The proposed plan is as follows: 1) Baseline temperature survey (performed 8/3/05). 2) Obtain permission to inject from AOGCC. 3) Inject for 8-9 weeks, keeping maximum injection pressure under 3000 psi. 4) Follow-up temperature survey. 5) Obtain administrative approval to inject. 6) Monitor well daily and repeat temperature surveys every two years. - ~. \"X.?tA ~C\~\t _ ~ryvt tc/\~ Union Oil Company of California / A Chevron Company http://www.chevron.com e e Tom Maunder AOGCC October 11 , 2005 Page 2 Please review the enclosed Form 10-403, 8/3/05 baseline temperature survey, maximum allowable operating pressure graph, and schematic and call me at (907)263-7675 if you have any questions. Sincerely, M /J;~ Hal Martin Reservoir Engineer Union Oil Company of California JHM:jll Attachments Union Oil Company of California I A Chevron Company http://www.chevron.com - 5000 - Q> J! - ~ C 6000 :E . .c - c. Q> C 7000 10000 11000 12000 60 o o Pressure (psia) 1500 2000 2500 3000 3500 4000 4500 500 1000 1000 2000 3000 4000 8000 9000 70 80 110 120 130 90 100 Temperature (Deg. F) 4000 - ....... c:1) J! 5000 - ~ C > ..... I .c 6000 ....... Q. c:1) C 7000 10000 11000 60 o o Pressure (psia) 2000 2500 4000 4500 500 1000 1500 3000 3500 1000 2000 3000 8000 9000 70 80 120 130 90 100 110 Temperature (Deg. F) 1.000 2,000 3,000 4,000 5,000 . - c > I- ¡ 6,000 Q. () C 7,000 8,000 9,000 10,000 11 ,000 12,000 K...11 Maximum Allowable er "ng Pressure Graph o 3,000 Pressure (PSI) 4,000 5,000 6,000 1,000 2,000 o -Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP @ 70% -Outside Containment for Production casing -MASP (production casing) -Intermediate CYP @ 45% -Outside Containment for Intermediate casing - MASP (Intermediate casing) Current Pressure Readings 7,000 8,000 9,000 10,000 date: 10/11/20058:06:00 AM Disclaimers (fine Casing yield values taken sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Size Weight Grade Yield Top Bottom 9.625 47 38.2 40.0 9.625 47 N-80 6870.0 40.0 8452.9 9.625 47 P-110 9440.0 8452.9 11037.2 9.625 11037.2 11039.1 9.625 47 P-110 9440.0 11039.1 11078A 9.625 11078A 11081.0 13.375 61 J-55 3094.0 39.1 2426.9 13.375 61 J-55 3094.0 2426.9 2428.5 13.375 61 J-55 3094.0 2428.5 2468.6 13.375 61 2470.0 sumptions f nominal with fluid weight of OA33 #/ft of nominal with fluid weight of 0.433 #/ft ysis @70 percent 20051 011.xls ARca Alaska, Inc. .ading Bay Unit· King Salan Platform \ïdL K.:l1 API'; 50.. 733·20148-00 .d Date: 9-27-68 Compledon Date: 3·26-88 '''\ ginal RKB: 100' MSL Hanger Type: FMC 4-112" BTC ./. iJp of Hemlock: 10500' Maximum Hole Angle: z:¡o Annulus fluid: Sea water Last Revised: 12-05-89 All Depths are RKB MD to Top of Equipment. ;"-' 1 9 2 3 Well Type: Water Injector New 0 Workover [iJ RKB to Hanger; 33.15' Angle at Perforations: 200 Reason: New Fill Level 1 2 3 4 5 6 Jewelry 326' 10373' 10375' 10404' 10411' 10412' Cameo TRDp·IA SSSV nipple: ID = 3.812" Otis seal assembly (17.04 + (1.11 + 0.65) locator +1.0 space out) Otis WD 9-518" permanent Jacker wi seal bore extention Cameo DB·6 nipple: ID = 3.7S" . Otis Shear-out w / witeline re-entry guíde . 4-1/2" tubing tail 7 8 9 Casing and Tubing Slu Welvht Gad& l3-318" 61# ]-55 9-518" 47## N-SO & P-II0 . 4-1/2" 11.61# N-SO Bottom Du~rlotlil1 2470' Casing 11081' Casing 10412' Tubing Thread IJu¡ BTC 34' 34' lID Lock·it 34' 4 Fill Level Data: IB ~ J&wh . Comments 5 1(2.6/87 2.24" 10970' Tagged fin 6 9113188 3.7" 10982' Tagged fill 3-4-89 PL 11023' Taggedfill 1/I'7M3 3.6" tOJ tl6 ß/ 10 Bench / Perforation Data ~ OIL depths 8-1 Zt.u TOD.MD/SS Perf Jnterval U .s.u 1 1050019717 10499-10509 10 4 8-2 2 1054019755 10550-10675 125 4-8 B-3 10 3 1068419889 10695-10733 38 8-12 8-4 4 10733m39 10733·10850 117 4-12 8·5 S 10854/10052 10865-10935. 70 8-12 6-6 lO93S·H)951 16 SQZD 6 10951/10142 10951-11030 79 SQZD 7 11034/1 0219 Not Perforated PBro :: 11030' MD TD = 11094' MD '. S Datum = 9350' 55 = 9450' TVD :: lOU)6' MD RE: K-II Water injector shut in e \<OS-o~~ e Sub.icct: RE: K-1 ] Water injector shut in From: "Greenstein, Larry P" <greensteinlp@unocal.com> Date: Wed, 03 Aug 200508: 19:55 -0800 To: Thomas Maunder <t0111_ maundcr@admin.statc.ak.us> CC: Hal Martin <martinh@unocal.com>, Jim Regg <jim_rcgg@admin.statc.ak.us> Tom, I changed the color of the 9 5/8" csg plot and made sure that all of them were graphing. The pressures are all hand entered, no automation, and the gauges are intact. As you can see between the K-11 & K-24RD2 plots, the May pressure responses were nearly identical. The most likely reasons relate to the fact that these two wells were the only two wells on King that had mechanical integrity. All the other wells are in variance/Admin Approval mode and didn't show this pressure response. The waterflood was shutdown in early May and within days the annulus pressure on only these two wells showed a steady increase, most probably thermal in nature. Both annulii were bled off to safe levels. They both then thermally pressured up again to a lower pressure and as waterflood came back on line, the cooling of the water took both well's annulus pressures right down to almost zero, again thermal in nature. Don't believe anything else explains these wells' pressure responses. Hope this helps. I also included a longer version of the K-11 pressure plot going back to the beginning of the year. Larry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, August 02, 2005 10:20 AM To: Greenstein, Larry P Cc: Hal Martin; Jim Regg Subject: Re: K-11 Water injector shut in ~(;ANNE[; NOV Ð 8 2005 Larry and Hal, Thanks for the notification. Looking at the pressure plot, there are few recent values for the 9-5/8" annulus pressure and it appears that that pressure was bled down in early May after showing a fairly rapid build up. Is the 9-5/8" annulus pressure automatically read or is it manually input?? Was the gage broken?? Can you all comment on these observations and Larry, would you please supply the pressure observations from January 1. Tom Maunder, PE AOGCC Greenstein, Larry P wrote: Per our conversation this morning, Tom, here is the 90 day pressure chart for K-11. The tree is being tested today and a temp survey is being scheduled for later this week, should the seals in the tree not resolve the integrity problem. As soon as we get the analyses back on K-11 & K-24RD2, we will get them over to you for review. Call me if you have any other requests/questions. Larry lof2 10/12/20057:54 AM RE: K-11 Water injector shut in e e «K-11 Pressure Observations 2005 08 01.xls» *From:* Neely, Dallas *Sent:* Tuesday, August 02, 2005 6:07 AM *To:* Dolan, Jeff J¡ Santiago, Johnny T *Cc:* Myers, Chris S¡ Johnson, Wayne E¡ Waski, John *Subject:* At 18:30 on 8/01/05 night waterflood operator found 9 5/8 casing pressure on K-11 to be 1650 psi. 24" at 90 psi, 13 3/8 at 95 psi, tubing at 2000 psi. Maximum psi is 500 psi on 9 5/8 casing, so well was shut in. Had to shut down waterflood also because we cannot maintain our minimum injection rate without K-11. After pressure bled off, restarted waterflood and tested K-11. After 30 minutes 9 5/8 casing pressure was above 500 psi and climbing along with tubing pressure. K-11 shut in at 1:45 am, waterflood also shut down. Dallas Neely C t t D . to . K -11 Pressure Observations on en - escnp Ion. 2005 08 02.xls Pressure Observations 2005 08 Content-Type: Content-Encoding: application/vnd.ms-excel base64 1 Pressure Observations 2005 08 C t t D . to oK-II Pressure Observations on en - escnp Ion. 2005 08 01.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 K-24RD2 Pressure Content-Description: Observations 2005 07 !K-24RD2 Pressure Observations 2005 07 31.xls 31.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 20f2 10/12/20057:54 AM K-ll Pressure Observations 2500 10000 o 11/09/04 HRS_ON -TBGPRESS ~~--wCSGPRESS295m CSGPRESS3 13 3/8 CSGPRESS6 26 -DAILY VOLUME 9000 2000 8000 7000 1500 6000 e :::I 11'I 5000 11'I e Q. 1000 4000 3000 500 2000 1000 12/29/04 02/17/05 04/08/05 Date OS/28/05 07i17/05 o 09/05/05 Printed on 10/12/2005 at 7:54 AM Prism Chart Prism Chart MEMORANDUM ) ~ ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Tuesday, July 05, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA K-ll TRADING BAY UNIT K-ll ~O:~3 Src: Inspector ~ (oq¡ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: TRADING BAY UNIT K-ll Insp Num mitCS050114145548 Rei Insp Num: API Well Number 50-733-20148-00-00 Permit Number: 168-083-0 Inspector Name: Chuck Scheve Inspection Date 1/10/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well K-ll Type Inj. w TVD 9719 IA 1780 2440 2440 2440 P.T.D 1680830 TypeTest SPT Test psi 2429.75 OA 10 15 15 15 Interval Four Year Cycle P/F Pass Tubing 1500 1500 1500 1500 Notes: SCANNED JUL 0'72005 );\-\'^-~~ "" ~\,ðlN;.~ ~ \e~~l;,\- ~'I ~~(<dæcn5.~1 A~~ ~ l-ç-O S Tuesday, July 05, 2005 Page 1 of 1 dAN, 1,2003 4:00AM KiNG SALMON PLATFORM NO, 967 P, 5 Select Tog String: _~.-~.' U K-11 Report Name Waterflood Injector Well Status Length Votume D~ (hours) (bp~) ~2/S~2002 0 0 1~/2002 0 0 12/2812002 0 0 12/27/2002 0 0 ~.2/26/2~:~}2 0 0 t2/2S12002 0 0 12/24/2002 0 0 12/2,S/2002 0 0 t2/22/2~02 0 0 t2/2:L/2O02 0 0 12/2012002 0 0 12/1.,9/;2002 0 0 12/18/2002 0 0 12/17/2002 0 0 I2/t6/2002 0 0 12/~5/2002 0 0 12/'tqI20O2 o 0 12/13/2.002 0 0 12/12/2002 0 12/11/2002 0 0 z2/~012002 0 0 12/9/2002 0 0 12/8/2002 0 0 ~2/712002 0 0 z2/6/2002 0 0 ~2/S/200~ 0 0 :L2/4/2002 0 0 12/3/2002 0 0 12/~/2002 0 0 ~2/UL, O02 0 0 Tbg String TimePeriod Date Created 'rBU K-11 Last 90 Days 11112003 ~ Press Csg Press Outer C,,sg CpsO lpsi) 0 700 10 0 ~ 12 0 68O 10 0 68O ~o 0 68O 0 680 0 680 0 68O 0 68o 0 68O 0 68O 0 68O 0 680 iO 0 680 0 680 0 caSo ~0 0 ~ 0 68o 0 68O :LO 0 680 .'tO 0 68O 0 68O 0 680 0 68O 1.2 0 6~ 0 680 :L2 0 67$ 0 675 0 675 12 0 6~ 0 0 660 0 http://kodiak-anchortown-unocaLc°m/da/temPlates/tabutar'asP 111/2003 MEMORANDUJ TO: THRU: FROM: Alaska Oil and Gas Conservation Commission Camille O. Taylor ~ DATE: December 29, 2001 Chair % . ,, ,~,r, SUBJECT: Mechanical Integrity Tests Tom Maunder ~'1~~.,~ Unocal P.I. Supervisor,--- ....~., \'"~" King Salmon Platform K-11, K-07RD Jeff Jones Trading Bay'Unit Petroleum Inspector MRF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI K-11 ITypelnj. I S I T.V.D. 19257 =,~0 I=,~0 I=,~0 i=,~0 Ilntervall 4 P.T..D,I 168,083 TypetestI P ITestpsil 1800 I CasingI I 1830 I 1830 I 1830 I P/F Notes: post MIT annulus depressured to 500 psi & monitored 30 min. with no change. WellI K-07RD I Typelnj. I S I T.V.D. 19500 I Tubing 12500 12500 12500 I 2500 I Interval] 4 P.T.D.I 177-021 ITypetestl P I Testpsil 2000 ICasingl I 2000l 20001 2000l P/F Notes: post MIT annulus depressured to 500 psi & monitored 30 min. with no change. WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: IType Inj. Type test IType Inj. I I I I Tubing I ' I I I l lntervall TypetestI ITest psi l ICasingI I I I IP/F I IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= FOur Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details December 29, 2001: I traveled to Unocal's King Salmon Platform to witness Mechanical Integrity Tests on water injection wells K-11 and K-07RD. Ben Metz was the Unocal Representative in charge of the tests, which were performed in a safe and proficient manner. The pre-test pressures were monitored and found to be stable. The standard annulus pressure tests were then performed with both wells passing the 30 minute pressure test. Following the MIT the annulus pressures were each bled to 500 psi and monitored an additional 30 minutes with no changes noted. Summary.: I witnessed successful MIT's on Unocal's TBU injection wells K-11 and K-07RD on the King Salmon Platform. M.I.T.'s performed: _2 Attachments: Number of Failures: _0 Total Time during tests: _4 cc: MIT report form 5/12100 L.G. MIT TBU K-11,K-07RD 12-29-01 JJ.xls 1/14/02 DATE .. ~:~U~lN~ n~.E..CTI~O i~u P~ESS PREss PRESS :7 17675 ~ ~0 T~ 0 0 0 1~ 1~0 0 0 o 0 1~ 1100 o o 0 1~ 1180 0 ~6W ~ .,. ~3~ ,~ ~!~0 0 ~39 ~ ~ ~ 130 67832 ~3~ ~ ~ 1~ 7~3~6 ~3 ~ ~ 1~ 0 . ,, ~708 133~ ~ ~ t~ 0 . . 979H 132~ ~ ~ 1~ 11~3~ 13319 M ~ t~ ...... 12~ 1:3192 _.. ~ ~ ~ 0 13776~. 13268 ~ ~ t~ 0 ... ..16~ . 1~87 ~,?S , 2~ 1~ .... o 1~317 ~2 ~ 2~o 1~ , 0,,. t~?. 1~ ~ 2~00 ~ 0 ....... , . ~70~6 1.~ I u~ 2~ ~ o ~ 1~ ~ ~ 2sqo ~ o ~1 16101~, 24 27~ 1~ 0 ~1~7 1~6 ~ 27~ 160 0 . ~1 1~ ~ 27~ '160 " ~ .. ~ ' ~1 ~ 27M , ,.16° ., 0 ..... 31~ 1~7 24 27M , ~. 160 o ~S 1M ~ 24 ~M , 1~0 0 0 . o ...... 0 ..... K.~6 I ~ETER" BARRELS "HRS TumNO'" 9'6Ju 13.am REAI)Wl) INJECTED INJ PRESS laa~ss PRESS O O 0 O 0 0 0 o 0 0 O O 0 0 0. 0 · (] o 0 0 0 0 O .... 0 ~' 0 0 0 0 O o 0 0 0 o .... 0 0 0 0 0 0. 0 0 O 'i 0 0 o o 0 o o ~) O .. 0 · 0 0 0 o .. 0 .., 0 ~. 0 0 .,, 0 O 0 0 0 0 0 0 o o 0 O 0.., 0 · 0 0 o 0 0 .... 0 0 0 O · 0 · 0 0 O o . o o o 0 o . o I o o o 0 o o .0 0 o 0 0 0 I 0 0 O O 0 0 O ~ 0 0 .. o 0 0 · 0 0 - . o o o 0 o o 0 0 0 0 0 0 o O o O o 0 o · o o O o o o o o o .... o 0 0 O 0 o o o o o o ., o 02/G~9 02/03/99 #2/04/90 0~7~ TOTAL = 329076 TOTAL 0 JAN-14-98 14ED 09:19 UNOCAL ASSET GAS GRP FAX NO, 9072637874 P, 02/02 UNOCAL4 909 W. 9~ Ave. Anchorage, Alaska Blair Wondzell State of Alaska Alaska Oil and Gas Conservatio~ Commission 77"OZl Re: McArthur River Field Injectors G-22, K-4RD, K-15RD, K-22RD, K-7RD & K-11 Dear Blair: As per our phone conversation on 1/13/1998. The WFL ran on Grayling Platform G-22 showed a breach in the 9-5/8" csg between 4750' and 4800'. The WFL indicated water flowing down the 13-3/8" X 9-5/8" annulus from the breach in the 9-5/8" csg out thru the 13-3/8" shoe..The well is currently shut-in and will remain so until it can be repaired. I will be forwarding G-22's WFL logs and summary to you when we receive them in their final version from Schlumberger. King Salmon K-4RD failed it's MIT on 2/26~/9_7~. The well was shut-in on 3/04/97. Slickline attempts on 4/5/97 failed to obt-~-~ a MIT. We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. , King Salmon K-15RD, passed it's MIT on 2/26/97. On 11/25/97 the csg_pressured up to 2800 psi (tbg 3000 psi) indicating communication between tl3~;-'i'-h~ ~ir-W'a-~-~h-~{~ On ..... l_2_./03/gy~.We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-22RD, passed it's MIT on 2/26/97. On 11/25/97 the_cs~q_p~essured up~o !80__0 p~i.. (tbg 3000 psi) indicating communication between the tb-g-ahd Cs~ The w~~~t-i~ on ~-2-~0-§/97~,-We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-7RD, passed it's MIT on 2/26/97. The welt was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the Iow injection rates caused by K- 4RD, K-15RD & K-22RD being shut-in. King Salmon K-11, passed it's MIT on 2/26/97. The well was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the Iow injection rates caused by K-4RD, K- 15RD & K-22RD being shut-in, If you require anything else regardingwhat we discussed, please let me know. St~~ve ~ Engineering Technician CC: Chris Ruff Unocal Corporation ~) Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: King Salmon Platform Well K-11 APl Number $0-733-20148-00 This is to inform you that the coil tubing sandback Sundry Request approval No. 93-150 has not yet been conducted. Unocal requests that this sundry be kept open so the work may be performed when it becomes feasible. Very truly yours, J. H. Martin ALA ~ STATE OF ALASKA ' OIL AND GAS CONSERVATION COM& "~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Alter easingm Repair well __ Change approved program __ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99619 Plugging __ Time extension __ Stimulate __ '* Pull tubing __ Variance __ Perforate __ OtherX_ ~ ,~ Type of Well: 6. Datum elevation (DF or KB) ~_ RKB 100' 5. Development ~._ Exploratory __ Slratig mphio __ Location ofwell at surface King Salmon Platform Leg #2, Cond. #12 617' FSL, 131' FEL, Sec. 17, R9N, R13W, SM At top of productive interval 3224' FSL, 2286' FEL. Sec. 19, 'r9N, R13W, SM At effective depth 3115' FSL, 2404' FEL, Sec. 19, T9Ni R13W, SM At total depth 3115' FSL, 2420' FEL, Sec. 19, T9N, R13W, SM 7. Unit or Property name TRADING BAY UNIT 8. Well number K-11 9. Permit number 68 -83/8 -79 10. APl number 50-133 -20148 11. Field/Pool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 11,094' 10,376' feet feet Plugs (measured) 11,036' Effective depth: measured 11,036' true vertical 10,319' feet feet Junk (measured) Casing Length Structural Conductor 378' Surface 2470' Intermediate Production 11081' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth 24" Driven 13-3/8" 1550 sx 378' 2470' 378' 2402' 9-5/8" 1000 sx 10363' Uppermost perf. 10,499' Lowermost perf. 10,935' J U N 1 199 Uppermost perf. 9717' Alaska 0il & Gas Cons, c0mmissi0t Lowermost Perf: 10,224' 4-1/2", 11.6#, N-80, HD Lock 17 Anchorage Packers and SSSV (type and measured depth) Otis 9-5/8" "WD" Perm Pkr @ 10,375'/Camco TRDP 1 -A SSSV @ 326' 13. Attachments Description summary of proposal _ _ Detailed operations programX__ BOP sketch X_ 14. Estimated date for commencing operation ~15. June, 1993 16. If proposal was verbally approved Oil _ _ Gas __ Name of approver Date approved Service --Water Ir~ector 17. I h~'rel~e, rtif~t_~.~t t,h~e~ir~ i~d-- correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Status of well classification as: Suspended __ Date June 10, 1993 Conditions of approval: Nobly Commission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- .~'~3~ I Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signed By Duvid W. Johnston .4koproval No. / Approved Copy Returned commissioner Date C.f/~/~ ~ SUBMIT IN TRI~ICATE ARCO Alaska, Inc. sd Date: 9-27-68 ginal RKB: 100' MSL , op of Hemlock: 10500' Maximum Hole Angle: Annulus Fluid: Sea water Lazt Revised: ~9 All Depths are RKB MD to Top of Equipment. T-'~ing Bay Unit- King Salmon Pl)atform APl#: 50..733-201484)0 Well 'IX. fl:e: Water Injector Completim Date: 3-26-88 New I~ Workover [~ Hanger Type: FMC 4-1/2" BTC RKB to Hanger: 33.7;5' 27° Angle at Perforations: 20° Reason: New Fill Level B-1 B-2 I)-3 10 Jewelry 326' 10373' 1037:5' 10404' 10411' 10412' Camco TRDP.IA SSSV nipple: ID = 3.812" Otis seal a~embly (17.04 +(1.11 + 0.65) locator +1.0 space ou0 Otis WI) 9-:5/8' pem,.aneat packet wi seal bose extentioa Camco DB-6 nipple: ID = 3.7S" Otis Shear-out wi wireline re-eau7 guid~ 4-1/2' robing tail Casing and Tubing ~ Wel?ht 13-3/8" 611 9-5/8" 471t 4-1/2" 11.6~ }.:55 BTC 34' 247ff Casin~ N-80& P-Il0 34' 11081' CuM N-80 HD Lock-it 34' 10412' Tubing Fill Level Data: !/26/87 2.24" 1097ff 9113/88 3.7' 10982' 3-4-89 PL 11023' T,ued flu Tagged fill Tagged fill 10 Bench I Perforation Data · DIL depths ~ ~ Eerf lnterynl ~T ,~P..F= I 10500/9717 10499.10:509 10 4 2 10540/9755 10:550-1067:5 125 4-8 3 1068aD889 1069:5-10733 38 8-12 4 10733/9939 10733.10850 117 4-12 :5 10854/100:52 1086:5-1093:5 70 8-12 10935.10951 16 SQZD 6 10951/10142 10951.11030 79 SQZD 7 11034/10219 Not Perforated PBTD = 11030' MD TI)= 11094' MD Datum = 9350' SS = 94:50' TVD = 10106' MD RECEIVED J UN l'q- 199~ Alaska 0il & Gas Cons. CommiSsion Anchorage General Work Procedure Coil Tubing Sandback K-11 1. RU & test 1-1/2" coil tubing unit (maximum depth 11,030'). , 3, , RIH w/bull nose & tubing tail Iocator. Locate tubing tail and tag fill. Mix and pump 80% of calculated sand plug slurry to fill to 10,945'. Tag sand top. Mix & pump remainder of sand necessary to fill to 10,945'. Tag sand & repeat until top of sand at 10,945'. RD & move to next well. E-line tag to follow to verify top of sand. REEEIVED JUN 1~- 1993 Alaska 0fl & (~as (;0ns. Anchorage .3' U' N -- TUE ARCTIC PIPE INSP P. ~2 ~RCTIC -~ECOIL Arctic Recoil, Inc. (907) 283-1980 P.O. BOX 2595 Kenai, Alaska g9511 RECEIVED J U N 1,t- 1993 Alaska Oil & 6as Cons. Commissio~ Anchorage O,L CO S V,T,O CO ,SS, R 1 6 1 A L REPORT OF SUNDRY WELL OPERATIONS 1. Type ~f Request: Operation Shutdown Stimulate ,, ' Plugging Perforate__ Pull tubing Alter casing ~ Repair well ...... Pull tubing ~ Other X MIT 2. Name of Operator UNOCAL Corporation (ARCO Alaska, Inc, is sub-operator) 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory ~ Stratigraphic __ Service X 4. Location of well at surface Leg Z, Conductor 1 2; 617' FSL, 131' FEL, Sec. 17, TgN, R13W, SM 6. Datum elevation (DF or KB) RKB 100' , 7. Unit or Property name Trading Bay Unit 8, Well number K-11 fe~t, At top of productive interval 3224' FSL, 2286' FEL, Sec. 19, T9N, R13W, SM At effective depth 3115' FSL, 2404' FEL, Sec. 19, T9N, R13W, SM At total depth 3115' FSL~ 2420' FELr Sec. 19~ T9N~ R13W~ SM 12, Present well condition summary Total Depth: measured 11094' true vertical 10376' Effective depth: measured 11036' true vertical 1031 9' Casing Length Size Structural Conductor 378' 24" Surface 2470' 13-3/8" Intermediate Production 11081' 9-5/8" Liner Perforation depth: measured 9. Permit number/approval number 10. ~PI nun~ber 50-733-20148-00 1 1. Field/Pool McArthur River McArthur River .(Hemlock) feet Plugs (measured) 11036' MD feet feet feet Junk (measured) 10970'feet feet Cemented Measured depth True vertical depth 378' 378' 1550 sx Class G 2470' 2402' 1000 sx Class G 11081' 10363' 13. See Attached Well Schematic true vertical See Attached Well Schematic Tubing (size, grade, and measured depth) 4-1/2", 11.6# N-80 from 34'-10412' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 13172' MDt Otis BMX series 10 SSSV @ 263' MD Stimulation or cement squeeze summary Intervals treated (measured) N/A RECEIVED JUL 2 8 1992 Alaska 0ii & Gas Cons. C0mmisst0n Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Avera0e Production or Injection D~ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 16648 0 2700 Subsequ.ent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 16714 16. Status of well classification as: 0 2700 Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Date Si~lned ~ ~ %, ~)u~.-'k~ Form 10-404 R~O6/~ff SUBMIT IN DUPLICATE ~.RCO Alaska, Inc. Trading Bay Unit - King Salmon Platform Well ~ API~. 50-733-20148-00 Spud Date: 9-27-68 Completion Date: 3-26-88 Original RKB: 100' MSL Hanger Type: FMC 4-1/2" BTC Top of Hemlock: 10500' Maximum Hole Angle: 27° Annulus Fluid: Sea water Last Revised: 12-05-89 All Depths are RKB MD to Top of Equipment. WeU type: Wa=r njector New ~] Workover [] RKB to Hanger: 33.75' Angle at Perforations: 20°. Reason: New Fill Level B-1 B-2 8-3 B-4 B-5 8-6 10 Jewelry 1 326' 2 10373' 3 10375' 4 10404' 5 10411' 6 10412' Camco TRDP-1A SSSV nipple: ID = 3.812" Otis seal assembly (17.04 +(1.11 +0.65) locator +1.0 space ou0 Otis WD 9-5/8" ~ .~ent packer w/seal bore extention Camco DB-6 nipple: ID = 3.75" Otis Shea'-out w/wireline re-entry guide 4-1/2" tubing tail Casing and Tubing Size ]~.LtJkt 7 13-3/8' 61# 8 9-5/8" 47# 9 4-1/2" 11.6~ G~de Thread ~=9.R Bottom ~ $-55 BTC 34' 2470' Casing N-80 & P-Il0 34' 11081' Casing N-80 HD Lock-it 34' 10412' Tubing Fill Level Data: Da~ Size Depth 1/26/87 2.24" 10970' 9/13/88 3.7" 10982' 3-4-89 PL 11023' Comments Tagged fill Tagged fill Tagged fill 10 Bench /Perforation Data - DIL depths ~ ~ Perf Interval FT S PF 1 10500/9717 10499-10509 10 4 2 10540/9755 10550-10675 125 4-8 3 10684/9889 10695-10733 38 8-12 4 10733/9939 10733-10850 117 4--12 5 10854/10052 10865-10935 70 8-12 10935=10951 16 SQZD 6 10951/10142 10951-11030 79 SQZD 7 11034/10219 Not P~dcramt PBTD= 11034Y MD Ti)= 11094' MD Datum = 9350' SS = 9450' TVD = 10106' MD ARCO Alaska, Inc. ~NTRACTOR REMARKS WELL SERVICE REPORT FIELD- Di~TRICT- STATE OPERATION AT REPORT TIME 16" F1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK DO0×C00'BD~d 9NI~NIDNB I3 Ol N~O51t~']d NON]~S DNI>! NO~l-~ EC:S! ~G, ~tI ~tdtt Z o Z 0 0~ Z 0 0 , .OJ & OIL AHO CaS COH. IAn~ CCFJ~,SSmH H_ECHAmr. At..INT~RITV T£ST PREIESr START 15 Hill 30 Hill *P '1 TYPE (IF PKR CASING; TgG REQ TEK; Tl~ TiHE IIHE P~E ~ ~i F~ID ~ ~S PR~S ~G ~G C~ ~ ~S ~E~ - ~ - l, - ,. ~ , - ..... , ,, ,,., ...... . _ ~ ~ ., .,. ~ · I,l,I ~ ,,-~ ..... ., l. I .' I. I Il · ~, .~ .. ........ . ......... , _ , ,, ,,, . .. ..... _ ...... ....... _ _., _. ~ *rUBSNG INJECTIO~ [~L_U!D: MIll. AR ~ e- ~CE KATER lNJ ~EESEL m S - ~LT WRIER I~J ~YCOL ~ H - NI~IeLE rNJ'ECTIOE S~r rATER I ~ - NOl lffJECI I~ OI~ER o OTH~ ~gP-.F~:~r,-t Ar~dJ~LU.~ TP~T 7'~$ r 20 AAC: 25.o3o(a) ?o nac 2s.t,l~lc! 6 -J Z ~.~ Z Z. G, 'r~ Unocal North Amer' Oil & Gas Division Unocal Cor~oratlon P.O. Box 190247 Anchorage. AlasKa 99519-0247 Teief~none tg0~ 276-7600 AlasRa Recj,on April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope tkis will meet your needs. Yours very truly, Gar~. S. Regional Drilling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG ~l: "Y" COOR. "X" COOR. WELL-#· FNL 2,511,762 213,819 K-21 & RD 688 2,511,761 213,815 K-30 687 2,511,764 213,811 K-18 690 2,511,768 "213,810 K-17 694 2,511,772 213,812 K-23 (23-19) 698 2,511,773 213,817 K-19 699 2,511,770 213,821 K-22 & RD.i 696 2,511,766 213,822 K-20 692 LEG #2: 2,511,690 213,768 9 10 11 12 13 14 15 16 LEG #3: 17 18 19 20 21 22 23 24 2,511,686 213,772 K-15' & RD 611 2,511,684 213,768 K-9 ~ 610 2,511,687 213,763 K-4 & RD 613 2,511,691 213,762 K-11 617 2,511,695 213,765 K-13 & RD 621 2,511,696 213,769 K-2 &RD 622 2,511,694 213,776 K-7 &RD 619 2,511,689 213,774 K-5 615 2,511,723 213,712 2,511,721 213,708 2,511,724 213,703 2,511,728 213,702 2,511,732 213,705 2,511,733 ' 213,709 2,511,731 213,713 2,511,726 213,714 2,511,799 213,760 K-8 725 2,511,798 213,756 K-1 & RD 724 2,511,801 213,752 K-lO &'RD 727 2,511,805 213,751 K-16 731 2,511,809 213,753 K-12 & RD 735 2,511,810 213,758 2,511,807 213,762 K-6 & 24 736 2,511,803 213,763 K-3 & RD 729 Leg #4' 25 26 27 28 29 3O 31 32 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 l!9 133 135 !41 142 140. 135 130 ,~) STATE OF ALASKA )S ALAS~',, OIL AND GAS CONSERVATION COM~. ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~ Pull tubing Alter Casing [] Other X WORKOVER 2. Name of Operator UNOCAL (ARCO Alaska, Inc. is sub-operator) 3. Address P.O. Box 190247, Anchorage, AK 99519 4. Location of well at surface King Salmon Platform, Leg 2, Cond. 12 617' FSL, 131' FEL, Seco17, TgN, R13W, SM At top of productive interval N/A At effective depth 1828' FSL, 2403' FEL, Sec.20, TgN, R13W, SM At total depth 1813' FSL, 2418' FEL, Sec.20~ TgN¢ R13W; SM 11. Present well condition summary Total depth: measUred 11094 'MD feet true vertical 10309'TVD feet Effective depth: measured 11030 'MD feet true vertical 10249'TVD feet 5. Datum elevation (DF or KB) RKB 100' Feet 6. Unit or Property name Trading Bay Unit 7. Well number K-11 8, Approval number 8-79 9. APl number 50-- 133-2Olb,8 10. Pool Hemlock Plugs (measured) 11030'MD Junk (measured) None True Vertical depth 378'TVD 2402 ' TVD 10363 ' TVD Casing Length Size Cemented Measured depth Conductor 378' 24" Pi le driven 378'MD Surface 2470' 13-3/8" 1550 sx Class G 2470'MD .Production 11081' 9-5/8" 1000 sx Class G 11081'MD measured 10499' -10509 ', 10550 ' -10675 ', 10695 ' -10850 ', 10865 ' -10935 ' true vertical 9783'-9791 ', 9825'-9927', 9943'-10079', 10093'-10159' Perforation depth: RECEIVED Tubing (size, grade and measured depth) 4-1/2", N-80 tbg w/tail ~ 10412' Packers and SSSV (type and measured depth) WD pkr @ 10375' & TRDP-1A-SSSV ~ 326' 12. Stimulation or cement squeeze summary Alaska Oil & Gas Cons, Commissio~ Anchor3~e Intervals treated (measured) All perforations f/10930'-11030' ~eatment description including volumes used and final pressure 65 sx Class G Representative Daily Average Production or Iniection Data OiI-Bbl Gas. Mcf Water-Bbl Casing Pressure Tubing Pressure 13. Water injector 22,040 2711 psi 2770 psi Prior to well operation 19,365 O p~i Copies of Logs and Surveys Run ~ Date 5/5/88 Submit in Duplicate Subsequent to operation .... 14. Attachments (Workover Well Hi story) Report of Well Operations ~, Daily 15. I,h~ereby certify that the, foregoing is true and correct to the best of my knowledge · " ~'~" Title S~gned Roy D. Ro~ts ,~ Enviro~tal Enqineer Form 10-404 Rev. 12-1-85 (Dani) SW03/66 ARCO Oil and Gas Company Well History- Initial Report- Daily Inltructions: Prepare and submit the "Initial RaIN, Il" on the first Wednesday after a well is spudded or workover operations are started. Dally wori( prior to spudding should be summarized on the form giving inclusive dates only. District IC°unty' parish or borough ARCO Alaska, Inc. I COOK INLET Field Itease or Unit TRADING BAY UNIT I Auth. or W.O. no. ITitle AD6072 I WORKOVER I Stat~K K-11 1well .o. API: 50-133-20148 Operator ARCO Spudded or W.O. begun IOate [Hour ACCEPT 03/18/88 Date and depth as of 8:00 a.m. 03/19/88 ( TD:11094 PB:11036 SUPV:MAL 03/20/88 ( TD:11094 PB:11036 SUPV:I~.L 03/21/88 ( TD:11094 PB:11036 SUPV:MAL 03/22/88 ( TD:11094 PB:11036 SUPV:MAL 03/23/88 ( TD:11094 PB:11036 SUPV:MAL 03/24/88 ( TD:11094 PB:11036 SUPV:HP 03/25/88 ( TD:11094 PB:11036 SUPV:HP Complete record for each day reported KING SALMON 2100 IARCO w.i. 18.0000 Prior status if a W.O. BREAKING OFF HYDRIL MW: 0.0 RU ON K-11. ACCEPTED RIG ~ 2100 HRS, 3/18/88. DAILY:S15,600 CUM:$15,600 ETD:S15,600 EFC:$850,000 POH MW: 8.5 FIW FINISH RU. TEST BOPE TO 3000 PSI. MIX AND PUMP 70 BBLS HEC PILL AND FLUSH TO PERFS W/ 160 BBLS FIW. SPEAR TBG. POOH LD 4-1/2" TBG. DAILY:S15,168 CUM:$30,768 CIRC BTMS UP POOH LD 4-1/2" COMPL. STRING. TO' 3000 PSI. PU 5" DP AND RIH. CHANGE TO 5" RAMS AND TEST SAME ETD:S30,768 EFC:$850,000 MW: 8.5 FIW BURN OVER PKR AT 10494'. DAILY:S17,946 CUM:$48,714 ETD:S48,714 EFC:$850,000 RIH W/ RTTS MW: 8.5 FIW CIRC BTMS UP. TOH. LD FTA AND PKR. MU BHA. RIH. CLEAN OUT FILL-F/ 10947' TO 11030'. REVERSE CIRC HOLE CLEAN. TOH. PU RTTS. RIH. DAILY:S24,066 CUM:$72,780 ETD:S72,780 EFC:$850,000 TIH MW: 8.5 FIW RIH W/ RTTS.. SET RTTS AT 10500'. TEST 9-5/8" CSG TO 2500 PSI F/ 30 MIN. TOH. LD RTTS. RIH W/ OEDP. SPOT 65 SX 'G' CMT ON BTM. PULL 6 STANDS. BULLHEAD F/ 10 MIN W/ FIW. TOH. MU BHA. TIH. (RAN CET F/11030'-10000') DAILY:$22,845 · CUM:$95,625 ETD:S95,625 EFC:$850,000 RIH W/TC PERF GUNS MW: 8.5 FIW FINISHED RIH WITH BIT, JB, SCRAPER & JARS. WOC. TAGGED TOP OF CMT @ 10930'. DRILLED CMT F/10930'-11030'. REV CIRC. POOH. MU PERF GUNS. RIH W/ SAME. HELD ARCO SAFETY MEETING W/ CREWS. RIH. DAILY:S13,600 CUM:$109,225 ETD:S109,225 EFC:$850,000 POOH MW: 8.5 FIW RIH. RAN GR/CCL. PERF WELL F/10499'-10509', 10695'-10845', 10865' TO 10935' W/ 5" 4 SPF GUNS. FLOW WELL. REVERSE CIRC. POOH. LD GUNS. RIH W/ BIT AND SCRAPER . REVERSE CIRC. POOH. DAILY:S17,473 CUM:$126,698 ETD:S126,698 EFC:$850,000 The above Is correct For form preperati~ and distribution, see Procedures M4l~lual, Section 10, Drilling, Pages 86 ud 87. Date Title 4-~-a~ [ AR3B-459-1-O Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation' name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and depth as of 8:00 a.m. ~ 03/26/88 ( TD:l1094 PB:11036 SUPV:HP County or Parish ARCO Alaska, Inc. COOK INLET Lease or Unit TRADING BAY UNIT K-11 Complete record for each day while drilling or workover in progress KING SALMON 03/27/88 ( TD:l1094 ?B:11036 SUPV:HP I StateAK SETTING PACKER MW: 8.5 FIW FINISHED PO. LD BHA, DC & 51 JTS DP. RU SOS. RAN VELOCITY SURVEY. RAN GR/JUNK BASKET TO 11000'. POH. MU TAILPIPE & 9-5/8" WD PACKER & TIH. SET PACKER @ 10375' TAILPIPE @ 10412'. RIH WITH OEDP. DAILY:S29,276 CUM:$155,974 ETD:S171,574 EFC:$834,400 RUNNING COMPLETION ASSY MW: 8.5 FIW FINISHED SETTING PACKER. RD SOS. RIH WITH DP. CIRCULATED WELL. LDDP. CHANGED RAMS TO 4-1/2" & TESTED TO 3000 PSI. RU TO RUN TUBING. RUNNING COMPLETION ASSEMBLY. DAILY:S115,860 CUM:$271,834 ETD:S287,434 EFC:$834,400 IWell no. The above is correct Signature For form preparatior~nd distribution see Procedures Ma~jJal Section 10, Drilling, Pages 86 &lSd 87 JOate [Title ASSOCIATE ENI31NEER AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil-' d Gas Company '~)Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Accounting cost center code State K-11 no. County or Parish COOK INLET Field ILease or Unit I TRADING BAY UNIT Auth. or W.O. no. ~Title AD6072 Ii WORKOVER Operator A.R.Co. ARCO 18. 0000 Spudded or W.O. begun Date ACCEPT 03/18/88 Date and depth as of 8:00 a.m. Old TD 03/28/88 ( 1 TD=11094 PB:11036 SUPV:HP API: 50-133-20148 Complete record for each day repo~ed KING SALMON Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 2100 HR$ RELEASED RIG MW: 0.0 FINISHED RUNNING 251 JTS 4-1/2", 11.69, N-80, TUBING W/TAIL @ 10412.23', SSSV @ 326', WD PKR @ 10375'. LAND SAME AND SPACED OUT. ND BOPE. NU TREE & TEST TO 5000 PSI. SECURED WELL AND RELEASED RIG @ 2000 HRS, 3/27/88. DAILY:S238,497 CUM:$510,331 ETD:S525,931 EFC:$834,400 New TD K nd of rig Released rig Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle For form preparatio~(~nd distribution, see Procedures Ma~al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Division of AtlantlcRIchfleldCompany 20 .MC 2~.1]~)(a3 20 ,~d::' 2.0 MC 25.2.~(d3 ALASKa,~ IL AND GAS CONSERVATION COMMi ' ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing'~ Amend order [] Perforate ~ Other 2. Name of Operator UNOCAL (ARCO Alaska~ Inc. is sub-operator) 3. Address P. 0, Box 190247, Anchorage, AK 99519 4. Location of well atsurfaceKing Salmon Platform, Leg 2, Cond.. 12 617' FSL, 131' FEL, Sec.17, TgN, R.13W, SM At top of productive interval 3224' FSL, 2286' FEL, Sec.19, TgN, R13W, SM At effective depth 3115' FSL, 2404' FEL, Sec.19, TgN, R13W, SM At total depth 3115' FSL, 2420' FEL, Sec.19, TgN, R13W~ SM 11. Present well condition summary Total depth: measured 11094 ' MD feet Plugs (measured) true vertical 1 0376 ' TVD feet 5. Datum elevation (DF or KB) 'RKB 100' feet 6. Unit or Property name Trading Bay Unit 7.K_llWell number 8. Permit number 9. APl number 50-- 1~,3- 201/~8 10. Pool Remlock 11 036 'MD Effective depth: measured 11 036 ' ND true vertical 10319'TVD Casing Length Size Conductor 378' 24" Sur face 2470 ' 13-3/8" Production 11081' 9-5/8" feet Junk (measured) feet 10970'MD Cemented Measured dePth True Vertical depth 3 78 'MD 3 78 ' TVD · 1550 sx 2470'ND 2402'TVD 1000 sx 11081 'MD 10363'TVD Perforation dePth: measured 10550'-10675', 10695'-10850', 10866'-11030' true vertical 9866'-9984', 10003'-10148', 10162'-10317, Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80, BTC ~ 10513'MD Packers and SSSV (t~,pe and measured depth) Baker model "F Pkr @ 10495', Otis ball valve ~ 263' 12.Attachments Description summary of proposal'~ Detailed operations program [] BOP sketch)~ 13. Estimated date for commencing operation March, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~ertif, y.,thj~t the foregoing is true and correct to the best of my knowledge Conditions of approval Approved by Form 10-403 Rev 12-1-85 ~ Title ]~"z~o~~_a'l _]~z3.g.i_n,~ Date ~--, ~1~,,~ Commission Use Only ~SR.~) .C;A~,/r~q Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI (~) "" ~ Mechen~cai Integrity T~5! Approved Copy Returned ORIGINAL SIGNED BY o~~'/~ -~ LONNIE C. SMITH Commissioner by order of oommission Submit in triplicate~ KING SALMON PLATFORM WORKOVER PROGNOSIS WATER INJECTION WELL TBU K-11 OBJECTIVE Workover water injector TBU K-11 to replace leaky 4-1/2" tubing string, cement squeeze any casing leaks, Hemlock Bench 6 perforations and a suspected channel just above the perforated interval, circulate out fill, selectively re-perforate and add new perforations to the injection interval, and put well on injection. K-11 is currently shut-in. pROCEDURE 1. MIRU over water injection well TBU K-11, leg #2, slot #12. 2. Kill well with brine. 3. ND tree. NU and test BOPE. 4. Pull and lay down 4-1/2" tubing string. Mill over and recover Baker Model "F" permanent packer set at 10495' MD inside ~-5/8' casing. ~', 6. Pressure test 9-5/8" casing, and lOCate any casing leaks above the perforated interval. . Perform diagnostic logging to locate suspected cement channel just above the perforated interval. Se 10. 11. 12. Run casing inspection log from PBTD to surface. Cement squeeze Hemlock Bench 6. Cement squeeze cement channel if necessary. Cement squeeze casing leaks if necessary. Clean out to PBTD @ 11036' MD. 13. Perforate Hemlock Benches 1, 3, 4, and 5 with 500-1000 psi under-balance using 5" tubing conveyed guns (approximately 230' of guns with 6 SPF and 206' of blanks will be required). Under-balance may be achieved with a partial fluid column in the drill pipe. Retrieve guns after perforating. 1 4. Run new 4-1/2" tubing completion assembly (see attached completion diagram). 1 5. ND BOPE. NU tree. RD and prepare rig for next well. A. L. Moritz Cook Inlet Engineering October 7, 1987 K-11 WATER INJECTION WELL PROPOSED COMPLETION 2. 13.3/8', 61#, J-55, BTC, CSG @ 2470' 3, 4-1/2', //, ~j N-80, 4. PERMANENT PACKER @ 5. NIPPLE, 3.75' ID, 6. TUBING TAIL @' 7. 9-5/8', 47#, P~110/N-80, CSG @11081' NOTE: ALL DEPTHS ARE MD. i i I INJECTI..~ INTERVAL ': /o~ --/oq~' ' 20' HOLE -- ANGLE @ PERFS ' - 6 -_ i i I i i i .-- ii I -- .;;.;.L-,:.',,'.-J?.:.-.:. ::.'.::-, ::::::::::::::::::::::::::::::::::::::::: :::..':::..'::.'..':::2::..':::.::::.::":..':".'.:::, ::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: PBTD @ 11036' TO @ 11094' 13-5/8" 3000 PS! BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 ACCUMULATOR CAPACITY TEST 1. CHECK AND FlU. ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIIV~ AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BLIND RAMS 4 1. FMC TYPE III UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAFTER 3, 13-5/8' - 3000 PSI DRILLING SPOOL 4.13-5/8' - 3000 PS1 BLIND RAMS 5.13-5/8' - 3000 PSi PIPE RAMS 6.13-5/8" - 3000 PSI ANNULAR BOP STACK TEST 1. Flu- BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT AU- HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT'AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10.MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOL~ CLOSE BLIND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTI=J::{ TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) REPORT OF SUNDRY WELL OPC:RATIQN$ 1. Operations performed: Operation shutdown~ Stimulate [] Plugging ~ Perforate Alter Casing [] Other[] Well shut-in because of~'t~.i~)(~J~O}T~ Feet 2. Name of Operator UNOCAL (ARCO Alaska~ Inc. is sub-operator) 3. Address P.O. Box 190247, Anchorage, AK 99519 4. Location 617' N At top of 3224'N At effective depth 3115'N & 2404'W from SE At total depth 3115'N & 2420'W from SE ofwellatsurface King Salmon Platform, Leg 2, Cond. 12 & 131' W from SW corner, Sec. 17-9N-13W-SM productiveinterval & 2286' W from SE corner, Sec. 19-9N-13W-SM 11. Present well condition summary Total depth: measured true vertical Effective depth: corner, Sec. 19-9N-13W-SM corner, Sec. 19-9N-13WLSM 11,0 9 4' feet Plugs (measured) 10,3 76' feet measured 1 1, 0 3 6' true vertical 10, 3 1 9' feet feet Casing Length Structural CondUctor Surface Intermediate 2,470' Production 11, 08.1_ ' Liner Perforation depth: 5. Datum elevation (DF or KB) 100' KB 6. Unit or Property name Trading Bay Unit 7. Well number K-ii 8. Approval number 427 9. APInumber 50-- 133-20148 10. ~ol Hemlock 11,036' MD Junk (measured) 1 0,9 7 0 ' MD Size Cemented 13-3/8" yes 995/8" yes 10695-10850'; 10003-10148'; measured 10550-10675'; true vertical 9866-9984'; Tubing (size, grade and measured depth) 4½", 12.6¢f, N-80, BTC @ 10513' Packers and SSSV (type and measured depth) Otis 3,812" ID SSSV @ 263' MD~ Measured depth True Vertical depth 12. Stimulation or cement squeeze summary Intervals treated (measured) 2~470' 2,402' 11,08 1' 11,042' 10865-11030' MD ~"~/ 10495 ' MD RECEiVEO AUG 0 '!-: 1987 MD Baker 'F' pkr. @ Naslm Oil & Gas Cons. Commission Representative Daily Average Production or Injection Data~u"m*~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1900 1900 130 100 Treatment description including volumes used and final pressure Prior to well operation Subsequent to oper. ation Daily Report of Well Operations [] 13. -- 21,756 Copies of Logs and Surveys Run ~ 14. Attachments 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Roy D. Roberts Signed ,/~'.~,.-~; '~, Form 10-404 Bev. 12-1-85 Title Dateo7'4/87 - Submit in Duplicate APPLICATION FOR SUNDRY APPROVALS ~ . 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator UNOCAL (ARCO Alaska, Inc. is sub-op.of King Salmor 3. Address P.O. Box 1990247 Anchorage, & .~ ~.4. ~- ..,- ~.~ .,- .,.L L / AK 99519-0247 4. Location of well at surface King Salmon Platform-Leg 2, Cond. 12 617' FSL, 131'FEL Sec. 17, 9N, 13W At top of productive interval Seward Meridian At effective depth At total depth 10500/9717 11034/10219 11094 11. Present well condition summary Total depth: measured 11094' feet true vertical 103,7~. feet Effective depth: measured 11036 feet true vertical t0319 feet Casing Length Size Structural Conductor Surface Intermediate 2470' 13 3/8 Production 11081 ' 9 5/8 Liner Perforation depth: measured true vertical Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) KB-100 ' feet Tubing (size, grade and measured depth) 6. Unit or Property name Trading Bay Unit' i. 7. Well number 8. Permit number 9. APl number 50-- 133-20148 lO. Pool 'McArthur River Fi id Hemlock Reservoir Cemented Measureddepth Yes 2470' Yes 11081' 110550 - 11030 C. VT. LOCK"WOOD True Vertical depth RECEIVED S EP 3 0 ]986 9860 - 10318 Naska 0il & Gas Cons. (;omm!ssien Anchorage 4½" 12.6# N-80 BTC @ 10513 Baker "F' @ 10495 Packers and SSSV (type and measured depth) Otis Ball Valve 3.812" ID @ 263' Description summary of proposal ~ Detailed operations program [] BOP sketch [] 12.Attachments Date approved Date 9/25/86 13. Estimated date for commencing operation 10/15/86 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~_~/_~. ,~3~ ~-~¢~ Title Envirorm'tental Enqineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ,.,.~/ [] Plug integrity [] BOP Test [] Location clearanc, eI , T ' ~rove~ E~,'' ~ :~ ~ ~:~: ¢' by order of Approved by ~'~ [~¢[~][[ ~. ~l~ Commissioner the commission Date Form 10-403 Rev ~85 Submit in triplicate . -.,... This notice is to follow up a verbal notification to Lonnie Smith on August 22, 1986, re- garding tubing/casing communication in injection well K-II. The 9 5/8" casing in this well is in pressure communication with the 4 I/2" tubing. We propose to evaluate and restore the mechanical integrity of this well with the program outlined below. Should our diagnostic work show problems more extensive than anticipated, we will file another Sundry Notice at that time. Diagnosis and Wireline Conveyed Repair I. Attempt to packoff sliding sleeve (OTIS "CX" at 2383) with'blanking sleeve 2 Pressure test casing to determine success of packoff a) Bleed casing pressure b) Pressure test casing to 2454 psi, (.25 x TYD of packer) 1 If packoff fails: a) set 4 I/2" tubing plug in nipple @ 10462' b) test tubing and casing to 2454 psi to check integrity of casing and packer If testing in #3 indicates the casing and packer are holding pressure, a) run electric logs to identify location of tubing leaks b) repair tubing leaks with wireline conveyed packoff sleeves and tubing stops c) retest 4 1/2" tubing and 4 1/2" x 9 5/8" annulus If testing in item //3 indicates a leak in the packer or 9 5/8" casing, repair work could not be performed with wireline, so another Sundry Notice wi~ be submitted at that time. MEMORANqUM Stat¢-,)o Chairman TH RU: Lonnie C. Smith ~zfP/ Commissioner~"~ v FROM' Edgar W. Sipple, Jr. Petroleum Inspector DATE,: September 29, 1986 f Alaska FILE NO.: D.EWS.68. · .. TELEPHONE NO.: SUBJECT: Mech Integrity Test ARCO. King Salmon K-4, K-7, K-ii McArthur River Field Thursday, September 25~ 198~ I traveled this date to ARCO King Salmon Platform t° witness e mechanical integrity test on 'the: subject wells. The test commenced at 11:45 a.m. on K-ii. They. were injecting inlet water during the test. When the' injection pressure was building up on the tubing, the casing pressure came up. K-II failed because of communication problems on this well. We did not get to test K-4 or K-7 because of mechanical problems with the injection pump. I filled out an AOGCC Mechanical Integrity Test Report which is attached. In summary, I witnessed an unsuccessful mechanical integrity test on ARCO K-II, King Salmon Platform, McArthur River Field. Attachment 301 A(Rev 10-84) Form REV. 9-30-6 9 S~brn~t "Intentions" in Triplicate & "Subsequent Reports" m Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMI'rTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-L1CATION 'FOR P'EH~i']~~-L' 'for such'p~o~osal.~.) 0IL ~ GAS WELL WELL [-] OT~ER Injection Well 2. NAME OF OPERATOR *Union 0il CO, of CalSforn~. 3. ADDRESS OF OPERATOR 909 W. 9th Avenue, Anchorage, Alaska ~01 4. LOCATION OF WELL At surface 617'N & 131'W fr SW Cr Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 100 ' KB 14. Check Appropriate Box To [ndi,cate Niature of NO~tice, Re, AP1 NI. rMY_/I/CAL CODE 70-!~$-20148 LF~E D]~IGNA/'ION A/~D SERIAL NO. ADL 17594 , 7. IF IiN-DIAN, ALLOTTEE OR TRIBE NA1VI. E 8. UNIT~ FARlVI OR LF.,ASE NAME Trading Bay Unit 9. V~ELL NO. K-11 (32-20) 10. FI_ELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HO'L~ OBJECTIVE) Sec 20, T~N-R13W: SM 12. PER/VIIT I~O. 68-8~ ~ort, or 'Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR %','ELL CHANOE PLANS ~Other) ! ..... SUBSEQUENT REPORT OF: WATER SHUT-OFF F REPAIRING WELL '__X! FRACTURE TREATMENT '~! ALTERING CASINO (NOTE: Report results of multiple completion on Well Completion or Recompletton Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · 9~7-70 Removed x-mas tree and installed BOPE. Pulled, sonoscoped, then reran 4-1/2" 12 6# N-80 butt tbg and set into model "F" pkr ~ 10,495'. String had' 18' of seal assy, 4-1/2" "N" nipple ~ 10,462', C~ mandrels (run closed) ~:6,113', 5,330', 4,101' and 4-1/2" ball valve ~ 263'. Tstd 9-5/8" csg w/1500 psi for 15 min OK. Removed BOPE and installed x-mas tree. Tstd w/5000 psi OK. Released Rig 12:00 noon 9-9-70. *Atlantic Richfield Co. sub-operator (Thi, sp&ee for S~;te~ffice APPROVED BY CONDITIONS OF APPROVAL, IF A correct TITLE Dist. Drl§. Supt. DATE 10/2/70 TITLE DATE ,~ Insttu;fions On Reverse Side Approye~' Copy Form P--3 REV. 9-30-69 S~brnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO. N CO,MMrFI'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'ER~Vii'f~-~' '/or such'p~o~osal~j · ~ 1. OIL ~-~ GAS ' F-1 OTHER ~EL~ ~ELL Injection well 2. NAME OF OPERATOR * Union Oil Co. of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION OF WELL At surface 617'N & 131'W fr SW cr, Sec 17, T9N, R13W, SM ELEVATIONS (Show whether DF, RT, GR, etc. 100' KB Check Appropriate Box To I,ndicate N, ature of N~tice, Re NOTICE OF INTENTION TO: FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS ~Other) 5. AP1 NUMERICAL CODE 50-133-20148 6. LF_,ASI~ DESIGNATION AND SERIAL NO. ADL 17594 7. IF Ilk-DId,N, ~J~LO'l-r~.k~ OR TRIBE N~MVLE 8. UNIT~ FA/R/VI OR LEASE HAME Trading Bay' Unit ~. w~ N'O. K-II (#32-20) 10. FL~L,D A~ND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 20' T9N, R1SW, SM 12. PERiVIIT NO. 68-83 ~ort, or Other Dat~ ' SUBSEQUENT REPORT O~': WATER SItUT-OFF FRACTURE TREATMENT SaOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENTS (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, We propose to pull the present string of tubing fr~n this injection well, inspect it, re-.run same. We will perforate an upper section of the present injection zone w/2 shots per foot as follows: ~ 10,505,,550 Well is no~ selectively perforated 10,550' to 10,940' JUL. ~ 4 19'tU Dtyi$1ON OF OIL AND GAS ANCNO~GJ th~o n~ 16. I hereby certifY~ ~t.. and corr~t (This space for ~t~te o ce ) . CONDITIONS OF APPROVAL, / DATE 7--17-70 See Instructions On Reverse Side Transmitted,,..,....,,,~'~' ....... ~t.h ,..:~-e thc fo].., Run No. Sepia Blue Scale ~n;:iuc'tion .... v leer'*:,:. ~.~...i. ~-,,os~,-9,~' K-7, K-3 ~ K-il ~--ea. ~'~. --'~ [.,u,,l"" '~ induction ua'' ..... ~.c,~-' ~,,~ Sonic/Caliper Log B!-iC Sonic, uamma Ray lx'~s Soaic/ Calipez/ ~" b.,..~,~a Ray Log ~ ...... Formation Sonic Log Dens ity..Gan'm~a Log Formation Density '~ Nm~tron I,og Formation "~ aeu~.~on LoS (Fn). CDM or.!figh Rcso!ut.ion Dipmeter' C~,,, oaicty Print' {.:i~;i c:' Poiy~.:og, .,= Pict Proxin:i ty-Mic~2ol o2/Ca I. iper I,og ,x,.',.i -i~w~ ~Y'Oi'i [OC' Gam:'r:a RRB'. Col ~ar '~,.,o .... Cement. Bond Log I, itid 1 o g Core "' ........ ipttions, ' .... ', ...... No Core D~. o,.,,. Core' Analysis Core Chips Sample Cut' l)irill Stem Test , . .,p~.rcatJgnal Su"~'e~'s DiViSiON OF Re. turn ..... 4" .- ~,.; 0~"--.~.' ,¢ Califo, ni". 'o0 ..... ,.c~.e...p~. t.o' ,xo~',%~¢!~,O ~}-i,'i%onc :' a '.. r' .t~::80; f'..::'~:~li, St ...... , Alaska 09503 Form P--3 REV. 9-30-67 . STATE OF ALASKA Submit "Intentions" in Triplicate & "S~bseciuent Reports" /n Duplicate OIL AND "GAS CO NSERVATI O, N, ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a di££ierent reservoir. Use "APPLICATION FOR PEH1VIIT--" /or such proposals.) 1. OiL oas [] WELL WELL OTHER 2. NAME OF OPERATOR *Union O±1 Company of California .... S. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd. ,Anchorage,Ak. 99503 4. LOCATION &F WELL At surface 617'N and l'31'W from SE corner, T9N, R13W, SM Section 17, 75~. API NUbI. EH/CAL CODE 13. ELEVATIONS (Show whether DF, RT, GR, etc. 100' K.B. 14. 50-133-20148 6. LEAS]~ DESIGNATION A_ND SERIAL NO. ADL 17594 7; IF INDIA.N, ALLOTTEE OR TRIBE NA1ViE ~'.' UNIT, FA~{~{ OR LEASE NA/~E Trading Bay Unit WELL NO. 10. FIELD ~D linGO.L, OR WILDCAT McArthur River-Hemlock 11. SEC,,. T., R., M,, (BOTTOM HOI2~ OBJECTIVE) Sec. 20, T9N, r12. PEPS/LIT NO. 68-83 Clmck Apprc~priate Box To I~ndi'caSe Nlature of N~oti'c'e, Re )oft, or ~Other R13W, SM NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OB ALTER CASINO MULTIPLE COMPLETE ABANDON* CHANOE PLAI~S SUBSEQUENT REPORT OF: WATER SIIUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SH.OOT]NG OR ACIDIZ.ING' ABANDONMENT* (Other). (NOTE: Repor~ results of multiPle completion on Well ~Other) Completion o.r Recompletion Report and Log form.) , 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, We propose to conduct a water injectivity test on this well pending final determination on the secondary recovery program submitted to the Oil and Gas Conservation Committee. We propOse t° start this test approximately February 1, 1969. No Changes will be made in the mechanical status of this well prior to the injection of water. J DIVISION OF O:L AbiD GA3 ANC I(D]L . f, *Atlantic Richfield Company sub-operator. 16. I hereby C~rtify~ SIGNED is true and correct ~. Taiie¥) TITLE Dist. Drl~. Supt. DATE 1/27/69 See 'instructions On Reverse Side Form ~o. ~---4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPO'RT OF ~DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE OIL ~ GA8 O OTHER WELL WELL 2. NAME OF OPERATOR *Union Oil Company of California -~. XD~)R]gSS OF OPER~TOR 99503 507 W. Northern Lights Blvd. ,Anchorage, Alaska 4. LOCATION OF WTM 617'N and 131'W from SE corner Section 17, T9N, R13W, SM ~. AP1 NUME~/CAL ~ODE 50-133-20148 ~. LEASE DESIGNATION AN'D SE1RIAL NO. ADL 17594 ?. IF INDIAI~T, ALOTTEE OR TRIBE NAME 8. I/NIT,FA/tM OR LEASE NA3~E Trading Bay Unit 9. WELL NO. K-11 (32=20) 10. ]fIELD AND POOL. OR WILDCAT McArthur River-Hemlock - 11. SEC., T.. R., M., (BO'I'FOM HOI.~ o~ Sec. 20, T9N, R13W, SM 1~-, PER_MIT NO. 68-83 13. REPORT TOTAL DEPTH AT END oF MONTTI, CHA/~GES IN HOLE SIZE, CASING A1N-D CEMENTING JOBS INCLUDING DEPTH SET A2NI) VOLUATES USED, PERFORATIONS, TESTS A_ND RESULTS. FISHING JOB~, JUI~K IN HOLE A_ND SIDE-T~LACKED HOLE ANT) A.NY OTH]gR SIGNIFICA~NT CHJtNGES IN HOL]~ CON/)ITIONS. T~rading Bay unit..K-11 ...... (3.2-20_)_..-November., 1968 Ran Schlumberger DIL from 11,094'. Ran and ~emented 9-5/8" 47% P-110 and N-80 casing ~ 11,081' w/1000 sx Class G cement mixed w/l% D-31' Ran = bit and 9-5/8" casing scraper, drilled out cement to float collar 11,036'. Tested casing to 2000 psi, OK. Ran Schlumberger CBL w/GR 11,033-9500'. Ran and hung 4½" 12.60% N-80 tubing ~ 10,517' w/9-5/8" Brown RSP packer ~ 10,479' and 3 Otis gas lift mandrels ~ 4623' 3879' and 2390'. Removed BOPE, installed Xmas tree. Tested tree and lines to 5000 psi for 15 min., OK. Set packer w/3000 psi, held for 30 min. -. Tested packer and annulus w/1000 psi for 15 min., OK. Perforated four %" holes/ft 10,550-675' 10 695-846' and 10,866-11,030' , , . Ran and set gas lift valves in mandrels ~ 4623', 3879' and 2390'. _.Rig released 1:0.0 ......... BEC 1 6 I968 DIVISION OF Oil AND GAS *Atlantic Richfield Company sub-operator. t2% I lJlllJl .~ Dist. Drilling Supt. vA~ 12-13-68 - ~ ~ ~' I VVVV"'~'l " N O~T~'__~Repo¢! . / on this ~orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines ~Minerals by the 15th of the succeeding month, unless otherwise directed. · SUBMIT. IN DUPLICA .I k ~TATE OF ALASKA (see other structions on reverse side OIL AND GAS CONSERVATION COMMITTEE i i iiii ii III I III~ I i I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG la. TYPE ~0F WELL:j on, [] w~.n~. ~J ~;aswr. Ln CJ "'ha, Other b. TYPE OF COMPLETION: NI~W ~ W0nK DIFF. Other ., 2, NAME OF OPERATOR *Union~ 0il Company ,. of California 2.A.~a~s~ oF o,E~,T°~ ' ' 507 W. Northern( Lights Blvd. ,Anchorage,Ak. 99503 ~. L~a~ON 6ir ~Z'nC~(-Repo~t';lOCattO~ elea~ly a~dt"'i~ a¢cordan~ with a~y ~tate requirem~.t~ )* At surface 61.7'N & l'31!'W :fr SE corner,Sec. 17,T9N,R13W,SM At top pr6d., intervi~ reported.,below 2124'S.?& 229'2'W fr NE Corner,Sec. 20 T9N,R13W,SM At total d~pth ~ ' - 2250,.S a 2428'W fr NE corner , Sec. 20,T9N,R13W,SM AP1 ~CAL CODE 50-133-20148 ~. LEASE DESIGNATION AND SERIAL NO. ~L 17594 ~, IF. INDiA~, A3.250~ OR I'I:~IBE NA,M~ 8. ~UN'IT,FA.RAff OR LEASE NAME ~rading Bay Unit ~. w~L ko. ' K?ll (32-'20) 10.~FIEI~.:AR~D POOL, OR WY/-~T ~ McArthur River-Hemlo~ 11. SEC;, T,, R., M., (BCYI~OM HOI..~. ' OBjECTiVE) Se~. 20, T9N, Ri 3W, '12..r: .PI,~iRiVIiT 68-83 9-27~68[ 11"I-68 ' [i'.' · 11-8-68! I 100' K.B, ,., . I 62' 18. T(~P.~L D~I~H. M~ &'TvD [19; PLOd,: B~C'K ' ~'a ~D~. ~ ~LTmLE CO~L., [ ~1. ' ' i~TERVALS 'bR ILLED '~1, 094'~'~ '~ 11 "036 :~ ~. ~oW~' , ~o~,~,~ " . ' o,,~ ~oo,~s Z0,550-675 (~) 10 ,'695-846 (~) & Z0,866-11,030(~) Hemlock 9746/;(~v~) i0 317 (Tv~) , il Yes chl~be ~e.r DIL and~Cement .f~. C~G gtrin~s set in well) C~SLNG SIZE ~.:'WEIGHT, DEPTH HOLE SIZE 2 47,0 18" 1050 sx C1 G Gel & 500sm~.~Neat 26. LINEI% I~ECO't%D four ½" holes/ft 10,550-675', 10,695-846' and 10,866-11,030'. ;!~one i ii i I, i i i . /% i , ~1-~-68 . t Ga~ lift - ! A1ViOUNT PULLED D-31 , D~ ~ (MD) I PACKER SET (MD) SCREEN (B/ID), SIZE t , ': ' ' !. t 4~" 10.517 10: 479 ! 29. ACID, SHOT, FR~%CTLrRE, CENIENT SQU~.E, ~C. · AMOUNT:'~ KIND.. OF lViATERIAL USI~" STATUS (Producing or shut-in) Shut-in DAli: OF T~-ST, [I~OU-RS TESTED '[C~IOXE SIZE [PROD'N FOR ~/N A , _I'., I ,I ,:,',, ~ ~W, ~B~G ~G P~S~ [C~~ O~BBL. .... t Vented 32, LIST 0~-aTTaCHMeNTS ~3. I hereby certify/~//he fo~nllmd attached information is complete and correct as determined from alUavatlable records .,~,~ I/f~L ;IlllJg ~,~, Dist. 5rilling Supt. DATE 12-15-68 - I~// I ~--/ , ~ , :", - , ' ~ W /*(See I~tructions and S~ces Jar Additionbl Data on Reverse Side) *~a~t~c ~c~e~ Com~an~ ~-o~e~a~o~. INSTRUCTIONS : -::Generah This form .is designed:for .submittingr-a'i:complete and correct well completion report and log on ' 'C'aij ..... t?pes of:land's a~'..q le~ses !in _ · ... _ ' , - : :.ltemf. 16: Indicate Which elevation' is: used as '.reference (where not otherwise shown) for depth., measure- " 7nen~ts given' in ther"spaces On this'form and in any attachments ....... : . - .-- :'-'items: 20, and 22:: If this w. ell is' cOmj~leted ~foi-'setda~'~'tb' -prC~J6ction from more than one interval zone .(multiple completion), so s~a'te in item 20, an~l, in item 22 show the prc,duci6g- interval, or intervals, · ~.'?op(s), bottom(s)~-and name (;) (if ~a'ny),'Z-(or only,_,the interval :reported in item 30,. S0bmit a separate report ':~ t ~--: ~-~- i'. ;..(page) on this Form,.-adequMe!y identified, for~:each c~dctitional inte, val to be 'sep~:rately produced, show- ._. · .~'ing.',fhe_ ac~itional data, ,perti'ne~.t~to~ such inter-~-al.; - " - ........ ' ,.-- _. :-~ "' ' -' ' ' - - I~_ , . ~ - ~'~ ~.~ ! ,- . : ~ :_. ~ , - 'item26: "sak:ks 'Cement": Attachea~- Su'PPlemeni~j~ re~:~'r:~l's f6~:'this well should Show-the de~ail,~ :0f~an-y' mui-' ' . ~ i --. '" ' ~ ~" ' ' "~ - ' ., - ~ ~ . .~- ,- .~ipl~/-~stage cem~ntin'~g af'CL"ih~, j6~'~ioh' of fhe ~cementing t001. :~.; ~- , ~.. -'. . - C: r-. :. ~..~ :-;... Lz. ~- :.,, --,., : ;Itemz.:28: Sqbmi(..a s~par, ate co~p!.e'!-io:n., report'on this. form !or each inter~,al i~ _...be separafeiy Oj-oducecl. · "(,5ee:'~nstruction ;for items 20 .an'cl;122 above). :h ..... . ~- ;:' .,. . ........... :.. L_': ,- ~ ~ '~. ¢- ~ °,-. - ,. · · ~ ·. ~ ~ -. , · ~ ".~ - . ~_.! : - ~,; _ a4. SUMM'A.I-tY OI~ POP, MATION TF-,STS INCLUDING IN~·I~KVAL TF_.~TED, 'P~URE DA~ ~ ~OV~ O~ OIL. G~. ~ ' : . - . .t'~ "' .- L;: .... ~'. ~ ~ .!- <' "~.~ 'L - 35. '- ~ . ' i "~' r" ' L~ ' '.~A~ AND MUD '~: ' ¢ : ' :.' : "' '"' :' : ~ ~.~ · o ; '.L~. ~ . · . f ~ : ; .,-. .'~ ,.: C.' ~ - ~-'- :.2 : · ~. . .... ,"'. :~ . . · . ~ · . - . ~ ; ,. ' ' ' ' ;~':~": .... ' ...... ' ' ' ~' :: ;:' ge 10~ .. " - - ... ~ ~ No. o aL tops re recor e .- e {' (,/ . . "~ ~.. ' ' . ' . .. .~_ , , _ :.j ..-. :.-. ~ . , : . : - .. . : L", ,' .:. ' ' - '-~ ' '-' . ~,,.. :_. ~ : _ ~': .- : , . ~:.. ~.- ? · _ ..... ; . .. , ....... : . :~. ' ~6. CORE DATA, i~'~Cll BRIEr ,D~CRIPI~ONS OF LITHOLOGY, POROSITY FRAC~R~ APP~NT DIP~ .... ': ' ' ' ,~, . ..... ~ . ' ~ - ':-' ' ~ AND D~EC~EI) SHOWS O~ OIL, G~ O~ W~. '" .-- ,_. ''- · ........ , · ~ .... ' . ; -: . "" t0 9 ~ ' ·: ~ .. ~ .... f'.J ' :'C ; ' ' ' ,,,, '- . , . , C" ,. F '' - ........ -" . · _ 7,' _ ." ' '. . ;: ........... ' : ' - ~' ,.' r.~' ' ~*: .-.. ' . . . , .. . , . , . .~., . ~ ': ~¢..: ~' . , . } "~ .. · .. . .. RECEIVED startcd. Daily work prior to spuddin6 should be summarized on the form 6ivi.g inclusive dar. cs only. DIVISION OF OIL AND O.4~ DALLY WELL HISTORY-INITIAL REPORT ANC~O~ - District Alaska Field ,~',r,~zthu'd River Hemlock County or Parish Lease or Unit TBU K-11 State Alaska ~32-20 Well ,No. Auth. or W.O. No. 1.9-7211 Title Drill De. vel omment Well. from. King Salmc~.. Platform. Operator Mpudded or W.O. Begun Atlantic Richfield Co. Date & Depth as of 8:00 A.M. 9-30-68 2572 10-1-68 2572 10-2-da 2572 10-3-68 3212 10 -4 -68 4,129 Spudded Date 9-27-68 !0 .~: ?-68 6495 TARCO' S W.I. 12.5% Prior. Status Hou~0:15AMif a W.O. TRM o~ . ; KLV ........... Complete Record for each Day Reported 3 ~. (2572) Opening hole. HWK ' REL FILE Mud 74~, Vis. 82"~ WL 10.7cc. S_p_p_udded ~ 10:15 AM 9-2_ ~ ~-6_ 8. Ran 17%" bit 372-400'. Directionally drilled 12¼" hole 400-2572'. Open.-i 12~" hole to 18" 400-890'. Survey: 2572' 22~ S27W, VD 2497.04, S362:04, W301.06. (0) Running 13-3/8" csg. Mud 74%, Vis 70" WL 12.0cc. Opened 12~" hole to 18" to 2497' - · RU to run csg. Started. running 13-3/8'; csg @ 4:30 AM 10-1-68. (0) Prep to drill ahead. (13-3/8" e 2470) Ran 60 jts 61~ J-55 13-3/8 Buttress csg. Cmt 1~"i:~_ o_k__y~ 2470 W/lO50 sx Class G cmt w/10% gel. and 500 sx l~eat c;.~:.% on btm. placed plug w/Inlet wtr, 2000 cu. ft. Plug down w/1500.%- , t~'essure. CI~ ~ 1:45 PM 10-1-68. Float did not hold· Closed valve, held pressure for 4 hrs. CJ. rc out approximately 500 cu. ft. cmt. LD 20" f[ydril and riser. Installed and tested 13-3/8~ BOPE. ~sted pipe rams and blind rams w/5000 psi for 15 min., OK. T~sted dril w/l:.i00 psi for 15 min., OK. Float (' 2427'. (640) Tripping. (13-3/8" ~{ 2470) Mud 76{~, Vis. 46", WL 10.5cc. Finished testing BOPf~. Instulied bit guide:.. RIH w/slick drilling set-uD~ and drilled .,...~"~a'2 .... ~-'-:~.7u'~' . Changed from Inlet wtr to mud. DO shoe an~ directiona!l2 drilled 12%" hole ~572-'{"~2' Survey: 3212' 25° $33W, VD 3084.93, $583.73, W437.00. (23(~6) Drill' ~ c. ~.~ 2470~ ' lng. (13-3/R" ~ bk~d 76. ~-.,-~, Vis. 46 , WL 5.3cc. Directionalty dr~lle.:i_ _~ _~ ~- ,~. 4i2q-64nS' Survey 6257' 20~ S42W, VD ~o:~:~,.67, DA't K Ox'iv:.: l)rill ,'(':- l)i:~t,'i,'t ()fl'i,:,. I':,,t'..i,,,.,,ri,,V: I~ivi:~i,,,, - (720) ~['1~11111 ~ll l~lll h}.l] Ill I~i1!~ I'l~l!:tl', Ji~,W'l.,lilltlll A'; Illi~ Alii }'lill'AiU.li [.!ii{ J'~lll ~l'l.l.~ INSTIIUC'I'ION.N: This form is used during drilling or workover operations. If testing° coring, or perforntlng, show formation nam,: in de:~cribing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work ~,~.r- formed by Producing Section will be reported on "IN'I'EIIIM" sheets until final completion, lleport official or representative test on "FINAl," form. ti)Submit "INTF. IIIM'~ sheets when filled out but not less frequently than every 30 days, or (2) on Wedne,sday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unti.l completion. DALLY WELL HISTORY - INTERIM District Field Alasl.:a County or Parish McArthur River I{emlock Lease or Unit State Alaska ~32-20 TBU K-11 Well No.__ Date & Depth at 8:00 A.M. 10 -10 -68 6910 10-11-68 7242 10-14-68 7792 10-15-68 7988 10-16-68 8190 10-17--68 84. 30 10-18-68 8650 10-21-68 9279 10-22-68 '~q].2 10 -23- (~ ~ 9778 10-24 ' ~ 10,000 Complete Recor~ for each Day While Drilling or Workover in Progress (86) GIH w/bit. (13-3/8" ~ 2470) .MUd 76 5~, Vis 45" WL 4.8cc. Direc~onally drilled 12¼" hole 6824- . . ~ . ,, 6910'. Survey:. 6875' 18¼° $44W, VD 6539.48, S1704.54, Wi222.60. · (332) Drilling. (13-3/8" @ 2470) '~ Mud 75.~, Vis. 44", WL 4. Bcc. Directional!y drilled 12~" hole 6910- 7242'. Survey: 7239' 20° 837W, VD 6828.54, 81785.76, W1271.25. {550) Drilling. (13-3/8" @ 2470) Mud~: 76~, Vis. 48", WL 4.3cc. Directionally drilled 12~" hole 7242- 7792'. Survey: 7744' 20~ S41W, VD 7302.21, 81921.07, W1380.83. (196} Drilling. {!3-3/8" ~ 2470) Mud 76#, Vis. 41"~, hqb 4.3cc. Directio~_~ally drilled ~2¼" hole 7792- 7988 ' . Survey: 7895' 20-3/4~ 843W~ VD 7443.81, S1959.43, W1416.60. (202) Drilling. {13-3/8" ~. 2470) .~ud 76~., Vis. 44", WL 4.3cc. Directionally drilled 12~" hole 7988- 8190'. Survey: 8117"~ 24½~ 841W, VD 7647.5t, 82025.29, W1475.30. (240) DriLling. (13-3/8" ~ 2470) Mud 75:;~:, Vis. 44", WL 4.3cc. Directionally drilled 12~" hole 8190- 8430'. Survey: 8318' 25~ S41W, VD 7829.89, S2089.04, V1530.72. {220) Drillin9. {13-3/8" ~ 2470) Mud 76~?, Vis. 43", WL 4.4cc. Directionally drilled 12}~" hole 8930- 8650'. Survey: 8512' 25° S41W, %.qb 7996.65,-82147.72, W1881.74. (629) Drilling. (lq-3/8" @ 2470) Mud 76.5.~, Vis. 40" WL 4.7cc. Directionally drilled 12¼" hole 8650- 9279' Survey: 9213' 27-'-~a 845W, VD [~:625 85 82373.51, W1791.98 . · · ~ · (233) ~ZI-I w/%J.t. (13-3/8" © 2470) I,~ud 76:i;:, Vis. ~!9.,.... , WL 4.6cc. D~ctiona"ly~ d::<'~led~ 12~" hole...o2'~.-~, _. 9512'. Surveys'9512'. 26° S43W, ~D oo93~:"~ ._.- ~; ~, 824.70. [~9, W1882. ~0. (266) Drilling· (13-3/8" © 2470) Mud 764~, Vis. 40", WL 4.8cc. Directionally drilled !2-~" hole 95~2-~.~. · . . _ ~¢3b. 77, . . 9778' Survey: 9630' 25° S4zW{, VD 9000·q1., S2~ ~' W19i7 44 (222) Dri!.li~?.g. (13-3/8" ~> 2470) c. rllled hole 9778- Mud 75~:, Vis. 41", WL 4.8cc. Directiona!!y q ' ~"='~'~""-.-a 10,000'. Mud loggc $ on (~ !0,000' (c~ 6:00 APt 10-24-68. Surve.~: 9~32' 23~'' S45W, VD 91~5.77, S2563.7]., W!974. 3&~. l)istril,t,t, ion: Thc APove is Correct: O,-ig.: l),'i 11 i,,g .Neet. ion - I)al l'.;,,tt 'i ,~,' ,, ,' i ,, g I)iv i.~ ion (720) (:o-Own,'r (~;) As Al,l~rOl,r i ~,t,c T I'A(:I' N*). 'Y . (NI~Mt;I:I: All. llAII ~ ~l,l.I. IiI:;'I'<:t{Y I.I)liM' t'rh,t,:,l Il 5 A IN,~;'I'IIIICTIONS: This f,,rm is used during drilling or workover operations. If testing, coring, or ~,erfornting, show formstion name in de:,eribing work performed. Number all drill stem teats sequentially. Attach deseripti~: of ,11 cores. Work par- formed by Producing Section will be reported on "INTEIlIM" sheets until final completion, llepork ,fficial or representative test on "FINAl." form. (I)Submit "INTEIIIM" sheets ~hen filled out but not less frequently than every 30 days, or (2)on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unti.l completion. DALLY WELL HISTORY - INTERIM Alaska District .~l.:-]::~ka County or Parish State 4f32-20 Field McArthur River Hemlock Lease or Unit TBU K-11 Well No._ Date & D,..pth at 8:00 A.M. 10-25-68 10,256 10-28-68 10,725 10--29-68 10,832 10-30 -68 I0,973 10-.,1-68 11,073 ll-1-68 1.1,094. 11-4-68 TO I1,094 PBD 11,036 1 .t - - 5 '- 6 f; Complete Record for each Day While Drilling or Workover in Progress (256) Pulling bit. (13-3/8" @ 2470) MUd 75:~, Vis. 41", WL 4.8cc. Directio~ally drilled 12 :' hole i0,000- 10,256 '. ~ Survey: 10,064' 22~g° 84.6W, VD 9400.49, S2624;46'i .W2037.28. (469) Drilling. (13-3/8"'@ 2470) Mud 7~'~.~r, Vis. 40", WL 4.9cc. Dire ct ional ly drilled 12~" hole 10,256~, 10,725'. Top Hemlock @ 10,392'. Survey: 10,311' 2].° S48W, VD 9630.48, S2682.88, W2105.84. (107) Drilling. (13-3/8' ~ 2470) Mud 75Q, Vis. 43", WL 5.0cc. Directionally drilled 12%" hole 10,725 10,832 ' . (14].) GIH w/bit. (13-3/8" G 2470) Mud 75~, Vis. 41", WL 4.7cc. Directional!y. drilled 12~" hole t0,832-. ~' ~qq 24 S2821 25, W2257 69. 10,9'73'. Survey: 10,973' 20° SA5.~g, XfD !0, ...... , . ~ . (100) Drilling. (13-3/8" ® 2470) biud ,c...;.· ~., Vis. 41", WL 4-,9cc. Dire ct ional !y drilled .... ~2t'''.~ hole ...]0,973- 11,0 ;3 ' . (21) Pullin7~ bit. (13-3/.7~" ~ 2470) Mud 7.5~.~, Vis. ~.~.~", ~ff~ 5.0cc. Directiona!!v_ drilled 12!4~' hole.. ].~.~.,073-~ 11,0~4'. . Pulled to 6840', worked thru tite~ h~;~le to 6556' a~ throug} ... tile spot ~, 6079' and 5911' in 18 hrs, then came free. Prep to LD DP. (9-5/8"~,,~ 11,08]_; DIL 11,094.) Mud 75{~, Vis. 45", W'.,~.~ 5.0cc. Ran Schl D~% 1k&q~' (Gcht depth ~1,II 2470'). Ran 262 jts (!1,036.60') 9-5/8" 47~, P-110 and N-80 csg. r;oc:el G differential fill-up float shoe & float collar Have Baker ~" (collar c'~ lI,D~6' ,:. .~ ) w/22 B&W centralizers. 80' interval 11,065- 10,265' & 200' intervals 10,265-7865'. Set cs9 Q 1!,080.52'. ~mpec 100 cu. ft. wtr~.,.~" ~ad, cml w/100c~ sx Class G cml mixed w/l,% D-3!, - ~' ....... ,~- !0 ~ 11-2-68 fol!o~vec~ w/20 cu.~t.wtr a 4536 Cu. ft mud. Cv~ ~'' :40 Bumped U].Ug, ''/~g601~,.,,,.. ~,, . float held_ OK. Instal. leo ~.-.~/,.~ OCT - ' :ested to 5000 psi, OK. LD HT,~P & DCs. Ran 8!~" bit and 9-5/8" (n,~t. to float collar c-> 1t,036' to 2000 psi, OK. POH. Ran Schl CLqL w/GR ]1,O33--~5OO'. ?.:~;S of .. 0 36 ' Dis'o] ace,:] from bond log :L0,]70-10,1[~0'. RZH w/OF.D~ i:o 11, ~ . mud w/SW. Bnckscutfled I hr. Running 4:~:.: tbq. (9-5/S" C~ 1t,08!,~ DIL !t LD q DP. ~'4ad~ 5" x ,~]~" X-ove~'. / Picked N-~:.;0 13t:~ttrc:,:::" ..... %.t)g ,,'/'~--~:/~:'",-,/,, j/ ,..~ Brown ..... '~'"'~ -~- anJ 3 C~t'i,s gas lif!; ~,andre I)i. stribut, ion: The Above is Correct: Orig.' l)rilli~g Section - c:c:- l)ist, rict, ()fl'icc , l".nr;i~,,',~rin/r l)ivisi{,~ - (720) C.-Ownf. r(s) - As Apt~rOl~r l/,./,,io..] ()fl'i ,,, W,~II I;, ,'or,I l"il,, Ti TI,E I'A(;E N~). ' (Nl%fl~l:lt Al.I. IiAII~' ~1:11 III':I'(d~Y I"(~IIM:; (:~)NNI:(:II'IIVIi.Y A~; TIIIY Alii': I'IiI(I'AIII'.I) tq)tl I'.A(II ~Ii,I.. ) INWI'llft¢:TION~;: Thi.~ form is used during drilling or workover operations. If testing, coring, or perforating, show formatxon name in describing work performed. Number all drill st. om te~t,s sequcnLially. Attach description of all cores. Work per- formed by Produc:ng Section will be reported on "INTEIIIM" sheets until final completion, i{eport official or represent, atis, o tent on "I"INAI," form. (1) Submit "INTEI{IM" sheets when ftlled out but not less frequently than every .30 days, or (2) on Wednesday of the wrek in ~hich oil string is set. Submit weekly for workover~ and following setting of oil string unti.l completion, DAILY WELL HISTORY - INTERIH District Field ~.~cAr%l;ur River County or Parish Lease or Unit TBU K-ii State Well No.~ Date & Depth at 8:00 A.M. 11-6-6~~, TD 11,094 PBD 1 ~ O3C' 11-7-68 TD 11,094 PBD 11,036 Complete Record for each Day While Drilling or Workover in Progress Circ Inlet wtr. (~-5/g" ~;? i1,081;- DIL 11,094) ;:.~n and hung 4k" .... 1.2 605~ ~i-80 Buttress tbg C~ 10,5q7', -:~/8'' RS? pkr c3 10,479'. Removed BOPE, installed ;~'r~as tree. "2'ested tree and linc~s to 5000 psi for 15 rain, OK. Circ~ Im!~t. wtr w/Halliburton unit Return wtr ten~Dc'.rature 51° '~ Waiting for wireline tools. (9-5/8" @ 11,081; DIL 11,094) Finished circ Inlet wtr. Changed to fresh wtr. Set pkr @ 10,479' w/3000 psi, held for 30 min. Tested pkr and annulus w/1000 psi for 15 min, OK. Sheared shear-out sub w/5000 psi. RU to perforate. Perforated 4 1/2 holes/ft 10,550-675', 10~695-846't and 10,866- 11,030'. kU to run Otis gas lift valves an~ ball valve. Lost wire-. line tools pulling ball valve from K-2. l)i s tri but. i()~: Orig.: I)rillin~: Sect. ion - 13~,11:~.~ cc:~ l)ist, rict. Office 15,~g i n,',~,' i ,~t: l)iv is i~,, (720) C()-Own~.r (:.;) As Apl,rOl,r i at.~ The Above is Correct.: /' .'~ ~ ) , . -, , . .'. · S 1 (;N ATIII{I': - I)ATE .. TI TI.E (NI~MI~I..II All. I~,[11 Y ~111. IIl:,l'(~llY 1'~1{~3:; I.(}N:,I.('II'IIVi. IY A~4 Tltt:Y AI{F I'HI;I'AhI.'I) I'~)11 FAt:l{ i~ll.l., ) INSTRIICTIONS: Prepare and submit the FINAl. REPORT on tile first Wednesday after allowable ha. been auaigned or .ell is Abandoned, or ,Sold, FINAL ilEPOBT should be .ubmittcd ~lao when operations ~re ~u~peaded for aa ~adefinite or appreciable length of time. On workovers when an official test ia not required upon completion° report coa, f;letioa snd representative teat data in blocks provided. The FINAl. REPORT focm may be used for reporting the entir~ operation if .pace is DAILY WELL ltlSTORY - FIliAL REPORT District Field .a]a?;'ka __County or Parish Mc.A.rtb~r River }lem]ock Lease or Unit TBU K-]. 1 State q-~32-20 Wel 1 No. Auth. or W.O. No.,. 19-7211 ~Title Drill Development Well from Kinq Salmon Plat for.r~!.. ....... 0pc ratom.. Spudded or W.O. Begun A~'l. sntlc Richfield ComDanv Smudde~ Date 9-27-68 Hou]sO:iSA~4 TARCO'S W.I. Prior Status if a W.O. Date & Depth as of 8:00 A.M. TD 11,094 PBD 11,036 ]. L.-..1 l.~G8 ].l-:l 2-68 Complete'Record for Each Day Reported 081; DIL- ~11,094) Opened gas lJ. ft /aandrels,~ ~ d-623' , 3879' and 2390' . Ran and set gas lift valves in mandrels (took 4 runs to set ~ ~623'). ~ re:kea:~e~a ~:.;; 1.0~ n;% 1./-o-6,.,. Ho,ged rig to K-2. Attempted to run 144 hr Otis clock to btm, unable to get to btm due to heavy emulsion 11-8-58. POH, RD Otis. T}lis AM gss lift- ing to clean up. Production :cate iast t2 hfs appro×imately 50 BWPD, tr oil. SI well (~: 3:30 P.;i il'il-60. Produced 406 bbls load wtr and 499 bbls for~ation .'tr for a total of 905 bbls p~:oduced. PB Depth !1.036 Released Rig J:O0 AM Date Classifications (Oil, Uss, etc.) W~r Injection ]1-8-68 Kind of Rig Rotary Type Completion (Single, Du:;!, etc.) Sinqle Producing Method Official Leservoir Name(s)HcArthur River-Hemlo,: Potential Test Data: WELL NO., I DATE. ~H.T I~ FOR F1 PIIMP SIZE, SPM X I,ENGTll RESERVOI Il WATER SIZE '[PRODUCING INTERVAL T. P. C. P. WATER OILGAS OB { ]"EST TIME PRODUCTION OIL ON TEST [""~AS PER DAY AI.,LOWA;~I,E I EFFECTIVE DATE 1 .,.,? .. :, . 'i'l TI.E I',\{;I,: Nt'} ......... (NIIMI~I.i! Al.t, lb\lI.Y ~'t. 1,I 1115'i(HIY l.'(~llM.q (:ON:-;I-:i:I['I'IVI<I,Y Ak; TttI.;Y Alii< t'tiI<i'AIU.:I) i-Oil I,;At:II ~,'EIJ,. ) · INSTI~.UCT!O.~N.~:.. Prepare a~d submit the Ff"~L HEPORT on the first Wednesday after all-wable has been assigned or veil is Plugged, Ab~'=~n~'ux~"'~r Sold. FINAL REPORT ahoul, ; submitted also when operations are su~ ,ded for an indefinite or appreciable length of time. On uorkovera when an o~.e/Cial teat ia not required upon completiok~/report completion and representative teat data in blocks provided. The FXNAL REPORT form may be used for reporting the entire operation if space is available. · DAILY WELL HISTORY - FINAL REPORT District Alaska County or Parish Kenai Borough State Alaska Field Cook Inlet - McArthur River Fld, Lease or Unit TBU. K-il .- Well No.32-~ Auth. or W.O. No. 19-7252 Title Pull.. Tubingl & R. ep%ac.e Pkr, ' Operator Spudded or W.O. Begun Atlantic Richfield Company Date - 5-Oq-6q Hour - TARCO'S W.I. 12.6% __ Prior Status if a W.O. w~r TnJ~rinn Date & Depth as of 8:00 A.M, 5-09-69 5-12-69 Old TD 11.094' Complete Record for Each Day Reported ll,094''TD ·ll,036''PBD Perfg Moved~crew'in'from'K-10. Filled'hole &circ w/filtered Inlet wtr, (recov small amt of oil & condensate, Removed tree, installed riser & BOPE, tstd riser & hydril w/2000 psi, OK. Pulled on tbg,3d jt above pkr badly cork- screwed. Pkr was not set. Pulled tbg, ~D pkr, GL mandrels & ball valve. RU Dresser-Atlas to perf.. Now perfg. Hole taking wtr. -. 11,094' TD 11,036' PBD .- · ~i~.'"' -'-~ ...... .'---- _ Reperfd 9-5/8" csg 10,940-10,910, 10,850-10,820, 10,780-10,750, 10,725- 10,695, 10,640-10,550. w/4 hpf. w/Dr~ser-Atlas 4" csg gun. Ran &-set Baker 9-5/8" x 4-3/4" Mercury:Model D retainer prod pkr w/flapper valve removed @ 10,495 w/Dresser-Atlas WL setting tool. 4-1/2" tbg landed @ 10,511'. Ran 17' Baker seal nipples on 348 its & 4 subs (10,454) %f 4-1/2" 12.6#~ N-80 buttress tbg,' ball valve @ 384'. Spaced out seal its. Landing tbg on OCT tree w/locator sub 1' above pkr. Btm seal assy@ 10,511'. Removed BOPE & r'iser, installed Xmas tree. Tstd tree-&..hanger w/5000 psi, OK. Pulled Otis dummy sleeve in ball valve. 'RR'@~12'Mi'5-09-69 & moved'to'.K-13. New TD Beleased Big 12 M Date PB Depth 11,036' Classifications (Oil, Gas, etc.) Wtr Inlection Well Producing Method Potential'Test Data: 5-09-69 Kind of Rig Workover - RotaKy- Type Completion nr~ (Single, Dual, e~c.) TRM Official Reservoir Nqme(s) Hemlock KLV H'¢¢~ .... REL PRODUCTION WELL NO. ~ATE RESERVOIR PRODUCING INT'EBVAL OIL OB TEST TIME OIL ON TEST C~'~EB DAY GAS - 32-20 Hemlock 1094'0-1055 0 ' . , , PUMP SIZE, SPM X. LENGTll CHOKE SIZE T. P. C. P. - WATER ~; COB' GRAVITY ALLOWABLE EFFECTIVE 'DATE · ' CORRECTED . · '' ' ' Water '- Injection - , ..... W~I 1 Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File Th, Above is Correct: SIGNATURE - ~ DistriCt Drilling Supervisor T 1 TLE 5/21/69 DATE ~NSTRUCT~~epsre and aubnit ~he FINAt "PORT on t~e first Wednesday after .llovable baa been aaalgned er veil ia Plugged, ~band~ned, or Solg~ FINAL REPORT should be~...~onitted atao vhen operetiona are suspen,' for .n indefinite or appreciable ~en[th of tine. uorkovera ~hen an offici-~l teat ia hOC required upon completion. ~rt completion and representative data in blocks provided. The FINAL REPORT fora may be used for reporting the entsre opera~ion if space is availeble. District . Alaaka Field. McArtbur Miver ' DAILY WELL HISTORY - FIHAL REPO-RT County or Parish Kenat Borough Lease or Unit TBU Well No.22=2D Auth. or W.O. No. 19-7P5~ Title _ Puql Tubing & Replace Packer. - ... Operator.- Atlantic lRiebf~eqd Company Spudded or W.O.. Begun_ wmwkmxr~w Date 5-91-g9 ,,Hour - TARCO' S W.I. Prior Status if a W.O. _. p~ .. Date & Depth as of 8:00 A.M. 5-2~-69 5-22-69 5-26-69. Complete Record for Each Day Reported · Moved.~ig #57 to Conductor #12, Leg 2. Removed tree & OCT tbg hanger. Reset seals back into pkr w/15,000# on locator sub. Seated at same depth as in original spacing. Pulled tbg. Now dressing seal assy. Old TI) ll,09h' 11,09~' TD 11,036' PBD RR. Finished POH. Dressed all seals. RU Hydrotest. Tstd seal & all tbg to 3500 psi. Ran 2 Otis GL mandrels & Otis ball valve nipples @ ~l~'.. One GL mandrel ~ 2~50', one ~ ~850'. Set locator sub on pkr ~ 10,~95'. W/ mandrels pulled & gas valv~ opened, reversed down tbg for 5 mins ~ 1800 psi, 7 BPM. No returns thru csg. Spaced out w/locator sub 1.~0' above pkr. Removed BOPE& riser. Installed Xmas tree. Tstd tree & hanger & ball valve nipple to 5000 psi', OK. Pulled dummy ball valve. RR ~ 3:30 AM, ,~-22-69,=moved over K-h. MIR #57 @ 6 AM, 5-25-69. Removed tree & tbghead. Added h.13' ~-1/2" tbg sub below top jr. Installed turbine hanger & Xmas tree. Tstd tree to 5000 psi, OK. RR @ 12 N~ 5-25-69. Started injection pressure ~ 1750 psi. In 12 hrs, CP 500 psi, 1B-l/2 hrs 700 psi. Shut well in. CP bled to 75 psi in 2 hrs. ,, New TI) PB Depth .... 11,036' Released Rig Classifications (Oil, Gas, etc.) . · Producing Method 12 N Date 5-25-.69 Water Injection Kind of Rig Type Completion (Single, Dual, etc.). Single ..::~i!Official Reservoir Name(s) . -. ')'t :' ' Workover Potential Test Data: ' -- : ..... T IE ' .,- ..... -, ............. , ......... ,,,., , p OIL OR TEST I~ [ RODUCTION ' WELL NO. DATE BESEBVOIB PRODUCING INTERVAL GAS : ' .... OIL ON TEST GAS PER DAY , , , , ,, ,,, , ,, . ' , _ , ., ,, , . 32-20 - Hemlock lO,gh0-10,550 ' - . - · - - · · . - , , ~ , ,, , , , , , ,,, , , , ,, ,, , ,, , ,, PUMP SIZE, SPM X'LENGTH CHOKE SIZE T. P~ ' C. p. WATER ~ i GOR .GRAVITY ALLOWABLE EFFECTIVE DATE CORRECTED ..... , ~ ' - ''', : . . -. Water ; - ' ~ u ~Vn~ec*~on . · t ,, , ,, , k , ..... , , , , · Distribution: The Above is Correct: Orig.: Drilling Section - Dallas cc:- District Office -/~'-' "~-ff /':/'~-'~"~ g-07--69 Engineering Division - (720) ~[GNATUnE - // ~ATE Co-Owner(s) - As Appropriate District~{llin~ Supervisor .... 'u--.,.--:--...,. Regional_Office, Well Record File TITLE ........... - -':.-'- -- - ~- ..... ".~ .'.-,'--( (.'~.~ f: '":.'.. :?~:F_~:-¥..::~ "7.?~!~-~.(:]~(/~/.-)~:~F. ~C:T~ 7: :~7~:q~ -t~-:?'~-'~?~'.~:~-~-~:~-~-~:-~.:~:--:~-~_: .... - ...... ....... ............ 11 I1, STillY FOBMS CONsECdT'i'V'~i,Q 'Ak'THEY'-~ii~ ~;'¢;~iON OFOiLANg GAS Hemlock INSTRUCTIONS: Prepare and submit the FINAL REPORT on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold, FINAL REPORT should be submitted also when operatloqs are suspended for an indeflnlce or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The FINAL REPORT form may be used for reporting the entire operation if space is available. DAILY WELL HISTORY - FINAL REPORT District South Alaska . County or Parish Kenai Borough.. State Alaska Field McArthur River .... Lease or Unit TBU K-11 Well No,32-20 ,, Auth. or W.O. No. . 1§.7229 Title Pumped Diverting,Material in K-11 Operator- Spudded or W.O. Begun Atlantic Richfield Comoanv - - , Date . 9-7-70 Hour TABCO'S W.I. Prior Status if a W.O. 13.6% 12.6% .. , Date & Depth as of 8:00 A.M. 9-8-70 11094' TD 9-9-70 i1094'TD 9-10-70 li094'TD Complete Record for Each Day Reported l1036'PBD - Filtered inlet wtr. Mvd rig to K-11. RU flow line, remvd x-mas tree, install BOPE. POH. LD tbg, broke all collars, sonoscope tbg. Re-dressed Baker seal assy. RIH. L1036'PBD - Filtered inlet wtr. 4-1/2" tbg hng @ 10513'. Ran & hng 10429' (347 its & 3 pups) of 4-1/2" 12.6# N-80 butt tbg@ 10513'. Broke out all threaded ends & applied iliquid "0" ring (teflon base) thrd dope. Stabbed into Baker model "F" pkr @ 10495'. Press 9-5/8" csg w/1500 psi for 15 min, OK. Spaced out tbg w/locater Sub 1' above pkr. Strng had 18' of Baker seal assy, 4-1/2" Otis "N" nipple @ 10462', CX mandrels (run closed) @ 6113', 5330', 4101' & 2381' & 4-1/2" Otis ball vlv @ 263'. Landed tbg, remvd ROPE. 11036'PBD - Filtered inlet wtr. Instld x-mas tree. Tstd hd w/S000 psi, OK .... pulled bali vlv dummy sleeve. RR @ 12:00 NOON 9-9-70. Mvd rig to K-13. FINAL REPORT. '~ ~ .... DiViSION OF OiL AND GAS ANCHOR'AG~ Old TD 11.094' New TI) 11094' PB Depth 11036' Released Rig 12:00 NOON Date Classifications (Oil, Gas, etc.) Water Injection 9-9-70 Kind of Rig Type Completion (Single, Dual, etc.) Producing Method Official Reservoir Name(s) Workover Single Hemlock Potential Test Data: WELL NO. DATE RESERVOIR PRODUCING INTERVAL OIL OR TEST TIME ..... PRODUCTIO,~ GAS OIL ON TEST GAS PER DAY ..... GBAVI'TY ALLOWABLE EFFECTIVE DATE PUMP SIZE, SPM X LENGTH CHOKE SIZE T. P. C. P. WATER % GOB CORRECTED · .... "<':'[ ,' ', ,.'"''..,. , ' '-: i ' ';. '" ""~' "":"~' .' <'J-< :')~i~ ',::..i>.':' '" " ' " __ _ __ _..D~st.r~hu~-~on: .. "~'"" · Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File The ABove '~i's ~ ...... "'.,:-' ". . ~- · . -, ..-. - ,.,..~' '.,... ,, ~'..[ .'.- .~"~~'~/~.~'~'""-' ',September 10, 1,9~0 Distr~rillina// supervisOr . ,, TI TLE PAGE NO. 8 . (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) 3B-459-3 INSTRUCTIONS: This £orm is used during drilling or workover operations. If testing, coring., or perforating, show formation n~'~me ~n d'escribing work performed. Number all drill stem teats sequentially. Attach description of all cores. Work per- forned by Producing Section will be reported on "INTEHIM" sheets until final completion. Beport official .or representative test on "FINAL" form. (1) Submit "INTEHIM" sheets when filled out but not less frequently than every 30 days or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following ~etting of oil string until completion. DAILY WELL HISTORY - INTERIM District South Alaska County or Parish Co~k Inlet State Alaska Field Lease or UnitKing Salmon Platform K-11 Well No.___ Date & Depth at 8:00 A.M. 12-17-70 Complete Record for each Day While Drilling or Workover in Progress ,. PRODUCTION 12-14-70 - RU GO Internat'l. Ran inj profile w/spinner & RA tracer & temp tool. Ran 4 hr temp survey. Ran 8 hr temp survey, RD. Mvd to K-2. GO PBD 10980'. Inj rate during survey 15288 BWPD @ 2250 psi. . The Above is Correct: DATE 'I'1 TI (NI ,~,~l~l. Jl &l.I.I.~4li,Y I;-I.i1.1. I!i' t'i~lCf l:oiiM;; IO,,"~Y;t.¢ !!TIVIt.Y AS 'I'IIt,:Y &il!,: l'lli P^Iif, D 1,01i I.:A(H ~.FI,I,, ) ' COMPANY A?L'LANTIC ~.ICHFIELI) FIELD C001( INLET JOB NO. Norther%tern DireCtional Drilling, I LEASE T.B.U. K-il WELL NO.__ 32-20 DISTRICT Alaska ' P. O. BOX ,4--I153 ANCHORAGE, ALASKA g9503 TYPE OF SURVEY e-r..~.. COMPUTATIONS Ferguson DATE September=o°~ 1968 ,- November 8 196 .... s~ Shot ....... ' ' ' ' ENGINEER I~erguson OBJECTIVE SHEET 1 O'.F ' Decl ination '- ' . . · , ........ · , . , , , ,, , ,' , , , . [ .... , ,' ,.: COORDINATE DIFFERENCES RECTANGULAR COORDINATES TRUE VERTICAL SECT'N COU ESE DEl FT Om[CT'L ..... , ' STAT'N MEASURED ~OURSE. DRIFT VERTICAL VERTICAL SECTION DIFF, DEVIAT'N DIRECTION DIFF. NO. ~ DEPTH LENGTH ANGLE DEPTH DEPTH NORTH SOUTH EAST WEST NORTH SOUTH EAST' WEST .... ~'r ~' .... ' " " " ' " " ' . ".. ' ERY ,.~ 369 0035, 369 0C 369 00 M 24 W 2 37 . 596 ........ ~ ...... , __ 545~ 60 4°10~' 59 .84~ 544 77 + 155 .4 36 ~ 7q w,,9_25 ] ~ A ?~ 6 ~n~ ]~ 132 , 760: 2]_5 ,5.°15~ 21~ 10 .75S g7 600 19 ~67 ~ 72 w' 25 6 0~ 18 7!. ~ 12 ~13 ,., 32 .... . 940 130 5°15' 179 24 938 1t [ ..17.75 939 ]6 &7 N gq ~,7 ;5.25 2g 16 A7 12 &2 /~g . ' 974 34 5°45': 33 83 971 94 ~ 20.] 5 2 0 3 ~1 S RI W ~.5 25 5q q q7 11 gq '~1 ~,q7 , . 1040 .66 7° 65 51 1037-~5 26.95 630 8 04 ~ r63 W ~,2.25 ..... 3 65 . 7'16 8 24/ 59 03 i 1070 '30 7°45' 29 ~73 1067 18 30.55' 330. ~kO5 49 ~',7.25 2 66 3 06 5 58 ........ 62 I. 1100 30 6°1 " . 5 29 82 1097 ~0 33 81 326 3 27 32 3.75 2 77 1 73 2 gl 63 g2 . -. 1183 83 3°15'~ 82 14 '!!79 14 45.7! 1~90. 11~'1 33 2.75 9 99 6 48, 7 18 .,, 70 30 1246j 63 )o 62 22 ..t241 36 55.55 9J34 .. 9 86 '39 3.2~ 7 66 , , 6 21 ]4 gA 7A I i · . 1431 19~ 1.2°30'~ ~g 11 1422 46 92.99 26!4 26 40 42 6.25 [9 ~% 17 67 43 _- ~,~_ , ' I N1 ~ 1557 126 L5° 121 70 1544 16 i25.34 32~5 32 61 43 7 25~ !3 ~5 22 24 67 15 123 ' , 1679 122 t7~ 1~6 67 1660 B3 160.20 34~6 35 J67 48 '2.25 ~3 ~7 26 51 __91 02 149 ]3. 1802 123~ [9~15'! 116 12 1776 95 199.97 3977 40 55, 47 '1.25 17 56 29 66 118 68 179 1934 1~2 8~30'' 125] !8 1902 13 241.12 4215 4l 3g 25 'D_75 ~7 ~7 17 7D 154 65 197 2174 179 ~0° 168 21' 2128 D2 321.14 60~I 6t 22 27 8.7~ 54 55 27 79 '229 20 ~. 233 ~7 SP S~ .:' ' " · ~ COMPANY ATLANTIC RICHFIELD FIELD COOl( INI,ET JOB NO. Nort~/esfern I)ire~fion~l I~rillin ~ i.~~ T'B g. K-il · ' g LEASE · WELL NO. 32-20 · '~. o. ~ox ~--,,,3 , -- DISTRICT., Alaska ' · ..~ .' . *.C~0~A~, AL*S~A 9~S03 TYPE OF SURVEYS'zg~iG S~o~ COMPUTATIONS ~prgtl~q DAT~p~m~r ?~ l qr, q ~T~ .... ~1~ R Dec Jination ENGINEER ~er~so~ _ OBJECTIVE SHEET 2 OF~ STAT'N MEASURED ~OURSE DRIFT VERTICAL TRUE COORDINATE DIFFERENCES RECTANGULAR COORDINATES NO. DEPTH LENGTH ANGLE DEPTH VERTICAL VERTICAL SECT'N COURSE DRIFT DIRECT'L DEPTH SECTION , DIFF. DEVIAT~N DIRECTION DIFF, NORTH SOUTH EAST WES~ NORTH . SOUTH ' EAST WEST . . . .. 2923 211 ~4° ~92 75 2819 60 606.09 8~ 6~ 85.81.~32. 3.75 72 77 ~47. ~~ ~0i7 94 ~A° .Z ~ 85 37 9905 ~,7 4.24 3R 15 RR 2~ _ _ _ ~ · 3370~ 15~23~_~ 140 48 3225 ~+0 793.24 65 42 65 50 33 2 75 54'93 35 69 638 65 r. 472 66 3670__ 83_ 14~45': 75 38 3496 64 921,14 34 68 34 75 __32.__3,75.__~Z9_~.7. 18 41 ~ 34 ..... .RS~S 18q~ P4°4q' l~'~ , ,~, fll .R~4 6~ 99R,3~ 77 ~9 77 A5 ~ ~ 75: ~6 ~0 39 89 Ri3 74 580 47 3980 125 24~15' 113 97 3778 62 1049,49 51 16 51 34 31 4,75 t~4.~1 26 44. 857 75 606 91 4129 149 !3° 137 15 3915 77 1107.59 ~=°,~ 10 58 ~2 32 3.75 ~9 37 ]0 85 907 12 637 76 41.65 36 13~ 33 14 3948 91 1121,63 14)4 14 07 32 3,75 L1 93 7 ~5 919 05 645 21 ' 4345 180 Z2~15'' 166 59 4115 50 1189,55 67 .92 68 15 31 4,75 5~ ~2 ]5 10 9'7747 680 4567 222 ~I°45'' 206 19 432t 39 1271,73 82 18 82 27 33 2,75 ~9 O0 44 81 1046 47 725 12 4690 123 ]1°30' 114 43 4436 i2 1316,66 44 93 45 08 31 4,75 ~0 lO 58 13 1126 57 773 25 . 4879 189: ~0~15' 177 '32 4613 ~4 1381,74 65 08i65 41 30 5,75 56 55 32 71 11~3 22 805 ?:6 . . 5034 155i ~1~15"~ 144 46 4757 90 1437 52 55 78 56 17 29 6 75 ~9 13 27 23 1~32 35 833 ,'.~ .I .. 5~60 226 21~ ~ ~ ~iu 99 4968 ~9' 1518,35 80 83 81 O0 32 3,75 S8 39 ~2 92 1301 04 876 Il 5~61 .201 ~1° 1~7 65 5156 56 1590.33 72 03 72 O~ 35 .75 59 31 41 32. 1360 05 9~7 ~3 · . .'. · COMPANY ATLA?,'rTTC P.'fCt{FiF, I~D FIELD COOK INLET J'OB NO. NorthWestern D'irecfional Drilling, I LEASE T.3.U I<-11 wELL NO. 32-20 DISTRICT Aln~!~n .... P. O. BOX 4 ---I I I 3 , . ~uc~o~g~. ~s~ ~950~ TYPE OF sURVEy Single Sho~ COMPUTATIONS F~r~u~nn DATESep~n,I-,~ 9.~.,_t)..*~ ~2..~..L~ ~ . , ~ -~ ................ ' ....... , !9'33 . Declination ENGINEEE Fcrguson. OBJECTIVE .. SHEET 3 OF . . . ,,, , ,, . ,, , ,,, TRUE COORDINATE DIFFERi:ENCES RECTANGULAR COORDINATES STAt*N MEASURED ~OURSE DRIFT VERTICAL VERTICAL SECT'N COURSE DRIFT DIRECT* L NO~ DEPTH LENGTH ANGLE DEPTH VERTICAL SECTION DIFF. DEVIAT'N DIRECTION 'DIFF. ' "' DEPTH NORT~ SOUTH EAST WEST NORTH SOUTH EAST. WEST· .-0,. 5364 73 .1670.3C~ 23_D2.,.TD_ 83 n ~ w 7 a~ z~7 ' ~ 57~,6 65 21° "57,-°~ -~ 25 oo~. 5422 J6t ~692252 _~' ~ ~ , : _ 5965 213 20"45 20z~ 79 5627 40 .17fig.gO 77 3T; 77 Sq l~fl /,:gq! qq A4 A9 R7 1502 94 [ i1026 21 , .. 6120 155 20o45, 14~ 94 5772 34 1824.73 54 82 54 92 39 3.25 . a2 68 ~4 56 1545 62 1()60 77 I .. _ _. 6257 137 20°. 12~ 7~ 5901 08 1871.30 4fi 57 ~6 85 ~2 ~_25~ ~& R? ' ~1 ~ ~qn ~/~J ~noo 6461 2OZ, 9fi°3~' 19! 09 6092 !7 !942.j.2 7! 02 7! /:/: /:2 6.25 .... 53 09 47 80 1633 53 . 1139 92 . . 6583: 122[ 20°15'' 11/I 46 6206 63 1983.99 4! 67 42 22 45 9.25 29 85 29.85 ............. 1663 38 1169 77 .. ii , 6636 53 17030' 5C 55 6257 18 1999,80 15 81 15 94 43 7.25 11 66 10 R7 . ~7q nfl. ~]~qn 6730 94 ]6045` qO ~1 62/~7 !q 2r~pR_7~ 2~ q2 97 g'q ~1 R 9~ 20 13 18 13 ~aac ~v l~no I I 6875 145 18°15', 137 7! ...6484 90' 2071.6'7 44 94 45 41 44 8.25 32 67 31 .54 1727 Rfi !230 3! I 6925~ 5C 17° 47 82 6532 72 2086,2.9 14 62 14 62 36 .25 ' I ll 83 8 59 1639 67 12B8 ' 6957~ 32 16o30' 3C 6~. 656g ~0 2OqS.g7 q ~ ~ OO ~ ?~7~ 7 6~ ~ 5D 17/~7 29 12/~a fi988 3~ i7o .29 651 6593 05 210~.~0 9 03 9 06 31 ~.75 7 77 ~ 67 1755 06 · ~2~5 7019 31 17° 29 65 6622 70 2113.44 904 9 06 32 3.75 7 68 ~.Sfl 17'~? 7~ ]?~ } · . 7239 125 ~0° 117 46 6830 ~2 2186.71 42 7/}I42 75 37 1.25 34 14 25 73 1822 20 1296 '13 7270 31 !0°45'' 28 99 6859 11 2197.69 1098 10 98 37 1.25 . .8 77 6 61 lg~ q7 ~ ]gr~9 7~ 7363 9S !0°30~' 9i 79 ..6950 90 2232.00 3~ 31 34 32 37 1.25 ~7 ~1 ~20 65 185~ 3~ t323 . 7~4~ 78 !0°30': 75 06 7023 96 2259.30 27 30 27 32 38 2.25 . 21 53 16 82 1879 91 1340 21 7491 45 ZO°15'~ 22 ~066 ~8 2274.87 lSj 57 15 58 38. 2.25 12 28 959 1892 i9 1349 30 . ,, ' ~ COMPANY ATLANTIC RICHFIELD FIELD COOK INLET JOB NO. Northws~tern J)JrecfJ0.~J OrJJJJ.g, JB~ LEASE · T.B.U.K-11 WELL NO. 32-20 DISTRICT Alaska ' ANCHORAGE. ALASKA99~03 TYPE OF SURVEY. Single Shot COMPUTATIONS Ferguson DATESeptember 26~ 1968-L~ovembet.' ~ i~ .~ 90 ~ DecJin~fio, · ENGINEER F'ergu~on ' OBJECTIVE SHEET .. 4 'OF 5 COORDINATE DIFFERENCES RECTANGULAR COORDINATES STAT'N MEASURED COuRsE DRIFT VERTICAL TRUE VERTICAL sEcT,N COURSE DRIFT O~ECT,C.................... NO. DEPTH LENGTH ANGL~ DE~TH VERTICAL SECTION OlFF. DEVIAT'N DIRECTION [ .D5~TH NORTH SOUTH ~AST WEST NORTH SOUTH ~AST WEST 7623 20° 12~ '7~ 7194 92 2321.64 4( 7] 46 85 S 39 W 3.25 36 41 29 48 1929 60 1379 28 ..... 77..4~ .. 1t( 20° 10~ 0~ 7303 93 .... 2361.14 3~ 5( 39 :~.7 ..4!: 5.2..5 29 94 26 03 ....... 1959 54' ......... 1405 31 7872 126 20°15'' 12C 0[ 7424~02 2405.09 4~ 9~ 44 30 ZJ. 3J 7.2~ 32 40 .30 21 199G 94 '1435 52 739~ 22 20°45'' 2] 51 .. 7445 53 2413.17 [ 0f 8 15 43 7.25 59 61 5 56 2050 55 14Z~l 08 805f 168 23° i4) 2~ 7592 81 2475 31 6~ 1~ 62J 51 42 '6.2~ 46 45. 41 83 2097 00 1482 91 8117 62 24°30~[~ 5( 42 7649 23 2500.91 2f 6( 25~ 71 41 5.2~ 19 40 16 87 2116 4'0 1499 78 ....... 823E 12] 2Z~°45' 10~'~ 8~ 7759 11 2.551.36 5[~......~f 50' 66 41 5.2~ 38 23 33 24 ..... 2154 63 !533 02 .. 831,'~ 8C .25~.. 7~ 5(' 7831 61 2585.03' 3..~67 33 81 41 5.2f 25 52. J.22 18 2188 15 1555 2...0. ~A4(] 12~ 25° . ]]~ 57 7g42 1S 2636.37 5] 3Z 51 5~ 41 5.2= 38 91 ~33 83 2219 06 15.89 03 866q 15>. 25~15~ 14~ 0C 8149 43 2733.36 6C 6f 66 97 41 5.21 50 5I~ 43 94 2292 57 ...... 1652 93' 873~ 12( ~5~15~ '10~ 59 o~ . · 38 ~04 34 25 233C 61 1687 - o=57 97 2784.25 5C 8(~ 51 19 4~ 6 2~ Zg,~ ~05 2A°~5~] 17~ 28 ... S430 17 28({8.49 8~: 2Z 94 92 43 7.2~ 62 57 92 2392 72~ ..... 1745 10 9123 '14~ 27° 12( 52 8556 69 2932.22 62 7~ 64 57 fi5 9.2~ 45 66 45 66 2438 3~ 1790 76 q2l~ q( 27~0~ 7(~ gJ ~636 52 2973.24 4] 02 4! 56~ 45 9.2f 29 39 29 39 2467 77 1820~15 °~°Z 6~ 69 51 03 47 58 ~' oD 1867 70 936~ 15f ~o ~5' 13~ 4] 8774 93 3042.~5 2[ 77 43 7.2~ 2518 o ...... 939~'~ 3( 26°30~ o 8f 8801 73 0055 76 1] °~ 13 39 42 6 2f 9 95 o 96 °52~, 75 1876 9512 I!Z 26° 10~ 4~ 8904 24 3105.34 4~ 5E 49 98 4'3 7.21 36 55 34 09 256~ 30 '1910 .............. 963f t1~ 25° 10( 9z 9011 18 3154.69 4 3f 49 87 44 8.2] 35 87 34 64 260] 17,, 1945 42 ' ,~, COMPANY ATLANTIC RICHFIELD FIELD C'OOK INLET JOB NO. I, NOrfh~/estern l)irecfional DriiJing, Inc.~ LEASE T.3.U. K-ii WELL NO. 32-20 DISTRICT Alaska .' ,. -~'~ove~ her ~.~C.O~*G[. *~S~* ~0~ / TYPE OF SURVEY Single Shot cOMPUTATiONS Ferguson DATE. Segtember 26,1968, . Declination ENGINEER .. Ferguson. . ~ .OBJECTIVE SHEET 5 OK ~ , ~, , , , , . ,. , , . . , / TRuE') CooRDiNATE DIFFERENCES RECTANGULAR COORDINATES ' STAT'N MEASURED COURSE DRIFT', VERTICAL VertiCAL SECT'N COURSE DRIFt ~JRECT'L i I NO. DEPTH LENGTH ANGLE DEPTH VERTICAL SECTION Diff. DEVlAT'N DIRECTION Diff. I I I I I~ ....... I" I ,,, DEPTH ~ NORTH SOUTH EAST WEST NORTH 'SOUTH EAST WEST . i .... / . . ~832 2~2 ~3°30':' 185 25 9196 ~.3 323~. 1~ 7~ 49 ~0 54 S 45 W 9.25 ~6 ~5 .~ 56 ~5 ~o' 12 2002 ~'7 ............... 10064 232 !2°'15' 214 72 9411 hL5 3320.62 86 4[, 87 84 ~6 20.25 (~1 )2 53 19 2719 t4 2065 56 .......... , , , , . .... 10256 192 ~].°30° ].7~'} 64 958.9 79 33°0 84 63 9~ 70 37 50 '.4 25 ;5 13 53 91 276Z~ 37 2119 47 I ..... . i · 10311 55 !1° 51 35~ 9641 4 3408 10 19 26~ 19 71 . 4S 2 25 L3 o lZ, 65 2777 56 2134 12 10772 461 !0~. 433 2D: 10074 ~4 ,13561-56. L53 /~.61..57 66 49 3.25 l~D3 ~3 11.8 99 2880 99 i 2253.1i ~1 =J01 7 10g73 i ..201 .!0~ oo ~o 22 41 5 68 7~ 45 9 25 %8 6]. ~8 61 0929 60 .. ~ 1~',~.., ,~o - 10263 3629. 67 o . ' ' i . . ~ . . . .. i 42 o . i i 2960 27 2332 .39 1,u94~ 121 !O~ 112 97 10376 19 3672 22 ,,]. ~3 37 45 9 25 {0 67 B0 67 .~ .i ...... . , ...... . , i J . '.i ii , . i i , ...... .... i i t' ', i .i i,i i . , .., .. .. . .. . F-efta lq'o. REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN I)UPLICATE MONTHLY REPORT OF 'DRILLING AND WOR'KOVER OPE'RATIONS ~. A~U N~SmCXL 'CODE 50--133--20148 LEASE DESIGNATION AND SLmfilAL NO. ADL 17594 1. 7,IF INDIA~, ALOTTEE OR TRIBE NAME 0IL [] G~S ~ WELL WELL OTHER 2. NAi%~E OF OP~I~ATOR 8. I/NIT,F.~R~I OR LEASE NAME * Union Oil Company of California Trading Bay Unit 3. ADDR]gSS OF OPE~{ATOR 507 W. Northern Lights Blvd. Anchoraqe,.Ak. 99503 4. LOCAT/ON OF WEJ~L 617'N and 131'W from SE corner, T9N, R13W, SM Section 17, 9. WELL NO. K-il (32-20) 10. ~'l.~.;l.a~ A_ND POOL. OR WILDCAT McArthur River-Itemlock 11. SEC., T'., R., M.. (BO/'TOM HOLE OBJECT~v'E) Sec. 20, T9N, R13W, SM 1~. PERA/IIT N'O. 68-83 ]3. REPORT TOTAL DEPTH AT END oF MONTH, CI-La~'GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrMES USED, PER.FOP~ATIONS, TESTS AND RESULTS, FISHING JOB~, JU/~K IN HOLE A/~D SIDE-T];~CKED HOLE A/ND ANY OTHER SIGNIFICANT CH.A/NTG~S IN HOI-,I~ CONDITIONS. Trading Bay .Unit _K-11 :(932r.20).r.....0.c~ober 1968 Ran and cemented 60 its 619 J-55 13-3/8" casing ~ 2470' w/1050 sx Class G cement w/10% Gel and 500 sx Neat cement on~ bottom. CIP ~ 1:45 PM 10-1-68. Installed and tested BOPE, pipe rams and blind rams w/5000 Psi for 15 min. and Hydril w/1500 psi for 15 min., OK. Cleaned out cement 2422-2470'. Directionally drilled 12~" hole 2572-11,094'. * Atlantic Richfield Company sub-operator. NOTE--Report on this fo/m is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines &IMinerals by the 15th of the succeeding month, unless othe~ise directed. STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF 'DRIrLLING AND WORKOVER OPE:RATIONS WELL WELL OTHER 2. NAME OF OPERATOR *Union Oil Company of California 3. ADDRESS OF' OPERA. TOR 507 W. Northern Lights Blvd. 4. ~OCAT~ON OF WELL Anchorage~ Alaskga9503 617' N + 131'W from SE corner, Sec. 17, TgN, R13W, SM. AP1 NLr~EHiCAL CODE 50-1~2-20148 LEASE DESIGNA~ON AND SERIAL NO. ADL 17594 ?. IF INDIAI~, ALOTTEE OR TRIBE NAME 8, ~-NIT, FAi~ OR LEASE NAME Trading'Bay Unit 9. w~:~ NO -11 (32 20-) 10. ~-,Ri.r~ A-ND POOL. OR WILDCAT ~cArthur River-Hemlock 11. SEC., T., R., M.. (BOTTOM HOLE R~n. P0_ MC)N. R]~. 68-83 SM. 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE. CASING. AND CE1VIENTING JOBS INCLUDING DEPTH SET A2~> VOLLrMES USED, PEI~FO.HATIONS, TESTS A2~D HESULTS. FISHING JOB~, JUNK IN HOLE AND SIDE-T~ACKED HOLE A~N'D ANY OTHER SIGNIFICANT CHA~,GES IN HOLE CONDITIONS. Trading Bay Unit K-11 (32-20) - Septembers 1968 Spudded ~10:15 AM 9-27-68. Ran 17 1/2" Bit 372-400'. Directionally drilled 12 1/4" hole 400-2572'. Opened to 18" 400-2497'. * Atlantic Richfield Company sub-operator. RECEIVED DIVISION OF MII'qS$ a MINERAL~ ANCHORAGE S~GNXD ~_~ Dist. Drlg, Supt. DA~Z 10/15/68 NOTEmReport on this form J is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the ZSth of the succeeding month, unless otherwise directed. Union. Oil Compam-~f. California 2805 Denali Street; Anchorage, Alaska 99503 Telephone (907) 277-1481 union Robert T. Anderson Distric,', Land ~/a~a;er 'October 2, 1968 Director Division of Lands 344 Sixth Avenue Anchorage, Alaska 99501 WEST FORELAND AREA State of Alaska ADL 17594, WFore-2 Dear Sir: In accordance with the provisions of the captioned oil and gas lease, Trading Bay Unit K-Il (32-20), drilling from the King Platform located on State Lease ADL 17594 was spudded on September 27, 1968. The proposed bottom hole location of said well is approximately 2,200' South and 2,090' West from NE corner, Section 20, T9N, R13W, S.M. on said captioned lease. Very truly yours, -' RoBert T. Anderson / RECEIVED r.: c.-T' ~) ANCHO~GE DIRECTOR'S OFF~':. .... ~' Date Not~.d l..', :' ',-,i Lands ./ En~ Minerals ~/' P"r",; & R~c l,Vater ForesLTv Admin An? :'u-ca .info File : Co;nmcnt , '" f." Form401 ANC-A iNev,, r/671 :~ep~ember 2&, 1~68 Tradt~ Gay lh~C £-11 ~niou 0~. Coup~y of ~a11~ornLu, Operator ~Ir. Robert T. Anderson District .Laud. HanaSer U~on Oi! C~ompany of Cali~o~a 2~5 ~ Steer Au~ra~, ~~ 99~03 Enclosed plmme £~nd the approved app:L~cat~on for permit to d~ ~ ~~d ~.. ~ ~'~ ~ ~re ~t~ ~e V*~~' t~Zy ~uro~ ~ Thorns l~. liarshall, JE. ~etrolmm Supervisor FORM SA-lB t 25,5M 8/67 .MEMORANDUM TO: r'- ~JIJlJIllJ ~ ~ State of Alaska DATE : FROM: FORM SA- I B :125.5M 8/O7 / MEMORANDUM TO: FROM: State of Alaska DATE SUBJECT, Form REV'. 9=30-67 SUBMIT IN THIt- TE (Other instructions o reverse side) STATE OF ALASKA OIL AND, GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL I~ DEEPEN [] PLUG BACK b. TYPE OF WELL OIL ~ OAS ~-] SINGLE ~ MULTIPLE ~_~ WmLL WELL oTHER ZONE ZONE 99503 2. NAME OF OPERATOR * Union 0il Company of California 3. ADDHESS O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 4. LOCATIOA~ O~F WELL At surface 617'N ~ 131'W from SE corner, Sec. 17, TgN, R13W, SM At pro.posed prod. zone 1980'S ~ 1980'W from NE corner, Sec,':,',!20, T9F~!:R13W, SM 13. DISTANCE IN MILES AND DIRECTION F.%OM. NEAREST TOWN OR.POST OFFICE* 24 miles NW of Kenai Federal Insurance Co. #8011-34-40 Surety and/or No. 14. BOND INFORMATION: Statewide TYPE 15. DISTANCE FROM PRO.POSED* LO'CATION TO NEAREST PROPERTY OR LEASE LINE, FT. 3'300'W (Also to nearest drig, unit, if any) D~ISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETE-q), OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT. CR, etc.) 100' K.B. PROPOSED 'CASING AND CEMENTING"PROGI~AiVi.2 ' .'~,, API 50-133-20148 $. 6. LEA~E DESIGNATION A2VD SERIAL NO. ADL 175~4 8. UNIT~ FAPdVI OR LEASE N~'VIE Trading Bay' Unit K-Il {32-20) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC.-, T., R., M., (BOTTO1VI HOLE OBJECTIVE) Sec. 20, T9N, R13W, SM $100,000.00 17. ffO::AC~:S ASSIGN~ TO THiS WELL ..... ' " 160 20. 'ROTARY 'OR CABLE TOOLS Rot..ary 22. APPRO~X~:D.<AiTE .WORK WILL START' september 25, 1968:, _ SIZE OF HOLE SIZE OF cAsING ;"'WEIGHT' I~"F0~' O'~AI~E' :' S~i~G DEJP~' ''''~ '" :' '~ "' ~ (: .... "~ ' Q'UAN~I~;~)I~ C~MENT , 15" ~3-3/8" 61~ J 2,000 21'O0~'~acks'~ ' F,'~Is % 300' 12~" 9-5/8". ' . 47~ .,P~N , . 1.0,000 ..-,,. 700~sa~ks ~, 7- . . .29t N . 11,015 ...... 175 :sacks . . : - . , , ~ ~..~,-.,.~ ... ..... · .... , , , , ,, ~ , ., , , , BOPE: S00 psi Double and single Shaf£er gate and Hydril. Logging program at 10,000' and TD. Bottom Hole Location: 2200'S I 2090"W from NE corner, Sectfon 20,.TgN, R13W, SM .. *Atlantic Richfield Company sub-operator IN ABOVE SPACE DESCRIBE I~ROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zofle. If proposal is to drill or deepen direct lonally, give pertinent data on s~bsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify that the Foregoing is True and Correct S!GNED~ . . . DATE, September 19, 1968 (This space for State office use) C~ONDITIONS OF APPROVAL, IF ANY: ISA1ViPLES AND CORE CI-IIPS REQIJI~ [] YES ~NO rn~E District Land Manager [ D~CTIONAL SURVEY YES [] NO t~ I~UI~: A.P.I. 1~C~ CODE S"'o --/33 - Z_o Executive Secretary =.~ *See In~udions DATE --t R 13W K-6 J7 ARCO /.,...// KING SALMON ( ~ 10,4~OTVD ~ "0 9 ATLANT lC R ICHFI ELD A D L - 18772 UNION- MAR ADL 18730 N UNION WELL LOCATION MAP ARCO SUB-OPERATOR TRADING BAY STATE ( 3 2-20) SCALE '. I "= 200d 0 2000 K II SEPT, 4,1968