The URL can be used to link to this page

Home My WebLink About176-049 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Martin, J. Hal [Hal.Martin @chevron.com] Sent: Tuesday, May 17, 2011 2:06 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Lee, John R; Payment, Glen A Subject: Granite Point State 18742 #21 (a.k.a. Anna Well No. 21) AIO 6.009 Compliance Temp Survey Attachments: Anna 21 5- 16- 11.zip Jim & Tom, A compliance temp survey was conducted on Granite Point State 18742 #21 (a.k.a. Arena Well No. 21), AIO 6.009 (PTD 176 -049) on 5/16/11. The previous compliance temp survey was conducted on 5/16/09. The attached temp survey data and plots include a MD plot overlaying Anna Well No. 21 temp surveys on 5/16/11, 5/16/09 and 10/4/06 indicate downhole containment of the injection fluids with no significant temperature anomalies. TVD plots of the 5/16/11 survey show the same result. As you recall, our waterflood injection has been down on the Anna since January 2008 due to drilling activity during much of 2008 and sand filter issues since that time. Past correspondence between us indicated your acceptance of a compliance temp survey even though the well was not on injection for a period immediately prior to running a temp survey. Please call me if you have any questions. ' ®— , Thanx, �� r 5Z NO- Hal Martin Optimization Engineer ��` �s `� \ \bQ MidContinent /Alaska Business Unit l Chevron North America Exploration and Production � �rcC�'CSh \e�Ns..5 3800 Centerpoint Drive, Suite 100 } ` ��`� �C � toi Anchorage, AK 99503 s I ■ b -per Tel 907 263 7675 Fax 907 263 7847 4 c- oc�`�v�� hal.martin @chevron.com S I s 1, - c3 ( - \\ 3001 511 5 1 ,�� \\ MAY 18 20U - "r'oo c.c-Nc,,,NZ c31/4. cQ 49- c)-1)4 '` IC 4 5/18/2011 'Chevron I WeIAnna # 21 Long I Field:lAnna • 105 -16 -2011 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 �` Pressure - Temperature Profile 500 _ 1. Going in hole Overlay 2011- 2009 -2006 _ 2 Shut-In 1000 - ' \ - 1500 - ,` fi 2000 ► _ r -_ _ _- - , 2500 1 I 300 0 .. 3500 -4 \ 4 ::::: „ KIIIME Q 5000 nu , 5500 , anal 6000 IN 6500 y 7000 Ilinlat 7500 8000 IKE IL\ 8500 90N 1 1 I I 1 I I I I I 50 60 70 80 90 100 110 120 130 140 150 160 Temperature_(Dea. F) - 2011 Pressure - Perfs 13 3/8" - 9 5/8" 3 1/2 TBG - 2" Coil TBG - - - 2006 Pressure — —2009 Psia 2011 Temperature - - - 2006 Temp - - - 2009 Temp 5/18/2011 • • Page 1 of 1 Regg, James B (DOA) I"~ ~ 7~~~ From: Martin, J. Hal [Hat.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Atkins, Mark C Subject: Granite Point State 18742 #21 (a.k.a. Anna Well No. 21) AIO 6.009 Compliance Temp Survey Follow Up Flag: Follow up Flag Status: Orange Attachments: An-21 Temp Survey 5-16-09 vs 10-4-06.zip Tim & Tom, A compliance temp survey was conducted on Granite Point State 18742 #21 (a.k.a. Anna Well No. 21), AIO 6.009 (PTD 176-049) on 5/16/09. The previous compliance temp survey was conducted on 10/4/06. The attached temp plots (MD and TVD) overlaying Anna Well No. 21 temp surveys on 5/16/09 and 10/4/06 indicate downhole conta~n~+P^t of the infection fluids with no significant temperature anomalies. As you recall, our waterflood injection has been down on the Anna since January 2008 due to surface facility issues compounded with heavy drilling activity during much of 2008. Also, correspondence between us in February 2009 indicated your acceptance of a compliance temp survey even though the well was not on injection for a period immediately prior to running a temp survey. Please call me if you have any questions. Thanx, `a ~~ 4 ~; ~~ Jar~~ ~ 2 k~ Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com 9/16/2009 ~ ~ ~ -~~--~,~~~i Chevron Well: Anna # 21 Long Field: Anna 05-16-2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 500 1000 1500 2000 2500 3000 3500 .-. ~ 4000 ... ~ 4500 L Q 5000 D 5500 6000 6500 7000 7500 8000 8500 9000 Pressure-Temperature Profile 1 Going in hole 2 Shut-In 55 5-16-09 Pressure - Perfs 13 3/8" 9 5/8" 3 1/2 TBG 20" 2" Coil TBG 5-16-09 Temp 10-4-06 Temp 65 75 85 95 105 115 125 135 145 155 Temperature (Deg. F) • ,~ 17~ -- ~~y `1 Chevron Well: Anna # 21 Long Field: Anna 05-16-2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 500 1000 1500 2000 2500 3000 3500 .-~ ~ 4000 .~ ~ 4500 I!- fl. 5000 ~ 5500 6000 6500 7000 7500 8000 8500 9000 ~ ~ Pressure-Temperature Profile ~ - 1. RIH Hole TVD ~ 2. Shut-In - - ~ - ~ i - -- - - - ~ - ~ - - -- - ~ 55 65 75 85 95 105 115 125 135 145 155 Temperature (Deg. F) 5-16-09 Pressure - Perfs 13 3/8" 9 5/8" 3 1/2 TBG °°°°- 20" 2" Coil TBG 5-16-09 Temp 10-4-06 Temp • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, December 26, 2007 5:23 PM To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA) ~ - G' ~ ~~~ ~ f°'1 :~ ,, ~,~I~~~~~f= 1 ~` G~ a i~;v`i' Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Larry -Each of the listed admin approvals did not establish a formal 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 wells accomplishes what you are after (efficiency}. The wells you reference below are (with a due date for the next temp survey). Granite Pt State (Anna) 19 - AIO 6.008 (3/29/2005); next temp survey due 3129/2009 Granite Pt State (Anna) 21 - Af0 6.009 (3/29/2005); next temp survey due 3/29/2009 TBU G-11 - AIO 5.009 (12/15/05); next temp survey due 12115/2009 (you 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 6/30/2009 yo=,~ suggested 3i20~J9) TBU G-27 - AIO 5.003 (3129/2005); next temp survey due 3/29/2009 TBU G-29RD - AIO 5.007 (9/23/2005); next temp survey due 9/23/2009 TBU G-40 - AIO 5.002 (3/29/2005); next temp survey due 3/29/2009 TBU K-11 - AIO 5.011 (2/6/06); next temp survey due 2/6/2010 TBU K-24RD2 - AIO 5.010 (2/6/06); next temp survey due 2/6/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells). This does not affect any admin approvals that have anniversary dates specifically listed in the conditions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~° D~:.C ~ ~ ZQ07 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing for me to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3!29105 -last compliance temp survey 1013!06. Would like to slide 10108 temp survey to 3109 tc get on AA anniversary date cycle. An-21 - AA signed 3129105 -last compliance temp survey 10/4.%06. Would like to slide 10108 temp survey to 3!09 for the AA date reason. K-11 - AA signed 2/6;06 -last compliance temp survey 12;'11107 (ust see Et to you}. Would like to slide 12109 temp survey to 2110 for the AA date reason. 12/26/2007 - ~- ---a° - ~^- K-24RD2 - RA signed Zi6106 - last c ance temp survey 12i21f07 (will send to~ soon). Would like to slide 12109 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 would like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RC? 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 12/15105 -last compliance temp survey 6/25f07. Would like to slide to 6109 temp survey to 09;(}9 for efficiency. G-22 - AA signed 9/14/05 -last compliance temp survey 4126!07. Would like to slide 4x`09 temp survey to 9/09 for the AA date reason. G-23RD - AA signed 6/30x`05 -last compliance temp survey 4!19107. Would like to slide 4109 temp survey to 3109 for efficiency. G-27 - AA signed 3129;05 -last compliance temp survey 9121106. Would like to slide 9108 temp survey fio 3109 for the AA date reason. G-29RL7 - AA signed 9123105 -last compliance temp survey 6/24/07. Would like to slide 6,'09 temp survey to 9/09 for AA date reason. G-40 - AA signed 3129f05 -last compliance temp survey 9121x'06. Would like to slide 9108 temp survey to 3f09 for AA date reason. t hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. Larry 263-7661 12/26/2007 ---~ 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these wells did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L. Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. 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 4/19/2007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2/6/2006 12!21/2007 GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) Options Next Temp Surve Due, Based on AA Date1 AA Date2 Last Survey 3/29/2007 3/29/2009 10/3/2008 3/29/2007 3/29/2009 10/4/2008 12/15/2007 12/15/2009 6/25/2009 9/14/2007 9/14!2009 4/26/2009 6/30/2007 6!30/2009 4/19/2009 3/29/2007 3/29/2009 9/21 /2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2/6/2010 12/11/2009 2/6/2008 2/6/2010 12/21 /2009 last update: 12/26/2007 Next Survey Due (Chevron Proposed) Next Survey Due (AOGCC) Which Option? 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 6/30/2009 AA Date 3/30/2009 3/29/2009 AA Date 9/30/2009 9/23/2009 AA Date 3/30/2009 3/29/2009 AA Date 2/28/2010 2/6!2010 AA Date 2/28/2010 2!6/2010 AA Date • • An -21 Compliance Temp Survey required under Admin Approval A... • • Subject: An -21 Compliance Temp Survey required under Admin Approval A10 # 6.009.:':; From: "Greenstein, Larry p� <i reensteinzlp @chevron.com> Da te Tue, 24 Oct 200619 09 050 • y, ,: ' un r <tom. maunder @admen state ak Jim R °� lgt regg 7adm n state alc tis> C 4 � , - ,, Tom & Jim, Unocal is forwarding the compliance temperature survey to demonstrate production casing integrity under Administrative Approval # AIO 6.009 (approved 3/29/05) for the continuation of water injection in the Anna Platform Well No. An -21 (PTD # 1760490) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. MD and TVD temperature survey comparison plot (attached). The temperature survey run on 10/4/2006 shows no cooling anomaly changes above the packer from the last survey run on 6/12/2004. This indicates that injection is occurring only into the Tyonek C- Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run again in two years as required to confirm the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263 -7661 or Hal Martin at 263 -7675. Larry . ?0Vi «Anna 21 2 -16 -99 final dwg.pdf» «An -21 Temp Survey 6 -12 -04 vs 10- 04- 06.pdf» Content- Description: Anna 21 2 -16 -99 final dwg.pdf Anna 21 2 -16 -99 final dwg.pdf Content -Type: application/octet - stream Content- Encoding: base64 Content - Description: -21 Temp Survey 6 -12 -04 vs 10- 04- 06.pdf An -21 Temp Survey 6 -12 -04 vs 10- 04- 06.pdf Content -Type: application/octet - stream Content - Encoding: base64 1 of 1 10/25/2006 8:24 AM • • ( Chevron I Well 'Anna # 21 Long I Field:lAnna 110/4/2006 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1 - 500 - NI Pressure- Temperature Profile 1. RIH Hole TVD 1000 � \ 2. Shut -In • 1500 ) 1 - 2000 1 - 2500 1 1 i 3000 , a 3500 \\1/4 CD 4- 4000 > 4500 ' I- a t A Q 5000 a 0 CI 5500 i 6000 f 3 i 6500 jh e 7000 S I 7500 - i -:1 [ } { t- i 8500 9000 - 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) 10 -4 -06 Pressure — Perfs 13 3/8" —9 5/8" —3 1/2 TBG 20" - - - 2" Coil TBG 10 -4 -06 Temp •6 -12 -04 Temp S • Chevron Well 'Anna # 21 Long Field 'Anna 110/4/2006 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 -- Pressure - Temperature Profile 500 NIP 1. Going in hole 2. Shut -In 1000 1500 2000 2500 l - 3000 3500 G1 y am -• 4500 _ Q 5000 Ca 6500 k :. r _ 7500 8000 8500 9000 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) — 10 -4 -06 Pressure — Perfs 13 3/8" 9 5/8" 3 1/2 TBG 20" 2" Coil TBG 10 -4 -06 Temp — 6 -12 -04 Temp ~~ íì!ÆA ~ iŒ' i . f I \1 ¡ ~ ~ I U, "-it ~'~¡-. ) ~., i1 ~,\ ~~~- !Æ ¡tl¡! ,/L! III IÆh,: I ,8 \,t..i'~f y,lf¡, ii' ";', ~ U\~, \, ',,' ) / / I I FRANK H. MURKOWSKI, GOVERNOR A."~A.~1iA OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.009 Mr. Larry Greenstein Production Technician U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ,SCIA,N~jEr: !~I ~:J¡ n ¡QOh ¡,. d '-", "ì RE: Granite Point State 18742 #21 [aka Anna #21] (PTD 176-049) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 32RD from producer to injector via Sun- dry permit 300-214 approved September 28,2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with conversion sundry and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The original analysis performed for the conversion in September 2000 is still valid. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein March 29,2005 Page 2 of2 ) ) Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #21 [aka Anna #21] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and S. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE~Ska~ddatedØï~ K.~man Daniel T. Seamount, Jr. Commissioner ) Unocal Alaska . ') Union Oil Company of California ' 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519~6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCALe SCANNE,[,: P¡PR 2 0 2005 Larry P. Greenstein Prodction Technician Date: February 25,2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ¡th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-21 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for the Anna Platform Well No. An-21 Injector (Permit # 176-049) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled and completed as a producer in September of 1976. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled IIProcedures to Obtain Variances on Packerless Wells (Version 4) dated February 9,200011. This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 6/12/2004 matches the last survey run on 11/25/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only ') ) into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, tA~UH P. L:r;~~~'nstein cc: MIT book Well File ¿" UNOCAL8) Packer Fill tagged @ 9,560' 4/ 1/96 RKB to TBG Head = 33' L L I I- i i:! ~,¡ r- ~~ 11:.- .L..J.B ~. i C 3 4 5 / Anna 21 2-16-99 final dwg.doc ) ) Anna Well No. 21 Actual Coil Tubing Jet PUi... Completion as Run 2/16/99 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 Surface 610' 13-3/8" 54.5/68 J-55 12.615 Surface 2,979' 9-5/8" 40/47 N-80 & S-95 8.5" restr ID @ 8972'- Surface 10573 ' 9005' Tubing: LS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 9569' SS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 8785' SS 2-3/8" 4.6 1.995 8785' 8796' 2" .109" wall HS-80 Coil Tbg 1.782" Surface 8698' ~ ~ 1 2 ~ 3 4 5 6 7 8 Depth 35' 8799' 8799' 8824' 8979' 9569' I } , ¡' 'I ! II ~ I ¡',I ~' b' ~ 11 j' t,," , ! í t 2 ì I,,; 11 ! ,* , ì If ~, ~: ! ~ ~: \) f. it ''-1 \ ", .¡t @ -....¡ 8739' . :~ Tubing ~::t¡ Hal es .LJ 8757'- :,;.} 8759' Tubing '1 Jet Cut, --. R @ 8829 : \ - t ì t j ~. t~ Live Perf ... I' gun left at 9070' Tubing 9 9600' Holes 8757' - 8763' B 8785' C 8785' 0 8688' 8697' E 8698' F 8732" 8737' 8747' 8747' G JEWELRY DETAIL ID 00 Item Dual Tubing Hanger 2.992 3.5 3-1/2" BTC tbg 2.687 3.865 Kobe 3" Cavity, Type B SIN L-236 2.992 3.5 3-1/2" BTC tbg Blast Joints, 8979' -9067' Live perf gun fish left in hole 3-1/2" BTC tubing 3-1/2" Muleshoe Baker DB packer Short String 2.992 3.5 3-1/2" BTC tubing bottom 1. 995 2.375 2-3/8" pup with XO to 3-1/2" in top of cavity 1.300 2.75" Baker seal bore extension with 10' seal assy 1.440 2.20" Baker K-22 anchor 1.375 2.765 Baker "F A-I" packer with 1 0' seal bore extension on top Tops Adm!! 2" Coil Tubing (.W9" wall) ill1l Long StU'ilßg 1.625 1,300 1.440 ì.375 2.27" 2.75" 2.20" 2.765 1-1/2" jet pump cavity with standing valve Baker seal bore extension with I 0' seal assy Baker K-22 anchor Baker "f A-I" packer with I 0' seal bore extension on top E-line set packer at 8739' ELM PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments S/24/78 8,862' 8,86S' 3' 3 Squeezed 9/76,6/96 C-S 8,932' 8,995' 63' 8-12 9/76,6/96 C-4 9,005' 9,085' 80' 12-18 4/2/96 C-7 9,348' 9,374' 26' 14 4/2/96 C-7 9,430' 9,486' 56' 18 9/76,4/96 C-7 9,534' 9,560' 26' 6-14 8 9 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' " 02/17/05 I-\II-L I I t:llltJt:1 dLUI t: ~UI Vt:y::, ) 11/25/01 vs 6/12/04 ') -¡. 1000 o 1500 2000 2500 Pressure (psia) 3000 3500 4000 4500 5000 5500 Pressure-Temperature Profile 1. GOhlg in hole 2. ShuHn ".~ "'j '1 ., 1000 ! .\ j '. "1 2000 '. .! .J .\ 3000 !! .L ·l - ...... (þ .! 4000 ....... ..1" c :! I .c Q. 5000 -- CI) C T J "1-- I 6000 r _.", ,"......"w ,,_.,. ."...."..~.." 7000 8000 9000 - 50 I 60 I 70 80 ! 90 100 110 I 120 130 140 150 160 Temperature (Deg. F) -6-12-04 Pressure - Perfs -TBG -6-12-04 Temp -133/8" -9518" -11-25-01 Temp O:\OOE\OOEFields\GPF\Anna\Wells\An-21\Surveys\Temperature\An-21 Temp Survey 11-25-01 & 6-12-04.xls ) ') NOTE TO FILE In Re: Anna 21 (18742 #21)...PTD (176·049) Unooal has applied to convert this production well to an injector. Since the well does not have a packer in it MI demonstration must be by other means I The well was drilled in summer 1976. There is no information in the well file regarding the cementing operation. on the 9-5/8" production casing. According to the weir history. the 9..5/8" casing was run and landed on July 26 -27t 1976. The completion was run and the well perforated. Unfortunate~y aU the well would make was water and the initial . completion was puffed on August 20. A CST was attempted foftowed by a series of squeezes. it is noted that circulation eQuid be established via the perforations in the well. On September 1~ 1976 the wellbore was tested above a BP at 9575· to 1500 psi. Subsequent higher-pressure tests bled off to 1100 psi. Using an RTTS (or equivatent), the annulus from 8700' to surface was successfuUy tested to 2050 psi. On September 3 a eeL was run from 10277-7200. This eBl is not available in our files" The report notes "gcod bond across the squeezed perforations. The welt was then perforated in 5 Intervals and put on production pumping 448 bopd1 570 bwpd. The weir was worked over in May 1978 to shut off water production. FoUowíng a series of DSTs, squeeze perforations were shot about 65: above the upper production zone. 2 75 ex squeezes were performed May 23 -24. 1978. Little information is in the file on these operations, a1though the noted productjon rate before the squeezes was 174 bopd ·with 522 bwpd and the rate after was 362 bopd and 34 bwpd. Following the squeeze, a eBl was run, The eBL is not avaUable in AOaCC files. The well was worked over again in May 1985 to replace the pump BHA. No other work was done at that time. The latest work on the well was done in January 1999. At that time a coiled tubi ng jet pu mp was run in the (ong string and the well pface back on production. Unocal has provided Xerox copies of the both logs mentioned above. n the 1978 log, row amplitude response begi ns at about 8930· or at the top of the perforations. The response of the 1978 log is improved with low ampUtude response beginning at about 8800!. MJ is indicated. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Varia noes on Packerfess Wells (version 4) February 9 2000u, r recommend z;:::", to convert Anna 21 (176-049) as proposed, Tom Mau7:Z~ ~ (J Petroleum Engineer Ia.S 0 An-21 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 ,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0 . RU~ d~e : 2(23(200510:04:23 AM Safe operating pressures (surface gauge I Production = 4021 psi @ 70% nominal casing yieki InJermediafe = 784 psi. limited by fracture pressure at shoe Surface = 162 psLlimited by fradure pressure at shoe Current Pressure readings ,000 "., 0" "., internal yield = 7510 psi from 10400' to 10573' MO' '. ... ,". ..¡temal yield = 5745 psi from 9376' to 10573' MO' .. . ',', ...ternal yield = 6822 psi from 6035' to 10573' MCY .. I intemal yiekl:; 7510 psi from 7222' to 10573' MO' iI' _"oJ.; ··Ilemal yield = 8150 Dsi from 9296' to 10573' MO' ......1.··.1 = NJA psi from 10572' to 10573' MO' "-'~ P . 5 internal yieSd = 3450 psi from 2900' to 2979' MO' ~ .. .. ·55 internal yield = 2730 psi from 1546' to 2979" M.D' 5 internal yiekl = 3090 psi from 1949' to 2979' MD' ,·55 internal yield = 3450 psi from 2578' to 297g MO' CSGPRESS3 = 356 \....h,y D~'l. Pc-ducüon . .¡.....1 Pr...ouct.ion· .-, .....1 pr-du~n ·-'1 ,,-..I Pr-ducbon . "". --, Pr-cfuction _,;,,j···l Pr....cfuction I.... : 'I Inbnnediat.. .-.,.-;"1 Inbrmediat.. _,.,i,p. In~rmediat. _..,i.. InbrmediaL. _,,,i,..... Inbrmediat· . Slrlaœ Ca." ,.. Striace Sh,- ",'" psi from 609' 10 610' MCY Crsing Parameters" Assumptions Pr-ducüon casing yield @nQ% of nominal with fluid weight of o 433/11ft Inl:!rmediate casing yield G 45% of nominal with fluid weight of 0.433 11Ift SlJ4ace casing yield @ 45°ktaf nominal with fluid weight of 0.433 #1ft c-' .~ Analysis @70 percent 20050223.xts AfiI P~L 1760490 W, rkbook: An· 2,000 3,000 4,000 5,000 6,000 ê ~ oS Q. ~ C Variable Definitions RP :: Reservoir Pressure CYP = Casing Y"1OId Pressure SF = Safety Fador (70% for WO!kíng annulus; 45 HP :: Internal Fluid Hydrautic Pressure MASP :: Maximum allowable surface working pressu - -Graphicah:alcutation-method Inside pressure potential = Outside pressure contain Therefore HP + MASP = RP + (CYP' SF) Rearranging MASP = RP + (CYP . SF) - HP , 7,000 8,000 -Internal Fluid Hydraulic Pressure -~... Formation facture pressure @ 0.7 #1ft -Production CYP @ 70% -Outside Containment for Production casing -MASP (production casing) -Intermediate CYP@45% -Outside Containment for Intermediate casing -MASP (Intermediate casing) -Surtace CYP @ 45% - Outside Containment for Surtace casing -MASP (Surtace casing) . Current Pressure Readings 9,000 10,000 Graphical Casing Pfessure Analysis ver 22x,xls p~~I~~;a~~;' ~~2bOshed sources where specifM:alions are known. If søecffica:tions are unknown I:hen values are the lowest value of probab~ materials. TVD interpolated from Openwor1<s directional surveys. VakJes should be +/0 25 fl @ 10,000 ft. MD 11 ,000 JAM. 1.2003 ?:30AM ~0.073 P.3×8 Uonthly InJ~!~rVarlance J AN 2~.42 J Dee J 2002 J §uz;~2029t00 ANNA pLATFORM I t1~i266~ Date 'l-i~ on Volume InJe;c...l~d T~ Pres,,, 8.67..5 GeG Press I,S:~'~6 CS9 Press , ,Comments - 1211pttt~ ' 24. 643 3256 32~8 350 " 12/2/2002 24. ' ' 644. 3302 3300. ,. 346 12/3/~002 24 64.3 3326 3328 34.7 12/4/;2~02 2,4, 640 . .3.34.2 3342 3~t5 12/8/2002 24 642 3364 3364, 12/6/2002 .... 24 635 3360 3380 348 12/712'0'02 24' 635 3384 3364 348 12/8/2002 "24 632 3380 ' 3390 347 1,2t9/200~ ..24- 63'1 3397 .... 3397 34'7 "' '12/10/2002 24 630 34,06 3408 , 12/11/2002 24-- 627 3403 34-03 345 t 2/I 2/2002 .. 24 627. 34.13 3413 342, ,. 12/13/2002 24 626 34.17 3600 338 12/14/2002 24 6'17 3267 3500 333 i2116/2002 24, , 28.3 2.741 3'500 ,.322 ____ 12/IG/2002 24 453 3160 3600 336 12/17/2002 2~. 44t 2466 24.86 31 ~ ~/18/2002 2'~ 3a3 3202 3~02 ~0 ._ " 12119/2002 24 576 3202 3202 '~41 ,i 2rao/2oo~ ..... ,24 603 32.50 3.250 333 .. 12/2~ 12002 24 804 3280 3280 333 __ 12/22/2002 ,24 607 ~] 3295 a2es 334, 12/23pnn= 24 610 3311 ,. 3311 334 ,_ 12/241~-0o2 2.4 '609 3323 33,,2,,3 330 12/25/~007 24 61D 3338 3400 327 .... ,f 2/2,6/~dh:~ - 24 ..... 610 ,, 3345 3426,,. 326 .., 12127/2002 24 612 2590 34.25 ,323 12/29/2002 24 " 611 , _3348 34-50 334 12/29/2_g'_n_~ "24 ,,- 6tl ....... 3350 3450 338 ., '12/30/2002 "'24 613 3360 3360 33,5 12/'31/2002 24 .- 415 .... .3100 _ ·3100 333 CANNED tAR t O 200 MOV. ?.~008 ?:i?AM M0.768 P.7/8 Mofllfll~ tojee~e~ Ylltillnee AH 21.42 Sep - ,~0O~e $07~202910D ANNA PL,ATFORIMI tt17102 Da~ H~'I On, Volume_l~e~_l~d TB6 PI'~I* -~62~-GS6 Pm~ t~.376 C~O P~s Common~ 9/1/~002 24 a~ e 2AO0 27~ 4~ 0 g1~2~2 24 353 3142 3142 9~2~2' 24 788 3~'73 31~ .... ~' 6/4~2 24 ~ 1 ~6 3~6 411 91512002 24 ~5 3175 3175,., 399 ~0/2002 24 ~7~ -2~9 2739 "'~ 817T2~2 ~ -24 ~2 2714 2714 391 g/~2~2 24 ~4 2709 2709 910~2~ 24 ~42 " 2~25 2~QO 400 911012002 24 441 ~0 2700 9111J~OD~ ....... ~ ~ ~17 27Q0 368 .... 9/1212002 24 ~ 8 2728 2700 911312002 24 ~ ........... ~ 2~50 B(1KI2~2 2~- ~6 27~ 87~ 389 · 1~12002 24 ~0 2780 2950 811612~2 24 ,., ~3 ' '~09 2709 911712~2 24 867 3159 315g 9118/2bd2 24 707 3375 ~375 911glEO02 24 ~5 3d~ ..... 30~2 391 ._ 9120120D2 24 S~ 3083 3083 38a ......... gl2112002 2~ 847 31Qg 31~-' 8~2002 24 554 ~ ~ 9 31~8 e/2512002 24 ..... 5~ ~1 ~ 8300 390 ....... 9127/2002 24 ~O 32~ ~2~0 385 ..... 9~8~Q02 24 E?2 32~ 3?-30 3B5 81~002 ' - 24 ~B 3~5 318~ 385 ,_ gl3~2002 24 560' ..... 3195 3195 3a0 , SEP. 1.~00~ 6:4~AM M0.431 P.~x9 Report Name / Tbg String pllonthly injector Varianc~ AN 21-42 MonthjL .] Year AUQ ', 2002 APl No 6.07332E.1-11 ANNA PLATFORMI Velume TBG 9,6~ C,,SG Date Hfs On.~ Injected Press Pre~e 13,375 Csg Press Comment~ 61112002 0 0 890 1100 365 8/2/2002 0 ' 0 830 1050 ......... 370 .......... ~i3/2oo2 o 0 79o.. _ .1000 365 8/4/2002 0 0 75§ 1000 365 8/,~2002 24 "' 25o 2300 2o00' 4o0 816/2b-0'2- 24 446 '"2490 2490 395 8/712002 "2'4 446 2555' ' 2750 394 e/B/2002 24 ' 438 2595 '2-~50 395 819/2002 24 436 2628 262~' 395 .... '_'_._. 8/t,0 ./~-002 24 ' 436 2652 2652 294 811112002 . 24 ~7 ..... 2684 2684 ..... ., 397 8112/2002 24 438 2708 2700 ........394 8113/2002 24 200 1400 1600 361 811512002 24 363 2470 2404. 400 8/16/2002 ' 24 436-"-- 2584 ;z/50 394, 8/1712002 24 , 143 1219 ,,I ,., 1450 364 __ 8/18/2002 24 142 1600 1600 263 ......... 8/16/2002 24 "'4.~ 2~7 25~ 395 8/;20i2002 ,. 24 2600 2600 397 8/2112002 § 107 1163 1450 '"3'6g 8122/2002 " 18 0 0 '1200 372 ,.'..' 8123/2002 ...... 6 0 0 1100 375 i~.4/2002 ~7 114 1025 .... 1025 369 6/2512002 14 "' 0 0 1000 377 8/26/2002 24 '%' ' 750 1000 " 375 8/27i2002" . ...... 24 0 710 950 376 8/28/2002 24 0 8~6 g00 375 8/29/2002 24 ...... 0 650 '90~) ...... 375 8/3012002 24 ' "0 e,?.5 850 380 ~GANNED MAR 1 0 200~ Tbg Report Name Stri.l~ Month Year APl No Platform Date Created Monthly ln.J.~-~tor Varia~o ._AN 21-42 Jul " 2002 5.07332E+'11 ANNA PLATFORM 8/1102 Volume TBG 9.625 Date Hfs On Injected Press Press 13.376 Cs9 Press Comments 7/t/2002 24 668 3573 3700 385 7/2/2002 24 6.18 3500 3800 380 7/3/2002 24- 641 3505 3600 385 7/4/2002 24 640 3510 3800 385 7/$/2002 24 600 3125 3300 370 7/6/2002 24 473 '3150 3300 365 7r//2002 24 396 3095 3260 370 718/2002 24 506 3152 3152 370 7/912002 24 514 3172 3172 370 7110/2002 24 638 3505 3505 377 7111/2002 24 644 3458 3458 377 71I 2/2002 24 613 3452 3452 384 7113/2002 24 614 3468 3466 377 7114/2002 24 614 3473 3473 388 7'/15t2002 24 273 2385' 2600 360 7/1612002 24 225 2265 2500 385 7117./2002 24 233 2235 2400 365 7/18/2002 24 242 2205 2400 370 7/19t2002 24 247 21-85 2300' 375 7/20/2002 24 252 21180 2400 375 7/21/2002 24 254 2l 60 2400 375 7122/2002 24. 254 2'158 2158 377 7/23/2002 24. 255 2153 2200 378 7/24/2002 23.5 248 2106 2108 373 7/25/2002 24 252 2111 2111 373 7/26/2002 24 256 2114 21 '14 378 7/27t2002 24 257 2114 2114 369 7/28/2002 24 258 21-11 2111 372 7f29/2002 24 92 2110 2110 370 7/3012002 24 0 1014 1250 366 7131/2002 24 0 940 1200 3~'0 SCANNED MAR t 0 20[}3 RECEIVED MAY. i.2002 9:SOAM MO. 80~ P. 3/8 Report Name ' , .... _Tbg St~ing Time Period Date Created Waterflood Injector Well statue .~.N 2142 Last Month S/1102 ........... Outer Ceg Length Volume Tbg Prees Csg Press Pre~e Date (houm) (bpd) (psi) (p~i) (.~.D __ 4/3012002 24 639 3447 3445 452 4/2912002 24 697 3448 3445 456 4/28/2002 24 590 3486 3600 46~ 412712002 24 730 3425 3400 261 4/26/2002 24 188 2783 2750 266 4/2512002 24 50 2470 2450 409 4/24/2002 24 292 2472 2460 409 4123/2002 24 655 2592 2580 4,16 4/22/2002 24 527 3470 3460 434 412112002 24 617 3469 ._. 346.5 ..... 436 412012002 24 620 3473 3465 __, 436 411912002 24 623 3478 3470 439 411812002 24 628 3473 3470 447 4/17/2002 24 618 3461 3460 447 4/1G/2002 24 632 3470 3465 444 4115/2002 24 638 3458 3450 447 4,/14/2002 24 646 3460 3550 450 4/13/2002 - 24 646 3455 3550 450 4/1212002 24 661 3452 3550 ~50 4/1112002 24 670 .... ~i~'45 3550 455 ............. 4ii 012002 ............ 24 670 3425 3500 465 419/2002 ............ 24 ' 684 3419 3500 470 4/8/2002 24' 425 34~t0 34,00 4BO 4/7/2002 13 426 3410 3410 470 416/2002 0 0 25 25 455 .................. 4/-}].2. p_02 ...... 0 0 35 35 450 41412002 0 0 60 60 425 4/3/2002 10.5 306 633 633 360 4/2/2002 24 .... 6~0 3415 34,15 0 41112002 24 627 3400 34,00 410 P. nd of Repert SCANNED lVlAR 1 0 2003 RECEIVED O 1 2002. Alaska 0]! & Gas Cons, Gomm~ss~o~ Anchorage IRepo~Name I Monthty.lnje~torVarianc4 Tbg I_., Month String _ AN 21,,421 Mar 2002 ._, L 5;~07332Ee11 ANNA F' ¥ ORMI j ....... ' Volume TBG Date Hm On htjected Press.. Press 13.376 Ce~I Press. Co,m..ments ..... 3!'! ~.~00_2 24 832 ,,33.97 3500 400 ....... ~3/2/2002 24 409 3399 3500 402 ........ 3/312002 24 392 .... 3272 3400 406 3/412d~)2 24 620 ' 3297 3300 403' 3/512002" 24 622 331~,'"- 3310 398 3/612002 24 523 3322 3~}20 397 .... 3/7/2002 ~ 24 622 ......... 3330 , ,_3330 ' '~00 31812002 .... 24 621 3330 3330 400 3/10/2002 24 i 597 3202 3200 419 3111/2002 r 2~' 576 3202 3200 419 311212002 24 .... 0 1250 1550,. 398 3/13~2002 24 ....... 0 1067 1300 417 3/14/2002 24 44 2319 2500 466 __~ 311512002 24 .... 504 2514 2700 ...... .,,453I ..... 3116/2002 24 508 ' 3434 3500 464 ..~ 3/1712002 ..... 24 586 3270 3350 4,50 3/1812002 24 ...... 704 3325 '3325 4,50 3/19/20~)2' 24 ....... 65;Z 3~i70 3370 445 3/2012002 24 657 3405 34[~5 .... _440 312112002 24 '6§9'~ 3430 3430 4~0 '312~/'2'0'02 24 657 3450 3450 440 312312002 24 634 ' 3~,05 3~05 ¢,3~, ," 312512002 24 631 2850 2900 416 3/2612002 24 610 3364 3350 42.3 3/2812002 24 ..... '~,1 3438 3430 422 3/2912002 24 63g ' '3445 3450 42d 3/30/2002 24 642 345~ 3450 ........ 416 ....... 3/31/2002 ........ .24 641 '3463 35,00 416 Gnff et F~p~m,t SCANNED 0 2003 JUN. 2.2002 6:lgAM >Historical Data >Wells >StatUs (daily ilt~o) >Waterflood Injectors Select Tbg IA~ 21.4:~ ]~j' Select Time String: ....... Period: Report Name Tbg String Time Period Waterflood Injector Well Status AN 21-42 Last Month Date Length Volume Tbg Press Csg press (lloUrs) (bpd) (psi) (pel) 6/1/02 24 337 2't90 2~0 5/29/0 2 24 372 2575 2575 5/28102 24 367 '2560 2560 $/27/02 24 246 2;15 2;15 5/26/02 24 410 2886 3000 5/25/02 2'~ 222 2.~,8 2;0O 5/24/02 24 573 3309 $250 ~/23/02 24 4~2 3028 3000 5/22/02 24 q97 3025 3000 5/21./02 24 ~9~, 2986 5/20/02 24 428 2961 2950 5/19/02 17 3'30 3242 $245 5/18/02 2[ 505 3244 324; 5/17/02 22 b-~,~ 3213 3200 5/26/02 24 609 3416 3410 5/15/02 24 606 3411 34:10 5/1.4/02 24 608 3z1,13 3410 5/~3/02 2;, 60~ 3384 5/12/02 24 610 338':~ 3500 5/11~2 24 651 3365 3500 G/lO/02 2~, 654 3410 3500 5/g~2 24 207 3103 ~/02 24 &OS 3~ 3~0 5/7/02 24 60~ 33~ 5/6/02 24 607 ~ 3450 S~2 21 SIS ~ 3220 ~/4/02 24 &38 3~7 3~0 S~/02 18 510 ~72 Date Created 6/2102 Outer Cs, g Press (psi) 445 430 430 445 438 434 428 442 247 411 447 439 43'I 442 438 'q'qO 439 RECEIVED JUN 0 Oil&GasCons. Commission Anohorage En~l o¢ Report http://kodi ak. m~ ch ortown.unocal, comdda/mm plates/tabul ar. asp 6/2/2002 Unocal Corporation Alaska Business Unit 909 West 9'h Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL January 17, 2002 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: ANNA-21 Variance Request Dear Tom: Unocal is requesting a 2-year variance for ANNA-21 (Permit# 76-0049-0). The plan is to rerun the temperature survey every two years, report the daily dates/pressures monthly to the AOGCC and monitor the rates/pressures daily using Unocal's web-enabled surveillance system. The attached baseline and follow-up temperature surveys show no anomalies indicating injection is occurring above the perforated interval. Please review the attached data and approve the variance. If you have any questions, please call me at 263-7830 or email me at ruffc@unocal.com. Sincer.e, ly, Chris Senior Reservoir Engineer Cook Inlet Waterflood Management RECENED A~$~,a Oil & Gas Cons. C0mmissi0~ ORIGINAL O:XAOGCC\CorrespondencesXAN-21 2002-01-11 Variance cover letter.doc Jeff Dolan STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: X Middle Ground Shoals 4. Location of well at surface 8. Well number 834' FNL, 676' FEL, Sec. 12, T10N, R12W, SM Anna-21 At top of productive interval 9. Permit number 3121' FNL, 1283' FEL, Sec. 12, T10N, R12W, SM 76-0049-0 At effective depth 10. APl number 50- 733-20291-00 At total depth 11. Field/Pool 3447' FNL, 1870' FEL, Sec. 1, T10N, R12W, S.M. Middle Kenai "C" Sands 12. Present well condition summary Total depth: measu red 10,575' feet Plugs (measu red) true vertical 9,996' feet Effective depth: measured 9,735' feet Junk (measu red) true vertical 9,240' feet Casing Length Size ' Cemented Measured depth True vertical depth Structural Conductor 610' 20" 1285 sx 610' 610' Surface 2979' 13-3/8" Cmt to surface 2979' 2949' Intermediate Production 10573' 9-5/8" 1100 sx 10573' 9994' Liner Perforation depth: measured 8932'-8995', 9005'-9085', 9348'-9374', 9430'-9486', 9534'-9560' "'. ~ E (~¢~ b ~ ED true vertical 8499'-8558', 8568'-8642', 8886'-8909', 8961 '-9012', 9057'-9081' ~ ~'~ ~' '" -. Tubing (size, grade, and measured depth) 3-1/2" LS, 9.2#, L-80 @ 9569', 2" HS-80,. 109" wall coil tubing @ 8747' /~,iaska 0il & Gas Cons. C0mmissi0p Packers and SSSV (type and measured depth) Anoh0raqe Baker "x 3-1/2" FA-1 Perm Pkr @ 8747' in the LS 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well ve~J~ppr, o./_,~e,.¢~ Oil: Gas: Suspended: Name of approv6lc,,-4&~////~/' Date approved Service: 17. I hereby certify that the foregoing i' ' -' " ' 's true and correct to the best of my knowledge. Christopher Ruff Signed: Title: Senior Reservoir Engineer Date: 1/10/2002 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J App rov~)& Plug integrity BOP Test Location clearance Mechanical Integrity Test ~/( ~.~(~ Subsequent form required 10- t'~_~'~'~'..~',,~.~-~. Original Sioned By (' Camm¥ Oechsli Approved by order of the Commissioner Commissioner Date '7/~ ~_ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 0 20 40 Anna 21 Comparison Temp Survey 6o 10/25/08o0 vs 11/~2o5o/01 120 140 160 180 500' 1,000' 1,500' 20" Csg @ 610' 10/25/00 Baseline Temp Survey 1125101 Follow Up Temp Survey 8,500' CoilTbg Cavity~ ~ 8730 / 9.000' An21 Temp Survey 10-25-00 & 11-25-01.xls 11/21/00 SLT UNOCAL RKB to TBG Head = 33' Packer @ 8739' Tubing Holes 8757'- 8759' Tubing Jet Cut @ 8829' Tubing Holes 8757'- 8763' Anna Well No. 21 Actual Coil Tubing Jet Pump Completion as Run 2/16/99 SIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP 20" 13-3/8" 9-5~8" Tubing: LS 3-1/2" SS 3-1/2" SS 2-3/8" 94 54.5/68 40/47 9.2 9.2 4.6 · 109" wall. Surface J-55 12.615 Surface N-80 & S-95 8.5" restr ID @ 8972'- Surface 9005' L-80 BTC SC 2.992 Surface L-80 BTC SC 2.992 Surface 1.995 8785' HS-80 Coil 'I'bg 1.782" Surlhcc NO. 1 2 3 4 5 6 7 8 D~pth 35' 8799' 8799' 8824' 8979' 9569' 9 9600' 2.992 2.687 2.992 OD 3.5 3.865 3.5 B 8785' 2.992 3.5 C 8785' 1.995 2.375 D 8688' 1.300 2.75" 8697' 1.440 2.20" E 8698' 1.375 2.765 Tops F 8732' 1.625 2.27" 8737' 1.300 2.75" 8747' 1.440 2,20' G 8747' 1.375 2.765 JEWELRY DETAIL Item Dual Tubing Hanger 3-1/2" BTC tbg Kobe 3" Cavity, Type B SIN L-236 3-1/2" BTC tbg Blast Joints, 8979'-9067' Live perf gun fish left in hole 3-1/2" BTC tubing 3-1/2" Muleshoe Baker DB packer Short String 3- I/2" BTC tubing bottom 2-3/8" pup with XO to 3-1/2" in top of cavity Baker seal bore extension with 10' seal assy Baker K-22 anchor Baker "FA-1" packer with I0' seal bore cxtcnsion on top Actual 2" (:()il Tul)in,~ (. ! 09" wall) in l~(mg String I-I/2" jet pump ca'~ity with standing valve Baker still bore extension wilh 1()' scm ashy Baker K-22 allch~)r Baker "FA.. 1" packer with 10' scm bore cxtcnsi(m E-linc set packer al 873q' EI.M BTM. 610' 2,979' 10573' 9569' 8785' 8796' 8698' Live Perf gun left at 9070' Fill tagged @ 9,560' 4/1/96 PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/24/78 8,862' 8,865' 3' 3 Squeezed 9/76,6/96 C-5 8,932' 8,995' 63' 8-12 -- 9/76,6/96 C-4 9,005' 9,085' 80' 12-18 4/2/96 C-7 9,348' 9,374' 26' 14 -- 4/2/96 C-7 9,430' 9,486' 56' 18 9/76,4/96 C-7 9,534' 9,560' 26' 6-14 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' 01/08/02 'UNOCAL APl #50-733-20291-00 Granite Point Field Well # An-21 Slickline Proposal Revised 10/19/00 Rev #1 Assembled by Steve Tyler Objectives: Wireline Problems: Tubing Size: Elevations 1 Qualify wellbore integrity, with temp surveys, to convert to an active injector. 2 Gauge tbg, Tag Fill. Run Temperature Survey. Place well on Injection for 1 month. Re-run Temp Survey 35' of unfired 2-18" Strip gun, lost 4/3/96 @ 9,068'. Tbg tail jet cut @ 8829'. LS 2" Coil, .109" wall, HS-80, ran concentrically inside 3-1/2" tbg to 8698' 3-1/2", 9.2#, N-80, BTC SSC Surf. to 9569' SS 3-1/2", 9.2#, N-80, BTC SSC Surf. to 8785' 2-3/8", 4.6#, N-80, Butt 8785' to 8698' Oil Master Coil Tbg Cavity 8732' Kobe Cavity 8799" Mule Shoe 5444' Minimum I.D. 10' Seal Assy below Oil Master Coil Tbg Cavity 1.30" 5389' Max Deviation: Max 25° @ 9,800' Perforations: Zone Top Btm Amt SPF Condition 8,862' 8,865' 3' 3 Squeezed C-5 8,932' 8,995' 63' 8-12 C-4 9,005' 9,085' 80' 12-18 C-7 9,348' 9,374' 26' 14 C-7 9,430' 9,486' 56' 18 C-7 9,534' 9,560' 26' 6-14 Brief History or Discussion · Diagnostic indicated that the pump cavity had developed a leak in the shod string side. · A 2" coiled tubing jet pump completion was attempted in the short string. Tbg conditions, found in the shod string, required the Coil Tubing Jet Pump completion to be ran in the Long String. · A Baker "FA-I" pkr with 10' Seal Bore extension and seals were left in the shod string during the coil tubing completion attempt. · IP average for the first month was 103 BPD gross, 32 BOPD net at 69% wc. · Iron Sulfite scale precipitating in the coil/tubing annulus, affected the performance of the coil completion and the well subsequently could not be pumped off. An-21 Temp Survey Procedure10-19-00 rev 1 .doc 10/19/00 Slickline Procedure An-21 Well Preparation [Prior to Slickline Work] 1. Circulate pump from well. I1. Slickline Work [Gage tbg, Run Temp Survey] Hold safety meeting with production, and slickline personnel. NOTE: This is an H2S Facility. 1. Ensure that lubricator can be bled off to facility system. 2. Establish tag out procedure for wellhead valves while wireline is in the well. 3. Spot SCBA's for rig up/rig down operation, 4. Production will issue a "Safe Work" permit for Slickline work. Establish that well room is free of gas and H2S, . Note: a 6. 7. Establish whom slickline personnel is to contact for pressure test and to operate wellhead valves. pump-in sub with a valve is required below the wireline BOP's. Open well room exterior door prior to breaking lubricator. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. MU equalizing prong onto tool string. 8. RI and actuate equalizing sleeve in standing valve. POOH. 9. BO equalizing prong. MU pulling tool. RI and retrieve standing valve. 10. MU 1.25" gauge ring onto slickline tools string. 11. RI and tag fill ( Last Max depth reached was w/2.60" GR on 2/8/99 @ 8,950' before CT completion) [1.30" ID obstruction @ 8,737']. NOTE: DO NOT GO BELOW 8800'. POOH. BO GR. 12. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. 13. Record time gages are started and the time slickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) 14. MU Temperature probe onto wireline tool string. Wait till bombs are "awake". 15. RIH at 60' per min making 2 minute stops every even 1,000' to 8800' [1.30" ID obstruction @ 8,737']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) 16. Wait 5 minutes at 8800'. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) 17. Once out of hole down load data. Insure data is good prior to releasing Slickline. 18. RD Slickline. Put well on injection. An-21 Temp Survey Procedure10-19-00 rev 1 .doc PAGE #2 8/4/99 II1. Slickline Work After One (1) Month of Injection [Gage tbg, Run Temp Survey] 1. Take well off injection 12 hrs prior to rigging up slickline 2. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. 3. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. 4. Record time gages are started and the time slickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) 5. MU Temperature probe onto slickline tools string. Wait till bombs are "awake". 6. RIH at 60' per min making 2 minute stops every even 1,000' to 8800' [1.30" ID obstruction @ 8,737']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) 7. Wait 5 minutes at 8800'. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) 8. Once out of hole down load data. Insure data is good prior to releasing Slickline. 9. RD Slickline. Put well on injection. An-21 Temp Survey Procedure10-19-00 rev 1 .doc PAGE #3 8/4/99 RKB to TBG Head = 33' Packer @ 8739' Tubing Holes 8757'- 8759' Tubin9 Jet Cut @ 8829' Live Perf gun left at 9070' Fill tagged @ 9,560' 4/1/96 6 7 Tubing Holes 8757'- 8763' SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" 13-3/8" 9-5/8" Tubing: LS 3-1/2" SS 3-1/2" SS 2-3/8" 94 54.5/68 4O/47 9.2 9.2 4.6 J-55 N-80 & S- 95 L-80 L-80 8.5" restr ID @ 12.615 8972'- 9005' Sudace Sudace Sudace 610' 2,979' 10573' BTC SC 2.992 Surface 9569' BTC SC 2.992 Surface 8785' 1.995 8785' 8796' Surface 2" .109" wall HS-80 Coil Tbg 1.782" 8698' NO. Dept h ID O__~D JEWELRY DETAIL Item 35' 8799' 2.99 2 8799' 2.68 7 8824' 2.99 2 8979' 9569' 3.5 3.86 5 3.5 Dual Tubing Hanger 3-1/2" BTC tbg Kobe 3" Cavity, Type B S/N L-236 3-1/2" BTC tbg Blast Joints, 8979'-9067' Live perf gun fish left in hole 3-1/2" BTC tubing 3-1/2" Muleshoe 9 9600' B 8785' 2.99 3.5 2 C 8785' 1.99 2.37 5 5 D 8688' 1.30 2.75" 8697' 0 2.20" 1.44 0 E 8698' 1.37 2.76 5 5 Tops Baker DB packer Short String 3-1/2" BTC tubing bottom 2-3/8" pup with XO to 3-1/2" in top of cavity Baker seal bore extension with 10' seal assy Baker K-22 anchor Baker "FA-I" packer with 10' seal bore extension on top Actual 2" Coil Tubing (.109" wall) in Long String PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/24/78 8,862' 8,865' 3' 3 Squeezed 9/76,6/96 C-5 8,932' 8,995' 63' 8-12 _ 9/76,6/96 C-4 9,005' 9,085' 80' 12-18 4/2/96 C-7 9,348' 9,374' 26' 14 4/2/96 C-7 9,430' 9,486' 56' 18 9/76,4/96 C-7 9,534' 9,560' 26' 6-14 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' An-21 Temp Survey Procedure10-19-00 rev 1 .doc PAGE #4 8/4/99 Ui )CAL ALASKA RESOUR. -'S WELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: UNOCAL Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: 10/26/2000 Pollard Wireline Inc. SN Survey Complete Mike Dimmick Anna Unit Tubing Hanger 1.30" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: An~21 Anna AFE # 143917 Biggs/deMello D. Pollard/McRee 1.5 33' 1.250" Time Operation Details 00:01 continued form 10-25-00, POOH w/BHP and Quick Temp Tools 02:30 - 04:00 Rig down off AN-21, download tools -- good Data BHP Probe Serial # 2108 Tool Cost: Single Electronic BHP Guage $650.00 Single Quick Temp Tool $750.00 Work String Detail: RS, KJ, 8' Stem, KJ, 8' Stem, SJ Description of any NONE tools or debris left in the hole: Brief Summary of BHP, Temp Survey Total Work Comleted: Total Hours Worked 4 Total Tool Cost $1,400.00 Total Hour Cost $ 320.00 Well Downtime Hr. Ticket # :1 P-528 I Daily Cost:I $ 1,720.00 H2S PPM Day # :1 2 Cumulative Cost:I $ 6,290.00 Wire Test Approved by: Dan Moultrie Code: AFE # 143917 Location: Anna Well #: AN-21 Date: 10-25-00 POLLARD WIRELINE INC. Survey Data Sheet Gauges On: 20:13:30 Gauges Off: 02:30:32 Started in hole 20:43:30 DEPTH RKB ARRIVE LEAVE DURATION 1000' 20:59:12 21:01:12 2 minutes 2000' 21:16:20 21:18:20 2 minutes 3000' 21:34:28 21:36:28 2 minutes 4000' 21:52:12 21:54:12 2 minutes 5000' 22:08:24 22:10:24 2 minutes 6000' 22:25:46 22:27:46 2 minutes 7000' 22:45:18 22:47:18 2 minutes 8000' 23:03:11 23:05:11 2 minutes 8800' 23:16:00 23:21:00 5 minutes 8000' 23:34:48 23:36:48 2 minutes 7000' 23:55:25 23:57:25 2 minutes 6000' 24:10:45 24:12:45 2 minutes 5000' 24:26:09 24:28:09 2 minutes 4000' 24:40:00 24:42:00 2 minutes 3000' 24:55:55 24:57:55 2 minutes 2000' 01:13:35 01:15:35 2 minutes 1000' 01:30:18 01:32:18 2 minutes Lub 01:47:44 01:49:31 2 minutes Date: Wireline Company: Work Being Done: Present Operations: UNOCAL Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: 3AL ALASKA RESOURC $ WELL SERVICE REPORT 11/25/2001 Pollard Wireline Inc. Temp & Pressure Survey Done G. Brown Anna Unit Tubing Hanger 1.30" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: An-21 Anna AFE # 143917 D. Pollard/Tomlinson/Kroto 7 8752' 36' 1.25" Time Operation Details 00:30 R/U on AN-21 02:00 RIH w/1.25" GR to 8718', work tools, little sticky, POOH 04:19 RIH w/Tandem Gauge & Quick Temp Tool, making stops to 8700', POOH, making stops 09:45 CCH, check data, data - good 10:45 Start Rig over to AN-26 Tool Cost: 12 hr min 3 man crew $2,080.00 1.25" GR $50.00 Single Electric Gauge $650.00 Single Quick Temp Tool $800.00 Work String Detail: (1" TS) RS, K J, 15' Stem, Spangs Description of any NONE tools or debris left in the hole: Brief Summary of GR run & Pressure and Temp Survey Total Work Comleted: Total Hours Worked Well Downtime Hr. Approved by: 12 Ticket # '1 Daily Cost: $ Glynn Brown Total Tool Cost $1,500.00 P-568 3,580.00 H2S PPM Total Hour Cost $ 2,080.00 Day # '1 1 Cumulative Cost:I $ 3,580.00 Wire Test Code: AFE # 143917 Location Well # Date Pollard Wireline Inc. Survey Data Sheet Anna Gauges On 04:08:00 AN-21 Gauges Off 09:49:40 11/25/2001 Bomb Serial # Depth KB Arrive Leave Duration Lub 04:19:00 04:29:00 10 min 1000' 04:45:56 04:47:56 2 min 2000' 05:03:34 05:05:34 2 min 3000' 05:21:43 05:23:43 2 min 4000' 05:39:33 05:41:33 2 min 5000' 05:57:50 05:59:50 2 min 6000' 06:15:50 06:17:50 2 min 7000' 06:32:52 06:34:52 2 min 8000' 06:48:55 06:50:55 2 min 8700' 07:01:33 07:06:33 5 min 8000' 07:17:58 07:19:58 2 min 7000' 07:35:43 07:37:43 2 min 6000' 07:53:50 07:55:50 2 min 5000' 08:10:24 08:12:24 2 min 4000' 08:25:54 08:27:54 2 min 3000' 08:42:00 08:44:00 2 min 2000' 08:58:02 09:00:02 2 min 1000' 09:15:23 09:17:23 2 min Lub 09:35:06 09:45:06 10 min Encoder on 04:05:45 Encoder off 10:02:00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: x'~(.~~ '~T~J'~r~.,,¢~'~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Pt. St. 18742 P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface 8. Well number 834' FNL, 676' FEL, Sec. 12, T10N, R12W, SM An-21 At top of productive interval 9. Permit number/approval number 3121' FNL, 1283' FEL, Sec. 12, T10N, R12W, SM 76-0049-0 At effective depth 10. APl number 50-733-20291-00 At total depth 11. Field/Pool 3447' FNL, 1870' FEL, Sec. 1, T10N, R12W, S.M. Middle Kenai "C" sand 12. Present well condition summary Total depth: measured 10,575' feet Plugs (measured) true vertical 9,996' feet Effective depth: measured 9735' feet Junk (measured) true vertical 9240' feet Casing Length Size Cemented Measured depth True vertical depth Structural ' Conductor 610' 20" 2885 sx 610' 610' Surface 2979' 13-3/8" Cmt to surface 2979' 2949' Intermediate Production 10573' 9-5/8" 1100 sx 10573' 9994' Liner Perforation depth: measured 8932'-8995', 9005'-9085', 9348'-9374', 9430'-9486', 9534'-9560' true vertical 8499'-8558', 8568'-8642', 8886'-8909', 8961 '-9012', 9057'-9081' Tubing (size, grade, and measured depth) 3-1/2" LS, 9.2#, L-80 @ 9569', 2" HS-80, .109" wall coil tubing @ 8747' Packers and SSSV (type and measured depth) Baker" x 3-1/2" FA-1 Perm Pkr @ 8747' in the LS 13. Stimulation or cement squeeze summary / RECEIVED Intervals treated (measu red) AUG 1 0 2001 Treatment description including volumes used and final pressure Alaska 0il & 6as 0ohs. 60mmissi0n 14. Representative Daily Average Production or Injection Data Anchorage OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 24 56 100 110 Subsequent to ope ration (~1~ ~T~--~'l~.,)(~ 1932 775 1200 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: (~/~' ' Title: Form 10-404 Rev 06 f88 ORIGINAl SUBMIT IN DUPLICATE • Maunder, Thomas E (DOA From: Ruff, Christopher A [ruffc@unocal.com] ~ ^~.,~ , Sent: Wednesday, August 08, 2001 3:59 PM ~ To: 'Tom Maunder' ~.C.~ Cc: Dolan, Jeff J; Moultrie, Dan R; Dorman, Allen; Delago, Paul A; Myers, Chris S; Cole, David A Subject: RE: Step Rate Tests Results for Anna 21, 25, 37 and 38 Attachments: AN 21 Step Rate Test.xls; AN 25 Step Rate Test.xls; AN 37 Step Rate Test.xls; AN 38 Step Rate Test.xls AN 21 Step Rate AN 25 Step Rate AN 37 Step Rate AN 38 Step Rate Test.xls Test.xls Test.xfs Test.xls '-"~'-~- Yes, we are going to limit our rates as stated below, but plan to run further tests in the future that will allow us to increase the rates to the mechanical limit. Here are better summaries of the data and the limits. Delete the files sent previously. I have hardcopies of the files in the mail. Chris ~~~ APR ~ 4 2D08 -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 08, 2001 12:58 PM To: Ruff, Christopher A Subject: Re: Step Rate Tests Results for Anna 21, 25, 37 and 38 Chris, Thanks for the information. I need to look at the well drawings and refresh my memory. Only real question I have right now is with regards to An 38. Since it appears that the frac pressure was reached, will you be lowering the injection pressure to stay below it?? Tom "Ruff, Christopher A" wrote: > Tom, > Here is the data from the step rate tests on the above wells. We > didn't run > a SRT on Anna 32RD and 36 because we haven't finished the conversion yet. > The SRT's went very well. Unfortunately, due to a miss communication, > the SRT's weren't run up to the mechanical limits. The tests were > designed to run up to the mechanical limits (70% of the casing burst > strength or the maximum injection pressure for the pumps, 5000 psi). > Anna 37 and Anna 38's > tests are complete tests and this is the final submission, but Anna 21 > and Anna 25's tests were stopped early due to ambiguous instructions. > The Anna 36 conversion is on hold for at least 6 months, we want to > wait for > a response before converting this well. The Anna 32RD conversion is on > hold until we have time to analyze the. casing pressure further. It > looks like there has always been some pressure on the outer casing i • > that can't be permanently bled off. We are working on a diagnostic plan. > Based on these tests and the casing burst strengths, the plan is to > limit the injection pressures as follows. > CONCLUSIONS Maximum Injection Pressure and reason for limit > An 21 3660 (Test stopped before reaching Frac Pressure or casing limit of > 4774 psi) > An 25 3400 {Test stopped before reaching Frac Pressure or casing limit of > 4025 psi) > An 37 4730 (Test stopped before reaching Frac Pressure or easing limit of > 6566 psi) > An 38 3820 (Apparent Frac Pressure observed at 3820 psi) > After we complete the temp survey's on these wells and make some > surface facility repairs we will rerun the SRT's for AN 21 and AN 25 > if we decide we > want to increase the injection pressure above the pressure which the current > tests have been run. > Chris > «AN 21 Step Rate Test.xls» «AN 25 Step Rate Test.xls» «AN 37 > Step Rate Test.xls» «AN 38 Step Rate Test.xls» > Name: AN 21 Step Rate Test.xls > AN 21 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 25 Step Rate Test.xls > AN 25 Step Rate Test.xls Type: Microsoft Excel Worksheet {application/vnd.ms-excel) > Encoding: base64 > Name: AN 37 Step Rate Test.xls > AN 37 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 38 Step Rate Test.xls > AN 38 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 2 ANNA-21 Step Rate Test Frac Pressure and Infectivity Analysis 5000 4500 4000 • 3500 H 3000 a 2500 a c ~ 2000 1500 i 1000 500 0 Rate (bwipd) 4/3/2008 \Wk-Anchorage\Groups\OOE\OOEFields\GPF\Anna\Waterflood\AN 21 Step Rate Test.xls 2:43 PM 0 200 400 600 800 1000 1200 1400 4000 3500 3000 • ~ a v 2500 d V ~ 2000 a a~ c 1500 1000 500 • 0 Q N O r O N Q Q a a a a a a a a . M ~ O ~ N M '~ O ~ N O O N ~ N ('7 ~ CO I~ OO r ~ ~ ~- r r ~ r r r O ~ ~ O O O O O O O 0~0 ~ ~ ~ 00 00 OO 00 00 OO N ~ 00 N CO N N ~ N ~ N I N f N 1 N I N f ~ ~ 1200 1000 800 a .; d 600 c 0 as 400 ~ 200 0 a (O M O r O N 4/3/2008 \\Ak-Anchorage\Groups\OOE\OOEFields\GPF\Anna\Waterflood\AN 21 Step Rate Test.xls 2:44 PM AN-21 Step Rate Test Frac Pressure and Infectivity Analysis Anna Injection well test sheet • • Sto test when maximum allowable in'ection ressure is reached Well # Date /Time Rate Tbg psi Csg psi Choke Comments VV@II = ~NN~1=~~ (bwpd) 13 3/8 e c o e ac 7/24/01 6:00 PM 620 3095 360 a es a er ow s a i ize or several days (Hook up chart to tbg pressure at this point) 7/28/01 10:00 AM 106 900 289 og a ua ra a an pressures before opening up well 7/28/01 11:00 AM 109 850 286 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 11:05 AM 213 903 289 og a ua ra a an pressures before opening up well 7/28/01 12:05 PM 210 1094 305 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 12:10 PM 303 1142 306 og a ua ra a an pressures before opening up well 7/28/01 1:05 PM 293 1367 319 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 1:10 PM 412 1455 325 og ac ua ra a an pressures before opening up well 7/28/01 2:10 PM 386 1705 339 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 2:20 PM 497 1775 344 og ac ua ra a an pressures before opening up well 7/28/01 3:10 PM 483 2044 356 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 3:20 PM 620 2141 363 og a ua ra a an pressures before opening up well 7/28101 4:10 PM 606 2445 378 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 4:20 PM 717 2508 383 og a ua ra a an pressures before opening up well 7/28/01 5:20 PM 720 2834 398 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 5:25 PM 830 2933 402 og ac ua ra a an pressures before opening up well 7/28/01 6:25 PM 795 3117 413 \\Ak-Anchorage\Groups\OOE\OOEFields\GPF\Anna\Waterflood\AN 21 Step Rate Test.xls 4/3/2008 2:46 PM Anna Injection well test sheet • • og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 6:30 PM 895 3192 414 og a ua ra a an pressures before opening up well 7/28/01 7:25 PM 890 3408 420 og a ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/28/01 7:30 PM 1002 3408 420 og a ua ra a an pressures before opening up well 7/28/01 8:30 PM 993 3660 430 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) CONTINUE SPREADSH EET IF NEEDED \Wk-Anchorage\Groups\OOE\OOEFields\GPF\Anna\WaterfloodWN 21 Step Rate Test.xls 4/3/2008 2:46 PM 5?UD DATZ; iZC RELEASE' · P~--~CHANICAL iNTEGRITY ~EPORT k.~_LL NUHBER :~.?.LL DATA %zD: %t2)5~"..~/).. ~cuq~TVD; PBTD: shoe: tOSh% m Shoe: and t~b ~ Y~_-C?BEqiCJ_L iNTEGIIZT~' - P.a_RT Annulus Press Tesu: v_p ; 15 rain ; 30 rain CBL Evaluauion, -_one Production Log :, Type Cemenu Volumes:' ~anc. Liner %bk ; Csg \\O~sg ; DV ~,~j ~'~ . Cmu vol :0 cover oerfs Cement Bond Log (Yes or No) ;,:-..~n, AOGCC File ', % ' , ...... % ' ; Evaluation CONCLUSIONS: Part ~1: · NOTE TO FILE In Re: Anna 21 (18742 #21)...PTD (176-049) Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled in summer 1976. There is no information in the well file regarding the cementing operation on the 9-5/8" production casing. According to the well history, the 9-5/8" casing was run and landed on July 26 -27, 1976. The completion was run and the well perforated. Unfortunately all the well would make was water and the initial completion was pulled on August 20. A DST was attempted followed by a series of squeezes. It is noted that circulation could be established via the perforations in the well. On September 1, 1976 the wellbore was tested above a BP at 9575' to 1500 psi. Subsequent higher-pressure tests bled off to 1700 psi. Using an RTTS (or equivalent), the annulus from 8700' to surface was successfully tested to 2050 psi. On September 3 a CBL was run from 10277-7200. This CBL is not available in our files. The report notes "good bond across the squeezed perforations. The well was then perforated in 5 intervals and put on production pumping 448 bopd, 570 bwpd. The well was worked over in May 1978 to shut off water production. Following a series of DSTs, squeeze perforations were shot about 65' above the upper production zone. 2 75 sx squeezes were performed May 23 -24, 1978. Little information is in the file on these operations, although the noted production rate before the squeezes was 174 bopd with 522 bwpd and the rate after was 362 bopd and 34 bwpd. Following the squeeze, a CBL was run. The CBL is not available in AOGCC files. The well was worked over again in May 1985 to replace the pump BHA. No other work was done at that time. The latest work on the well was done in January 1999. At that time a coiled tubing jet pump was run in the long string and the well place back on production. Unocal has provided Xerox copies of the both logs mentioned above. In the 1976 log, Iow amplitude response begins at about 8930' or at the top of the perforations. The response of the 1978 log is improved with Iow amplitude response beginning at about 8800'. MI is indicated. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend ap. roval to convert Anna 21 (176-049) as proposed. Tom Maunder Petroleum Engineer /'~-~- Procedures to Obtain Variances on Packerless Wells (version 4) February 9, 2000 It is preferred that wells have been shut-in for an extended period of time. Injection fluid will normally be filtered Cook Inlet water at -55 deg F. 1. Do a base line temperature profile from surface to top of perfs. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the stops used in the baseline profile are not appropriate, make appropriate stops in this profile and use in all subsequent surveys in this well. 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. Pertinent Data: Spud Date: Surface Location: Subsurface Location: Elevation: TD: PBD: Casing Record: Perforations: Original 8/3-4/76 2nd Perforation: 9/4-7/76 3rd Perforation: 5/24/78 Reperforated: 5/30/78 · Initial Potential: Initial Stimulation: GRANITE POINT ADL 18742 WELL NO. 21 MIDDLE KENAI SANDS 6-16-76 LEG 3, SLOT 6, G.P. Platform Anna 834' FNL, 676' FEL, Sec. 12, TION, R12W, S.M. TD-3447' FNL, 1870' FEL, Sec. 12, TION, R12W, S.M. 105' KB-MSL 10,575' 9,735' TVD: 9996' TVD: 9240' 20", 94~ CSA 610' x 1285sx 13-3/8", 54.5, 61, 68~ CSA 2979' x cement to surface 9-5/8", 40, 43.5, 47~ CSA 10,573 x 1100sx C-5: C-7: 8932-8935'~ x ~ 9005-9085' ~ - 9348'9374 !t 9430-9486 )06 9536-9560 C-8: 9680-9724F~ 9745-9798'~queezed 9808-9834'~, 10145-10154'~ -- 4 JSPF C-5: C-7: 9005-9085.') 9348-9374) 9430-9486; 9536-9560. C-8: 9680-9724' 4 JSPF Dresser Atlas C-4: 8862-8865' Perfs Squeezed 3 JSPF DresSer Atlas C-5: 8940-8990' 2 JSPF Dressler Atlas 448 BOPD, None 570 BWPD, 86 MCFD, GOR 172 NELL FILE DOCUMENTS (~ i7335 b'ignature ;FILE NO. COMPANY AHOCO PRODUCTI ON COHPANY ' . . ~21 WELL G P 18742 ~' FIELD GRAN ITE PO I NT COUNTY KENAI STATE ALASKA LOCATION: Other Services LEG 3 SLOT & PACKER 12 ION 12W SEC~__TWP RGE Elevations: Permanent Datum H, 5. L Elev. 0 KB 10 Log Measured from K B , ] Oq Ft. Above Permanent Datum DF --- Drilling Measured from I< _ R _ GL 0 Date 5- 27- 78 CSG. RECORD Surface Protection Production Liner Run No. THREE Size 9 5/~" Depth-Driller PBTD-~ 720' Wt./Ft. 43 Depth-Logger ~, 7~ Grade ~ Bottom Logged Int. ~, 7~1 Type Joint BUTT .ogged Int. ~, 200 Top SURFACE ....... , ,,easured- ~-2,qgl Bottom Type Fluid in Csg. SALT ~ATER PRIMARY CEMENTING DATA Density of Fluid --- Type Cement Fluid Level FULL Vol. of Cement Max. Temp. Deg, F, .... Additive SEE RENt RKS Tool Series No. ] q O 8 % Additive Tool Diam. 3 ~/~" Retarder ) Standoff Size ~ENT. % Retarder ' ~ Logging Speed ...... 30' P.M. SlurryWt. -- R RIA Log Type Water Loss /J~m ...... T.C ......... Drlg. Mud Type Sens. Setting ..... Drlg. Mud Wt. Truck or Unit No. SO]I Started Pumping ...... Preceding Fluid Location K[NAI Plug on Bottom Vol: Opr. RigTime q HRS Pres. Released Returns: Full Partial None Record~by POSPISIL Started B°nd Log 01~0 ~-27 PipeRot. During Pumping: Yes No Witne~by CANSON Finished Bond Log 1030 5-27 PipeRot. After Plugdown: Yes No 5" = 1OO' II PERCENT UNBONDED PIPE . .... SIGNAL ~ 6.4 16 40 100 200 MICROSECONDS 1200 -' i ' ,, ?. 'r.? · '. I * i . L o o o o o o' o o o .1~ o o 0 6.4 40 100 PERCENT UNBONDED PiPE SIGNAL O · AMPLITUDE INCREASES._ COMPRESSION WAVE , DEPTH AMPLITU DE ACOUSTIC SIGNATURE Company AMOCO PRODUCTION COMPANY Drillers T.D. Well G.P. 187/~2 ~21 Log F.R, 9,731 Field GRANITE POINT Log T.D. 9,734 County KENAI Elevations: State ^L^S~^ K.B. ~0S D.F. -- G.L CEMENT STRENGTH - I Cgunty KENAI ~. Elevations: - State ALASKA K B los D.F. -- G.L. o cEMENT STRENGTH PERCENT OF SIGNAL IN UNBONDED. PIPE Spacing 5' 100 - 50- 30- 20- 10- 5- 1- .' CASING THICKNESS (inches) 0.6 0.5 0.4 0.$ AVERAGE COMPRESSIVE STRENGTH (psi) - -4000 - -3000 - -2000 - -1000 - -500 - -250 - -100 - -50 J ,/,;,~.~:.. ;,:. ?f~.',] · ... ., , ~ ~ .%,~,~': ?,- /~'::( .. , · . :.. ~. .~,.~.., . . .,~.~=. ..~ ,,, ,.. . . . , ,~ ,,..--, I' Ii '1 "111 I I' II I (~ .8~ A~p'~ N -- BEFORI 5~J ~YE r u I I I I '~ 6.4 I I i 4 - I ~ I ~ , ?. I _.~ I/DL Signature c r. C FILE NO. COMPANY AMOCO PRODUCTI ON CO, WELL GP 18742 ~':-~2 t ~ 8 '~ ~-~(>~ o o FIELD GRAN I TE P01NT 111 COUN~ K~t STATE AL~S~ LOCATION: ~her Se~i~s LEG ~¢3 SLOT ~,,6 ' SEC I 2 TWP l ON Ret Elevations: Permanent Datum HSL Elev. 0 KB 10~ ~1 ~O~ ~ E E E o o o Log Measured from ~ , I 0. ~t. Above Permanent Datum DF Drilling Measured from ~ GL ~0 Date ~ ' 2' i' 6 CSG. RECORD Sudace Prot~tion Production Liner Run No. TWO Size 9 5/8H Depth-Driller 1 O, ~ 1 2 Wt./Ft. ~3 Depth-Logger tO- 277 Grad, N-60 Bottom Logged Int. t O. 272 Type Joint BUTT Top Logged mt. 7.200 Top SURFACE Measured 3,072 Bottom ,e Fluid in Csg. SALT WATI :R PRIMARY CEMENTING DATA i i ~nsityof Fluid 8,8¢~ Ty~ Cement ' Fluid Level FULL Vol, of Cement WSEE S )UEEZE D! TAILS] Max. Temp, Deg. F .... Additive ~ REH (RKS Tool Series No. ~ ~08H % Additive Tool Diam. ~ ~/8tl Retarder ~ ~t~t Standoff Size C~N'J', % Retarder ~ · t '" 0 R/ALogType - . . WaterLoss '~[~U~- ~ ~): ~ .~L~ T.C.,.. ..... Drlg. Mud Type ~~ ~ -- Sene. Setting - - - Drlg. MudWt. t -- APl Units/Div .... PRIMARY CEMENTING PROCEDURE '~ ~ ~ ~ruc~orUnaNo. ~0~2 S~ane~Pumcn~ .... Preceamg~u~a HU~ FLUSH ~ . .~ F ~ ~ ~ ~ ~ ~ ~ ~'~ Opr. RigTime 3,5~'{RS Pres. Released Returns: Full Pa.ial None ,'~ ~ ~! E ~ ~ ' g E ~ ~ ~ = J ~ 8 ~ o Record~by ...... ~[~J~:[~ Started a°nd Log 0~00~/2~ PipeRot. During Pumping: Yes No ~ ~ ~ m ~ ~ = ~ O ~'~':[:'~JT Finished Bond Log ~3D~/2;Pi~Rot. After P~ugaown: Yes No ~ m - ~ ~ ~ ~ = ~ ~ ~ ~ ~ = ~ ~ o:~ _ iiii i iii ii Casing Col~ -- -- 7300 ,, . . ~ · 7400 _,,, PERCENT UNBONDED PIPE SIGNAL ,11. iI I ~,~o~o~o~ . D6.4. 16 40 10.( ;~00 I 2,~O 7500 76OO 7700 7800, 79OO 8000 8 I00 8200 8300 8400 8500 .8600 '8700 8800 8900 .. 9000 -- ~. 9100 .;_. __ 9:>00 -- .~. · L 9300 -- "8 ~ _ _ '""8 ~ . '~ [=" 9400 .9400 9500 96~o 9700 9700 9800 9900 I0000 I0000 IOlO0 10200 10300 IIII !lm i1~°o MICROSECONDS II I J 200 MICROSECONDS 1200 6.4 16 40 ' 10( PERCENT UNBONDED PIPE SIGNAL ~.. '. AMPLITUDE INCREASES_ COMPRESSION WAVE' DEPTH AMPLITU DE VARIABLE DENSITY Company AHOCO PRODUCTION CO. Drillers T.D. 10,412 Well c~P 18742 ~21 Log F.R. 10,272 Field GRAN ~ T E PO l NT Log T.D. ; o, 277 County i.<~P~,A ~ Elevations: State ALASKA K.B. 105 D.F. G.L. CEMENT STRENGTH PERCENT OF SIGNAL AVERAGE IN UNBONDED PIPE COMPRESSIVE Spacing STRENGTH (psi) $, 50- 10- 2 - I - CASING THICKNESS (inches) 0.6 0.5 O.$ 10000 I0000 '10100 10200 r i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS pe of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved prOgram: Pu~'~ tUl~ing: Variance: ~ Perforate: Other: 'X 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: Middle Ground Shoals 4. Location of well at surface ..... ;¢~~E ~ ~ '~i'~ 8. Well number 834' FNL, 676' FEL, Sec. 12, T10N, R12W, SM RE:CL .. ~ Anna-21 At top of productive interval 9. Permit number 3121' FNL, 1283' FEL, Sec. 12, T10N, R12W, SM ~ ~f~ At effective depth AUG 2 i 2:000 lO. APl number 50- 733-20291-00 At total depth ~8.~ OJi & G~ L;OR$, 00~!Tli~[Ot3 11. Field/Pool 3447' FNL, 1870' FEL, Sec. 1, T10N, R12W, S.M. ~J3¢t{)1'~8 Middle Kenai "C" Sands i 2. Present well condition summary Total depth: measured 10,575' feet Plugs (measured) true vertical 9,996' feet . Effective depth: measured 9,735' feet Junk (measured) true vertical 9,240' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 610' 20" 1285 sx 610' 610' Surface 2979' 13-3/8" Cmt to surface 2979' 2949' ~ Intermediate Production 10573' 9-5/8" 1100 sx 10573' 9994' Liner Perforation depth: measured '" 8932'-8995', 9005'-9085', 9348'-9374', 9430'-9486', 9534'-9560' true vertical 8499'-8558', 8568'-8642', 8886'-8909', 8961'-9012', 9057'-9081' Tubing (size, grade, and measured depth) 3-1/2" LS, 9.2#, L-80 @ 9569', 2" HS-80, .109' wall coil tubing @ 8747' Packers and SSSV (type and measured depth) Baker" x 3-1/2" FA-1 Perm Pkr @ 8747' in the LS 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Conversion to a Water Injector 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: 17. I hereby cert~~s true and correct to the best of my knowledge. ~.;j Signed: ' Title: ~,~. ~'l/~4¢~ ~¢'~ ~/~~' Date: ~' ' ' "~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval N°. Plug integrity. ,. ~fBOP Test Location clearance. - I Mechanical Integ¢,[~ Test ~,. Subsequent form required 10-~ ¢,,. O,t,~ ¥CzI[::~¥-¥'~ Approved by order of the Commissioner O 1'2j¥tOt' se~mou¢' -- Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Procedures to Obtain Variances on Packerless Wells (version 4) February 9, 2000 It is preferred that wells have been shut-in for an extended period of time. Injection fluid will normally be filtered Cook Inlet water at -55 deg F. 1. Do a base line temperature profile from surface to top of perfs. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the Stops used in the baseline profile are not appropriate, make appropriate stops in this profile and use in all subsequent surveys in this well 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. UNOCAL RKB to TBG Head = 33' Packer @ 8739' Tubing ~"~,S 8759' I 'Tubing Jet Cut. @ 8829' Live Pelf gun left at 9070' Fill tagged @ 9,560' 4/1/96 Tubing Holes 8757'- 8763' Anna Well No. 21 Actual Coil Tubing Jet Pump Completion as Run 2/16/99 I :.... CASING AND TUBING DETAIL SIZE WY GRADE CONN ID TOP BTM. 20" 94 Surface 610' 13-3/8" 54.5/68 $-55 12.615 Surface 2,979' 9-5/8" 40/47 N-80 & S-95 8.5" restr ID @ 8972'- Surface 10573' 9005' Tubing: LS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 9569' SS 3-1/2" 9.2 L-80 BTC SC 2.992 Surface 8785' SS 2-3/8" 4.6 1.995 8785' 8796' 2" .109" wall HS-80 Coil Tbg 1.782" Surface 8698' JEWELRY DETAIL l~'O~ Depth ID OD Item 35' 8799' 8799' 8824' 8979' 9569' 9 9600' 2.992 3.5 ~687 3.865 2.992 3.5 8785' 2.992 3.5 8785' 1.995 2.375 8688' 1.300 2.75" 8697' 1.440 2.20" 8698' 1.375 2.765 Tops 8732' 1.625 2.27" 8737' 1.300 2.75" 8747' 1.440 2.20" 8747' 1.375 2.765 Dual Tubing Hanger 3-1/2" BTC tbg Kobe 3" Cavity, Type B S/N L-236 3-1/2" BTC tbg Blast Joints, 8979'-9067' Live peff gun fish left in hole 3-1/2" BTC tubing ' 3-1/2" Muleshoe Baker DB packer Short String 3-1/2" BTC robing bottom 2-3/8" pup with XO to 3-1/2" in top of cavity Baker seal bore extension with 10' seal nssy Baker K-22 anchor Baker "FA-I" packer with 10' seal bore extension on top Actual 2" Coil Tubing (.109" wall) in Long String 1-1/2" jet pump cavity with standing valve Baker seal bore extension with 10' seal assy Baker K-22 anchor Baker "FA-1" packer with 10' seal bore extension on top E-line set packer at 8739' ELM PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/24/78 8,862, 8,865' 3' 3 Squeezed 9/76,6/96 C-5 8,932' 8,995' 63' 8-12 9/76,6/96 C-4 9,005' 9,085' 80' 12-18 4/2J96 C-7 9, ..'.'.'.'.'.'.'.'.'M8' 9,374' 26' 14 4/2/96 C-7 9,430' 9,486' 56' 18 9/76,4/96 C-7 9,534' 9,560' 26' 6-14 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' Anna 21 2-16-99 final dwg.doc 07/12/99 Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL August 15, 2000 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Expansion of the Anna Waterflood Dear Tom: In follow up to the apparent success of the Baker Waterflood Expansion/Reactivation earlier this year, we realize if we could obtain variances on many of the shut-in and low producers on the Anna Platform, there are probably incremental reserves to be obtained. We have had many mechanical problems with our injection pumps since 1995 and had several attempts to repair and replace them. Even with the current oil prices most waterflood projects on this platform are difficult to justify due to the short expected life of the field. We would like to convert 7 of our wells to injection without any mechanical changes to the current completions. If we are able to prove casing integrity in each of these wells (all are packerless) via temp surveys and the wells are able to take sufficient amounts of water, we believe we can justify the repair and possibly the expansion of the surface equipment to increase the injection rate and reduce the decline rate on this platform. The plan is to convert the 7 wells, test them over the subsequent 6 months then size the appropriate surface facilities for our platform. No downhole modifications are planned except cutting tubing and dropping TCP guns. None of the wells have packers and the economics will not allow us to work the wells over. The variances will be based on a pair of temperature surveys before and after injection. There are no fresh water aquifers at risk and there are no shallow gas reservoirs in this area of the field. All wells will be protected through close monitoring of our injection operations which will recognize any casing/well failures. Below is a list of the conversions: AN-21, 25, 26, 32RD, 36, 37 and 38 The facilities modifications are planned to be initiated immediately upon the approval of this package by the AOGCC and the surface modifications will be sized and installed in mid-2001. As the wells are modified we will begin the series of temperature surveys and injection tests in order to prove casing integrity. Attachments: 10-403 Forms Wellbore Diagrams Location Map Reactivation Plan Senior Reservoir Engineer Cook Inlet Waterflood Management Description Summary to Convert Anna Producers into Injectors Anna 21 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 25 · Gage Tbg. ~li~" Temp Survey. · Place on injection for 1 month. Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 26 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 32 · Gage Tbg. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 37 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 38 · Gage Tbg. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: 'X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development: X KB 105' above MSL feet ...... 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Granite Point 18742 4. Location of well at surface 8. Well number 834' FNL, 676' FEL, Sec. 12, T10N, R12W, SM Anna-21 At top of productive interval 9. Permit nu mber,(approval n~.~b{~ 3121' FNL, 1283' EEL, Sec. 12, TION, R12W, SM At effective depth 10. APl number 50-733-20291 At total depth 11. Field/Pool 3447' FNL, 1870' FEL, Sec. 12, TION, R12W, SM Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 10575 feet Plugs (measured) true vertical 9996 ,e~, ORIGINAL Effective depth: measured 9735 feet Junk (measured) true vertical 9240 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 610' 20" 1285 sx 610' 610' Surface 2979' 13-3/8" Cmt to surface 2979' 2949' Intermediate Production 10573' 9-5/8" 1100 sx 10573' 9994' Liner Perforation depth: measured 8932'-8995', 9005'-9085', 9348'-9374', 9430'-9486', 9534'-9560' true vertical 8499'-8558', 8568'-8642', 8886'-8909', 8961 '-9012', 9057'-9081' Tubing (size, grade, and measured depth) 3-1/2" long string, 9.2#, L-80 @ 9569', 2" HS-80,. 109" wall coil tubing @ 8747' Packers and SSSV (type and measured depth) Baker 2" x 3-1/2" FA-1 Perm Packer @ 8747' in the long string 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 140 3500 jet pump Subsequent to operation 41 52 140 3500 jet pump 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: AFE #133644 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 1/4/99 1/5/99 1/6/99 1/7/99 1/8/99 Anna Well An-21 Daily Summary of Operations RU slickline unit on AN-21 ss. RIH with 2.25" LIB, tag "W" plug at 8817'. Recover asphaltene on LIB. RIH with 1.75" pump bailer and recover ashaltene/sludge on 5 separate trips. RIH with 2.5" RS pulling tool and latch "W" plug. Sheared off. POOH and repin RS pulling tool. RIH and latch plug but sheared off again. RIH with 2.5" GS adaptor/bait. Latch plug at 8817' but sheared off again. RIH with GS adaptor pinned with brass and JDS pulling tool pinned with stell. Latch plug at 8817' and slowly POOH from 8817' to 8217' with 1000 lb drag. Shut down to rest crew. Continue and POOH with W plug, drag decreased above 6800'. POOH with "W" plug, missing 1/3 of rubber packing. RIH with 2.875" gauge ring in short string and tag at 8818'. RU on long string and shake off standing valve at 330'. Pump power oil down LS and taking returns up SS for a total of 126 bbls up short string. RIH and pull equalizing prong of standing valve in LS. Attempt to pull standing valve in LS at 8853', no recovery. Try new pulling tool and recover standing valve from LS. RD from long string and RU on short string. RIH with 2.875" x 3'7" long dummy gun. Set down at 997'. RIH with 2.810" broach to 8815'. RIH with 2.843" broach to 8815'. RIH with 2.867" braoch and sat down at 3251'. POOH with 2.867" broach without working broach. Attempt to run 2.765" x 3' dummy gun. Sat down at 7707'. Jar free and POOH. RIH with 2.867" broach and chip through obstruction at 3251 '-3254'. Fell free to 7800'. Jar down and fell to 2-3/8" x 3-1/2" tubing crossover at 8815'. Broach was stuck in crossover. Attempt to jar broach free with no success. Drop SV in Long String and pump power oil down LS, pressure up to 900 psi and plug jarred free in short string. POOH with brach from SS. Unplug LS/SS with 1400 psi down LS. Circulate 150 bbls to surface on short string. RIH with 2.867" broach in SS to 8800' with no problems. RIH with 2.765" x 3' dummy gun and set down at 7880'. Fell through to 8038', POOH with dummy gun from SS. Circulate down LS and up SS with 110 bbls to surface. RIH with 2.867" broach, sticky from 7800' to 8800', POOH from SS. Circulate down LS and up SS with 150 bbls to surface. RIH with 3-1/2" braided line brush in SS while pumping down LS and returns up SS. Work brush from 7000' to 8800'. POOH. Total of 206 bbls pumped as brush returned to surface and them pumped 76 additional bbls up SS. RIH with 2.765" x 3' dummy gun to 8800' (somewhat slower speed from 6900' to 8800'). POOH with dummy gun. Circ down LS and up SS with 110 bbls to surface. RD from SS and RU on LS. Pull equalizing prong from standing valve at 8853' in LS. RIH and attempt to latch standing valve. No recovery. Recovered standing valve from LS on 3rd attempt. RIH with 2.875" gauge ring in long string to 8833', POOH with GR. RIH with 2.765" x 3' dummy gun to 8833' in LS, and POOH. RD slickline from Anna 21. Pump 100 bbls power oil down An-21 ss for final wash. 1/16/99 RU APRS E-line unit on An-21 ss. RIH with 1-9/16" hollow carrier tubing perforating gun, 6' long and 22 shots. Perf 3-1/2" ss tubing from 8757' -8763' (4' below a collar) POOH with spent gun. RIH with 2.765" x 3' long dummy gun in short string to 8750' with no problem. POOH with dummy gun. RIH with Baker FA 3-1/2" packer. Set packer at 8698' in short string. POOH and RD APRS. An-21 daily summary.doc Page # 1 03/10/99 1/23/99 1/24/99 1/25/99 Anna Well An-21 Daily Summary of Operations Move CT BOPs from An-26 to An-21 short string. Test CT BOPs to 250 psi/4500 psi. MU CT connector and pull test to 30,000 lbs. Load coil with CaCI brine. MU jet pump BHA with isolation sleeve and Baker anchor with upper PBR on bottom of 2" coil. RIH to 8500', check up weight @ 20,000 lb and down weight @ 12,000 lb. SD for crew sleep. Continue RIH and set down at 8658' CTM (top of packer was set at 8698' ELM). No indication of anchor seals entering packer seal bore. Pressure test tubing x CT annulus to 1000 psi. PU 25,500 lbs (7000 lb over PU weight) and shear pins in PBR. PU' 8' and pressure test annulus to 1000 psi. PU all the way to 8640' and still able to obtain 1000 psi pressure test on annulus. (Seal bore of upper PBR is only 10' long so something is wrong). RIH and set down at 8655' CTM. POOH with coil and recover seal assy, left Upper PBR, anchor and packer in hole. Attempt to pump down short string with power oil, pressured up to 2500 psi with no bleed off. RU slickline on short string. RIH with 2.300" LIB and set down at 8662' wlm. POOH and LIB indicated top of PBR. RIH with 1-1/2" drive down bailer, set down at 8672' wlm. Jar down to 8674'. Jar free, POOH and recover 8 oz asphaltenes. RD from short string and RU slickline on long string. RIH with 2.765" x 3' long dummy gun to 8775' wlm, no problems. POOH and RD slickline. Flush long string with 76+ bbl of power oil. Shut down and wait for packer for long string. 2/8/99 2/12/99 2/13/99 2/15/99 2/16/99 RU slickline unit on long string. RIH with 2.600" gauge ring. Bobbled thru Kobe cavity at 8837' to 8862' wlm and continue RIH to 8950'. POOH and RD slickline. RU APRS wireline unit on long string. RIH with 2.59" tubing jet cutter. Cut tbg @ 8829' (middle of joint below Kobe cavity). POOH with jet cutter. RIH with 2' long tbg punch. Shoot holes in tbg @ 8757'-8759' (4' below collar of first full joint above Kobe cavity). POOH with tbg punch. RIH with 2.765" x 2' long dummy gun to 8747', no problems. POOH with dummy gun. Flush long string with 76+ bbls of power oil. Annuluar returns observed at 11 bbls pumped. Shut-in well with 100 psi on long string. Pump FIW down long string until tubing pressure = 0 psi. RIH with baker FA-1 packer on E-line. Set packer at 8739' elm. POOH and RD APRS. RU coil tubing unit on long string. Pressure test BOPE, MU jet pump BHA with isolation sleeve in pump cavity. Pressure test BHA to 2500 psi with CaCL water. MU anchor latch/seal bore extension and seal assembly on bottom of BHA. RIH with BHA on 2" coil. Shut down for night at 8550 CTM. Tag top of packer at 8684' CTM which is 55' high to E-line packer depth. Pressure test CT x 3-1/2" tbg annulus to 1000 psi, OK. Pull test to 2K to verify coil is anchored in top of packer. Pump down coil 16 bbls with returns on tbg x 9-5/8" annulus but no returns on CT x tbg annulus. PU and shear out seal assy from seal bore extension with 6k overpull. PU 10' and could pump down CT x tbg annulus with no sign of blockage. Run seals into seal bore extension and mark coil at surface for hanger installation. PU and cut coil, install Versatech CT hanger. Land hanger and pressure test CT x tbg annulus to 1000 psi, OK. Pump down coil to release GS running tool. RD coil tubing. RU slickline unit. RIH to 8762' wlm and retrieve cavity isolation sleeve. RD slickline. Drop standing valve and jet pump down long string. Begin pumping well. An-21 daily summary.doc Page #2 03/10/99 ~nna Well No. 21 Actual Coil Tubing Jet Pump Completion as Run 2/16/99 RKB to TBG Head = 33' Tubing Holes 8757'- 8763' SIZE CASING AND TUBING DETAIl WT GRADE CONN ID TOP BTM. 20" 94 Surface 610' 13-3/8" 54.5~8 J-55 12.615 Surhce2,979' 9-5/8" 40 ~7 N-80 & S-95 8.5'reslrlD @8972'- Surhce 1057q' 9005' Tubing: 'LS 3d/2"9.2 I,-80 BTC SC 2.992 Surf, to:, 9569' SS 3-1/? 9.2 L..80 BTC SC 2.992 Sm~ace 8785' SS 2-3/8"4.6 1.995 8785' 8796' 2' !O9 w~ {880 Coi Fhg ?82 Sm%~vz 8698 JEWELRY DETAIL ~O_. Del~tl~ lID OD Item t 35' Dual Tubing Hanger 2 8799' 2.992 3.5 %1/2" BTC tbg 3 8799' 2,687 3.865Kobe 3" Cavity~ Type B S/N L-236 4 8824' 2.992 3.5 3-I/2" BTC tbg 5 8979' Blast Joints, 8979'-9067' 6 Live peff gun fish left in hole 8 9569' 31/2" Muleshoe 9600' Baker DB packer Short Siring 8785' 2.992 3.5 3-l/2" BTC tubing bottom 8785' 1.995 2.375 2-3/8" pup with XO to 3-1/2' in top of cavity 8688' 1.300 2,75" Baker seal bore extension wid~ 10' seal a&sy 8697' 1,440 2.20" Baker K-22 anchor 8698' 1.375 2.765 Bakm' "FA-1" packer with i 0~ seal bore extension oa top : 8732' ~625 227' I U2 )e~ p~mp c:*vi y w~h ,~4aading ,mire PERFORATION HISTORY Oai; Zone ] Top [ Btm ' A~mt ;~; 5/24/78 8,862' 8,86~5'_ _.._. ~i 3 .Squeezed ~/76 6/06 C-S 8,932' 8,995' 63' 8-12 9~6,6/96 C-4 9,005' 9,085' 80' 12~18 4/2/96 C-7 i 9 348' 9 374'' 26' 14 4/2/96 C-7 9,430' 9,486' 56' i 18 PBTD = 9735' TD = 10,575' MAX HOLE ANGLE = 25° 9800' Anna 21 2-16-99 final dwg,doc 03/10/99 Unocal Energy Resources Divi. 909 West 9th, P.O. BOX 196247 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-13 June 6,1996 Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. - 0'-I'1 Granite Point / Anna-21 fil~"blackline'" Completion Record 4/01/96 -~'~ Granite Point ~ Anna-26 f, flm / blackline ~ Tubing Packer Setting Record 4/20/96 .,tie ' Granite .Point / Anna-36 f~I¢", blackline,'" Completion-Record 5/20/96 · l,f~ Granite Point/42-23 RDf~m/ blackline"'"' Perforating Depth Control 2/17/96 ~ 0.~,~Trading Bay Unit K-26 RD 'film,-/'blackline~" Main Pass (Collar Locator) 3/23/96 =i$~ ~ Trading Bay Unit M-5 ¢if2m / blackline---' Completion Record 2/14/96 Trading Bay Unit M-25 ¢i4fn / blackline,.----Oompletion Record 4/24/96 '0~G Trading Bay Unit M-25 ~ifrf{'/blacklinec--mCompletion Record 4/30/96 Trading Bay Unit. G-21 " ¢ib'r~,~blackline,~ CCL/Gamma Ray 4/03/96 Trading Bay Unit G'21 fii~ blackline,-' Cement Retainer 4/08/96 Trading Bay Unit G-21 4,rrm / blackline--" Completion Record 4/13/96 /4 ~'' Trading Bay Unit G-21 ~ / blacklineL,-' Completion Record 4/18/96 Trading Bay Unit G-21 f~ / blackline--' Completion Record 4/22/96 Trad.(,ng Bay Unit G-21 ,,film / blackline~- Completion Record 4/25/96 Trading Bay unit .G-21 ¢i~/blackline-," Completion Record/2 1/8 Energet 3SPF 4/15/96 Trading Bay Unit G-21 . Lf~ / blackline,-' Gamma Ray/Temperature 4/10/96 Trading Bay.,U.nit G-21 ~ / blackline/ Tubing Cutter 4/08/96 ' ~1~{-:' -CRU 34 I-I,/~J c ~ :~ ~t --'4 d, ll'm / blackline ,- Completion Record 5/17/96 1 7~ RECEIVED 263-7828. Ple~..se~acknowle,~r./~eiptbYl~igningan,~.retumingonecopyofthistransmittal or FAX to (907) ,JUN 11 19..91 A~orage W. G. Smith District Manager May 15, 1985 Amoco Production Company Post Office Box 100779 Anchorage, A lask a 99510 907-272-8471 File. TJZ-175-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Notice Granite Point 18742 Well No. 21 Platform Anna, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to pulling tubing and replacing the bottomhole assembly in Granite Point 18742 Well No. 21. The well was returned to production and is currently being tested. Any questions concerning this project may be directed to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith District J~anager Attachment ~qTS/dds RECE!'V D Alaska 0ii & Gas Cons. G~)n~mission Anchorage STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL,I~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 76-49 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20291 4. Location of Well Leg 3, Slot 6, Granite Point Platform Anna 834' FNL, 676' FEL, Sec. 12, TION, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' KB, MSt I 6 . Lease Designation and Serial No. ADL 18742 12. 9. Unit or Lease Name Granite Point 18742 10. Well Number 21 11. Field and Pool Granite Point Field Middle Kenai "C" Sands Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing ,~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed OPerations (Clearly state all pertinent details and give pertinent dates, including estimated date of sta,~g any proposed ;": ..... work, for Abandonment see 20 AAC 25.105-170). .. " Amoco Production Company performed the following work: "~ ~.. i Circulated and killed the well with diesel _q~ ~'~, ' ' , ~ 2. Set back-pressure valves, nippled down tree, nippled up BOP s ~o~ tested to 2,500 psi. Pulled back-pressure valves. 3. Rigged up wireline, cut short string, and rigged down. ~ 4. Attempted to pull short string with no success. Cut short string at 3,103 feet. Pulled short string. 5. Attempted to pull long string with no success. Cut long string at 3,193 feet. Pulled long string. 6. Fished remaining tubing, bottomhole assembly, and tailpipe out of wel 1 bore. 7. Ran a 7½-inch and 8½-inch casing swedge through tight spot in casing at 8,970 feet. 8. Ran tubing and new bottomhole assembly. Bottomhole assembly set at 8,800 feet and tailpipe set at 9,569 feet. 9.Set back-pressure valves, nippled down BOP's, nippled up tree and tested to 4,000 psi. Pulled back-pressure valves. 10.Returned well to production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Di stri ct Manager The space below for Commission use Date 05/15/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 ;Anchorage, Alaska 99510 :~907-272-8471 May 1, 1985 File' TJZ-145-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent Granite Point 18742 Well No. 21 Platform Anna, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to pull tubing and replace the bottomhole assemlby in Granite Point 18742 Well No. 21. The existing bottomhole assembly is failing and has an engine efficiency of 31 percent. Replacing the bottomhole assembly prior to it failing will eliminate any downtime caused from the failure. We plan to begin this work as soon as possible. Any questions concerning this project may be directed to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachment MTS/dds iRECEIVED MAY 0 ]~ 1965 ,~,h~ska 0i~ & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name o[Operator Amoco Production Company 3. Addressp. 0. BOX 100779, Anchorage, Alaska 99510 4. Location of Well Leg 3, Slot 6, Granite Point Platform Anna 834' FNL, 676' FEL, Sec. 12, T10N, R12W, S.M. 7. Permit No. 76-49 8. APl Number 50- 733-20291 9. Unit or Lease Name Granite Point 18742 10. Well Number 21 11. Field and Pool Granite Point Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Mi ddl e Kenai "C" Sands 105' KB, MSL I ADL 18742 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to perform the following work' 1. Circulate and kill the well. 2. Rig up wireline, cut short string, and rig down. 3. Set back-pressure valves, nipple down tree, nipple up BOP's and test to 2,500 psi. Pull back-pressure valves. 4. Pull tubing and bottomhole assembly. 5. Run tubing and new bottomhole assembly. 6. Set back-pressure valves, nipple down BOP's, nipple up tree and test to 4,000 psi. Pull back-pressure valves. Circulate well with power oil and return to production. 14. I hereby certify that.the fore, gOing is true an~j.:correct to the best of my knowledge. District Manager The space below for Commission use Date 0510'I185 Conditions of Approval, if any: Approved by Form 10-403 F~v 7-1-R~ COMMISSIONER ~turned By Order of the Commission Submit "Intentions" i,'~ Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow Area Superintendent Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 m June 26, 1978 File: LAD-640-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas ConserVation Department of Nat,,ral Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Sundry Notice Granite Point.t8742 Well No. 21 PlatformAnna ..... Attached in duplicate is the Subsequent Report, Form 10-403 describin~ the repair of Granite Point 18742 Well No. 21. Yours very truly, · .->' /,, I~.~*~-' ~. A. Darsow Area Superintendent Attachments RET:sls RECEIVED JUN 2 8 Division oi Oil ~nd Gas Co.se~tion Anchorage Form 10-403 REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5, APl NUMERICAL CODE 50-133-20291 6. LEASE DESIGNATION AND SERIAL NO. ADZ. 18742 7..IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Amoco Production Company Granite Point State 18742 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 21 4, LOCATION OF WELL At surface Leg 3, Slot 6, Granite Point Platform Anna 834' FNL, 676' FEL, Sec. 12, T10N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB-105 ' KM-MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO. 76-49 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* 'CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE-' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly ~ate all pertinent details, and give pertinent dates, including estimated date of ~arting any proposed work. Work Performed May 15 - June 16, 1978 1. Cut tailpipe at 9420'. Pulled Production equipment. 2. Fish and recover 108' 2-7/8" tailpipe. 3. Clean out to PBD (9735'). 4. DST C-8 zone perforations 9680-9724'. Recover sample of 63 gal. 38° oil with 1% BS&W. 5. DST C-5 zone perforations 8932-8995' and 9005-9085'. Recover sample of 2 gal. free water and 61 gal. 38° oil with 1% BS&W. 6. DST C-7 zone perforations 9348-9374', 9430-9487' and 9535-9560'. Recover sample of 63 gal. 38° oil with 1.5% BS&W. 7. Perforate 8862-8865' with 3 JSPF. Cement squeeze with 150 sacks of cement. 8. Drill cement and clean out to PBD (9735'). 9. Reperforate 8940-8990' with 2 JSPF. 10. Complete well with downhole equipment so that the C-8 can be isolated at a later date (packer set at 9600','F-Nipple set at 9505'). 11. Return well to production, t(~ E]VEO Well Test: Before 174 BOPD, 522 BWPD JUN 28 i~ After 362 BOPD, 34 BW-PD 16. I hereby certify that the foregoing is true and correct 9ivisio. oi Oil :~n¢; ~a,, OoP,~,tio~l Anoh,'~ral;ll L. A. Darsow TITLE Area Superintendent DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 k A. Darsow Area Superintendent May 15, 1978 File: LAD-508-WF Mr. O. K. Gilbreth, Director Division of 0il and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Sundry Notice Granite Point 18742 Well No. 21. · PlatformAnna~ COOk Inlet,'Alaska Attached in triplicatefor your approval is a Form 10-403 for a workover on Granite Point 18742 Well No. 21 to locate and shut-off water. Yours very truly, /"~ L. A. Darsow Area Superintendent Attachment s WEN:klt Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20291 6. LEASE DESIGNATION ANO SERIAL NO. ADL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~' O,L ~ GAS [--] WELLI--~.J WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Amoco Production Company Granite Point State 18742 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 3, Slot 6, Granite Point Platform Anna 834' FNL, 676' FEL, Sec. 12, T10N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB - 105' MSL Check Appropriate Box To Indicate Nature of Notice, Rel 14. 9. WELL NO. 21 10. FIELD AND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 12. PERMIT NO. 76-49 3orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING ORACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢let&lls, and give pertinent dates, including estimated date of starting any proposed work. The following is the proposed procedure to locate and shut-off water production: 1. Pull production equipment. 2. DST C-8 zone perforations 9680-9724' MD. 3. DST C-5 zone perforations 8932-8995' MD and 9005-9085' MD. 4. .If water is entering through C-8 perforations, set permanent bridge plug at 9600' MD. 5. If water is entering through C-5 perforations, perforate 8902-8904' and 8800-8802' with 3 JSPF and block squeeze. 6. Clean out to PBTD and return well to production. RECE!VEF MAY .1. D!visi0n oi 0il ~"' Anchorage TiTLEArea Superintendent DATE May 15, 1978 (This space for State office use) APPROVED BY ~~ CONDITIONS OF APPI:~VAL, IF ANY: See Instructions On Reverse Side G. J. Ross Area Superintendent December 7, 1976 File: GJR-883-WF Mr. Hoyle Hamilton, Director Division of 0il and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Completion Report Granite Point 18742 Well No. 21 Please find attached our P-7, Completion Report, for the subject well. Yours very truly, ' George J. Ross Area Superintendent Attachments FOl~m P--7 WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL DR'/' Other. b. TYPE OF COMPLETION: NEW [] WORI( [~] DEEP-[] PLUG[] DIFF.[] ~VELL OVER EN BACK RESVR. Other SUBMIT IN DIfPI'i E* STATE OF ALASKA !St-,.{_,the,' h,- slruclior s on reverse side} 5. AP1 NI/I~LEItlC2, L ~,ODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20291 NAME OF OPERATOR Amoco Production Company ADDRESS OF OPERATOR P. 0. Box 779~ Anchorage~ Alaska 99510 LOCATION OF wEL£-(Re~ort location clearly and in accordance with any State requirements)* Atsufface Leg 3, Slot 6, Granite Point Platform Anna, 834' FNL, 676' FEL, Sec. 12, T10N, R12W, S.M. At top prod. interval reported below 9932' MD, 3121' FNL, 1283' FEL, Sec. 12, T10N, R12W, S.M. At total dep~ 10,575' MD, 3447' FNL, 1870' FEL, Sec. 12, T10N, R12W, S.M. ADL-18742 '7. IF INDIA.N, ALLOTTEE OR TRIBE NA1VI~ 8. UNIT,FAILM OR LEASE NAME Granite Point State 18742 9. WELL NO. 21 10. FIELD AlqD POOL, OR WILDCAT Granite Point !11. SEC., T., R., M., (BO~FOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. '12. PERMIT 76-49 10,575' MD--9996' TVD~9735'MD/9240' TVD ~ N/A 0-10,575'!.2~.W^SOiREC~ON~. ~.. PRODUCING INT~2RVAL(S) OF THIS CoMPLETION--TO'P, BO%~rOM, NAME (MD AND r¢b)* ' I SU[I. VEY M'ADE Top- 8932' MD, 8499' TVD I Bottom- 9724' MD, 9230' TVD Middle Kenai Sand i Yes, attached 24. TYPE ELECTRIC AND OTHER LOGS RUN GR-Sonic, DIL, FDG, Dipmeter ! CASING RECORD (Report all strings set in well) C~SI2qG .,q_T~.~ WEIGHT, LB/FT. DEPTH SET (iVI. D) HOLE SIZE C~%ILNTING RECOP~D ! AMOUNT PULLED 6 26" 20" 1285 sx Cement to surface 9- 43.5 & 573' 28 PERVO ONS pl~ DU size and number) 8932-8995 ' 9430-9486' 9005-9085 ' 9536-9560 ' 9348-9374' 9680-9724' 4JSPF 750 sx G w/l% CFR-2 & 0. g?. TUBINORECOI~I) HR-7 & 350 sx G neat SCrEeN (MD) SIZE DEPTH SET (MD) ~ PACKER SET (MD) ' 29. ACID, Si!OT, Fi%AC*I'URE, CEa%~E:NT SQUEEZE, ETC. D,~TIr INTERVAL (MD) I ASIOUNr AND KIND C)F MATER/AL USED )745-9798' I75 sx G w/l% CFR-2 ! 75 sx G w/0.1Z HR-7 .9430-9486' [100 sx G w/0.i% HR-7 i i ~. P~ODUC~IO~ 9745-- 9798 ' 75 SX G w/0.1% HR-7 8-3-76 [ Pumping 3 x 2-1/8 x 1-7/8 Kobe .... . I'~ P.roducing DATZ OF T~.ST, lift. OURS TESTD ' [CI{OXE SiZE IPROD'N J~'O.l:[ OIL--BBL. GAS--iV[CF. V~A'i'Ei~--BBL. [ GAS-OIL ~ATIO ! | ITEST PEF2OD ! I ! 1 9-28-76~ 24 I --- I -----~' I' 448 I 86 I 5,70. I 172 , ~--~0W, TUBING ' [C~LNG PRESSURE [CALC~TED OIL--BBL. GAS---~vlCF. WA'fO:it--BBL. ]OIL GRAVITY-API (CORFU.) 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) [ ..... fuel and sales ~ 32. LIST OF ATTACHMENTS Chronological ~ell History, Open Hole Logs, Directional Survey 33. I hereby certif,y~at the foregoing and .~ached information is complete and correct as determined from all-available records /~. ..... ~,o //, ~'~4~ Area Suoerintendent December 7 1976 le~l ~ ~ ~~ ~_, , txr ~ ,~ ~ ~,..~. TITLE . __ £ -- - -- ...... DA rE - ' SIGNED /- (/ 67 ir , · ' , _ *~'~ee Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This' form .-ii designed for submitting a complete and correct welJ completion report end log on all types of land's and leases~in Alaska. Item: 16: Indicate Which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. ~"-Item- 20, -nd '~2:: If this well is completed fo~ separate production from more than one interval zone '(multiple-completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, top(s), boTtam(~) and name (s) (if any) for only the interval reported in item 30. Submit a separate report ~(page) oril tFi'is form, adequately identified, for each aclctitional inte~ val to be seperately produced, show- ing the ~dditional data perfinen.t to such.interval Item26: "Sacks" Cement": Attached supplemental records for this well shoulJ show the details of any mul- . tiple stage cementing anti the location of the cementing tool. Item'S28:. Submit a separate completion report on this form for each interval to be separately produc'~cl. .. (See ~instruction ,for items 20 and 22 above)..'--.~ i,i . ~' ~4. SUM~A.I~Y Ol~ ~ORMATION 'I~,S'~I~'~bUmN(; INTEI~VAI., T~TED. PI~U~ DA~A ~ ~V~I~ OF OIL~ G~. ' ' ..... ~ "~ ~'. ' 35. G~GIC MARK~ ' tZ? WA~ AND MUD , , . , See aeeached:hts~0ry-' 'S~ate "'A" 6462' ~ ~ 6178' .~. · . '. ~'state "Bu 6990' ~ 6671' 7~ · . Stat, e "C" 8466' ~ '8063' . . - . .. ...... ~ . . L ~. .. .. <-~ .... . . ~$. CQR~ DATA, A~ACIt- B~IE~ D~CRIPI~O~S O~ LITItO~OGY, POROSITY, FII~C'~, ~PP~NT DIP~2 --.: t' ~:~ AND I)E'I'~"I'EI).S.}IOWS O~' O1~, G~S O1l WA'I~. '~ i i i i"i il z i . ill, ?~? ~' ,, Granite Point 18742 Well No. 21 Chronological Well History June 16: Spud Granite Point 18742 Well No. 21. June 17-19: TD 3000'. Directionally drill 12-1/4" hole to 3000'. June 20-22: TD 3000'. Open 12-1/4" hole to 17-1/2" hole. Rig up and run 77 joints of 13-3/8", 68#, 61# and 54.5# casing. Land at 2979' and cement to surface. June 23-24: TD 3000'. Nipple up and test BOP's. Test rams, manifold and Hydril to 3000 psi. Test blind rams and casing to 1500 psi. Test witnessed and okayed by Russ Douglas, Alaska Division of Oil and Gas. June 25-30: TD 6476'. Directionally drill and survey 12-1/4" hole from 2979' to 6476'. Ju~M 1-3: TD 7271'. Directionally drill and survey 12-1/4" hole. June 4: TD 7343'. Trip in with Turbodrill and drill from 7271-7343'. Trip out and lost one cone. July 5: TD 7350'. Drill on junk. July 6-24: TD 10,575'. Drill, trip and survey 12-1/4" hole. July 25.: TD 10,575'. Run Sonic log, DIL log, Density log and Dipmeter. July 26-27: Rig up and run 9-5/8" casing. Run 240 joints of 47#, 43.5# and 40# casing. Land casing at 10,573'. July 28~>~: PBD 10,484'. Swabbing casing. August 1-2: Trip out with casing swab from 4000', 6 barrel recovery. Trip in to 5000', trip out, no recovery. Trip in with Kobe bottom hole assembly on 3-1/2" dual tubing strings. Run API tubing broach every 1000'. Land tubing at 8801'. Nipple down BOP, nipple up tree. Dis- connect lines. Skid mud house, hook up flow lines and power oil lines. Skid rig. Rig released 0800 hours, August I, 1976. August.p.: Perforate 10,145-54', 9808-34', fluid level 4000'. Perforate 9775-98', fluid level 1200'. Perforate 9745-75', fluid level 1050'. Perforate 9680-724', fluid level at surface with 50 psi. Perforate 9536-60', fluid level at surface with 50 psi. Shut-in 3 hours, pressure increased to 500 psi. Flow test annulus, 12 BPH, 105 psi and 24/64 choke. - 2- August 4: Perforate 4SPF 9430-86', 9348-74', 9005-85', 8932-95', Sonic log depths. Run bottom hole pressure survey, 3900 psi at 8780' MD. Nipple up flow line. Flow 7 BPH of diesel. Tubing pressure 65 psi, casing pressure 75-270 psi in 6 hours. August 5: Location at bottom of C-8 zone 9885' MD, 9375' TVD, 1959' FSL, 1586' FEL, Section 12, T10N, R12W, S.M. 9-5/8" casing set 10,573', July 27, 1976. Casing pressure decreased from 270 psi to 100 psi. Flow 10 BPM diesel. August 6: Run standing valve, test long string, short string and stand- ing valve to 2500 psi. Circulate tubing with power oil. Well flowing through tubing. August 7-8: 24-hour test August 7: 0 BOPD, 1062 BWPD, 1100 BPOPD at 2350 psi, 50 SPM. Power oil pressure decreased to 1250 psi at end of test. Flowing tubing pressure 65 psi. 24-hour test August 8: 0 BOPD, 1119 BWPD, 1200 BPOPD at 2700 psi, 63 SPM, tubing pressure 65 psi, 124/64 choke. August 9: Pumping, no gauge. August 10: Pumping, no gauge. August 11: 24-hour test: 1128 BF, 100% BS&W, 1200 BPOPD at 2700 psi, 52 SPM, tubing pressure 65 psi. August 14-15: Pumping, no gauge. August 16: Reverse out Kobe pump, pull standing valve. Operations commenced 2331 hours, August 14, 1976. August 17: Rigging up pumps and lines. August 18: Rig up lines. Install kill lines and circulate well with 8.6 ppg salt water. Set back-pressure valves. Nipple down tree and nipple up BOP. August 19: Nipple up BOP. Raise weight of salt water to 8.9 ppg. Kill well. Cut short string tubing at 8675'. Trip out of hole and lay down short string tubing. August 20: Lay down short string tubing. Trip out and lay down long string tubing. Lay down Kobe bottom hole assembly. Change rams. Pick up 5" drillpipe. Run Baker retrievable bridge plug with pressure bomb, 24-hour clocks, RTTS packer test tool. Trip in. Set retrievable bridge plug at 9135', packer set at 8895'. Open tool for DST No. 1. - 3- August 21-23: DST No. 1, packer set at 8895', retrievable bridge plug at 9135'. Strong to weak blow in 6 hours. IO 6 hours. Chart from below bridge plug:. IOF 2579-3877, IHP 4089, FHP 4037. Chart from in- side recorder: IOF 1538-3707, IHP 3882, FHP 3742. Chart from outside recorder: IOF 1575-3710, IHP 3886, FHP 3745. Reverse circulate and recover 151 barrels gas cut salt water, chlorides 40,000 ppm. Test casing to 2000 psi. Work bridge plug loose and trip out with packer and bridge plug. Sample chamber contained 60' clear salt water, chlorides 13,354 ppm, resistivity 36 at 70°F. Chart on bridge plug indicated possible communication or leaking bridge plug. Trip in to 9700' with 8-1/2" bit and 9-5/8" scraper and circulate. Trip out and lay down bit and scraper. Trip in with RTTS test tool and set at 9636' for DST No. 2. Establish communications between perforations 9536-9560' and 9680-9724'. Reset RTTS tool at 9631', communicated. Reset RTTS tool above perforations at 8844' and test to 2000 psi, okay. Trip out. Trip in with RTTS test tool for DST No. 3, packer set at 9140'. IO 8-3/4 hours, strong to weak blow in 8-3/4 hours. Chart from inside recorder: IOF 874-3321, IHP 4022, FHP 4022. Chart from outside recorder: IOF 875- 3324, IMM 4026, FHP 4026. Fluid in annulus fell when test tool was opened and refilled annulus with 15 barrels. No gas or fluid to surface. Release RTTS tool and pull up hole to 8841' and reverse circulate. Recovered clear salt water, chlorides 11,472 ppm. Resistivity 30 at 70°. Trip out and lay down RTTS tool. Trip in with retrievable packer and set at 9735', communicated. Circulate at 600 psi perforation 9745- 98' and annulus. Reset packer at 9635' and circulate at 200 psi through perforation 9680-9724' and annulus. Reset packer at 9505'. Circulate at 350 psi through perforation 9536-9560' and annulus. Reset packer at 8844' and test to 1500 psi, okay. Trip in and reset packer at 9400'. Circulate at 300 psi through perforation 9348-9374' and annulus. Trip in to 9750' and circulate to clean hole. Trip out and lay down packer. Trip in with 9-5/8" casing cement retainer on wireline. Attempt to set retainer at 9735' and would not set. Trip out with retainer on wireline. August 24: Lay down retainer. Repair wireline. Trip in with Baker cement retainer and set on wireline at 9735'. Pick up Baker cementing tool on drillpipe. Trip in, sting into retainer at 9735'. Establish circulation and unsting from retainer. Pump 10 barrels fresh water. Mix and pump 75 sacks Class G neat cement with 1% CFR-2, 5 gallons per sack fresh water for 15.8 ppg slurry, followed with 10 barrels fresh water. Sting into retainer. Pump 10.8 barrels cement at 400 psi behind casing. Unsting from retainer. Spot 5 barrels cement on top of retainer. Pull up hole 30'. Attempt to reverse out. Pump 4 barrels fluid at 500 psi. No returns to surface. Pull up hole to 8750'. Reverse out. No cement returns. Cement in place 1500 hours, August 23. Trip out of hole. Rig up Dresser-Atlas while WOC 12 hours. Pick up 9-5/8" casing gauge ring on wireline and trip in to 9320'. Stuck gauge ring. Work gauge ring loose. Trip out of hole with gauge ring on wireline. -4- August 25: Rig down wireline. Pick up 8-1/2" bit and casing scraper. Trip in to 9320'. Wash 9320-9693'. Circulate. Trip out. Lay down bit and scraper. Pick up 8-1/2" bit, 15 joints Hevi-Wate drillpipe. Trip in to 9693'. Drill hard cement 9693-9735', top of cement retainer. Drill retainer and 25' hard cement to 9760'. Push retainer to 10,443'. Trip out of hole with bit. August 26: Pick up retrievable test packer. Trip in and set at 9660'. Establish communication with annulus, 700 psi, 1/2 BPM. Release packer, pull up hole and reset at 8000'. Test packer to 1500 psi, okay. Reset packer at 9640'. Establish communication with annulus, 500 psi, 1/2 BPM. Reset packer at 9732'. Establish communication with annulus, 550 psi, 1/2 BPM. Reset packer at 9730'. Establish communication with annulus, 400 psi, 1/2 BPM. Reset packer at 9739'. Establish communication with annulus, 250 psi, 1/2 BPM. Pull up hole to 8000'. Test packer to 1500 psi, okay. Trip out of hole, lay down packer. Pick up Baker 9-5/8" cement retainer on drillpipe. Trip in. Set at 9577'. Establish circulation. Unsting from retainer. Pump 10 barrels fresh water. Pump 132 barrels workover fluid. Sting into retainer. Pump 28 barrels workover fluid. Initial pressure 950 psi, final 1350 psi, 2 BPM rate. Cement in place 2202 hours, August 25. Unsting from retainer. Reverse out approximately 10 barrels cement. Reverse to clean top of retainer. Pull up hole to 9112'. Circulate and work pipe while WOC. August 27: Sting into retainer at 9577'. Pressure to 1500 psi, held 5 minutes and okay. Pressure to 2300 psi, held 5 minutes and okay. Trip out of hole. Pick up 8-1/2" bit, two junk baskets, junk subs and 15 joints Hevi-Wate drillpipe. Trip in and drill on retainer at 9577'. Push retainer to 9608'. Drill retainer and hard cement 9608-9680'. Circulate. Trip in to 10,443' PBD. Trip out of hole. Lay down bit and junk subs. Pick up Baker retrievable test packer and trip in. August 28-30: Set packer at 9570'. Pressure to 850 psi, bled back to 500 psi in 5 minutes, no communication with annulus. Reset packer at 9590'. Pressure to 1000 psi, bled back to 700 psi in 5 minutes, no com- munication with annulus. Reset packer at 9510'. Pressure to 1000 psi, bled back to 300 psi in 15 minutes, intermittent communication with annulus. Reset packer at 9135'. Pressure to 1500 psi, bled to 500 psi in 5 minutes, no communication with annulus. Reset packer at 8840'. Pressure casing to 1200 psi, held okay. Pressure drillpipe and inject fluid at 1 BPM, 1050 psi, 1-1/4 BPM at 1450 psi, 3-1/2 BPM at 2000 psi. Shut-in drillpipe. Pressure bled from 2000 psi to 400 psi in 4 minutes. Trip out of hole with packer. Pick up Baker Model "N" cast iron bridge plug. Trip in and set at 9135'. Establish injections into perforations 8932-95', 9005-85', 4-1/4 BPM at 1800 psi. Trip out of hole. Pick up Baker cement retainer. Trip in and set at 8800'. Pump 10 barrels fresh water. Displace with 149 barrels wor~over fluid. Initial pressure -5- 2200 psi, final 2450 psi. Cement rate 1-1/3 BPM. Cement in place 0212 hours, August 28. Unsting from retainer. Reverse out, no cement to surface. Trip out and WOC. Pick up 2 junk subs, Baker milling and retrieving tools, 15 joints Hevi-Wate drillpipe. Trip in, mill on retainer at 8800'. Trip out of hole. No recovery. Pick up 8-1/2" bit. Trip in. Push retainer to 8868'. Drill on hard cement and retainer 8868-8971'. Push retainer to 9115'. Circulate. Test casing to 2500 psi, 10 minutes, held okay. Circulate. Trip out and pick up new 8-1/2" bit. Trip in and push retainer to 9135'. Drill on retainer and bridge plug at 9135'. Push bridge plug to 10,412', new PBD. Trip out and pick up Baker retrievable test packer. Trip in, set packer at 9410'. Establish communication with annulus. Reset packer at 9510'. Establish communi- cation with annulus. Reset packer at 9577'. No communication with annulus. Formation taking fluid at 1500 psi. Trip out and lay down packer. Pick up 8-1/2" bit and 9-5/8" casing scraper. Trip in to 9772'. Reverse circulate. Trip out and pick up Baker cast iron bridge plug and set at 9575'. Trip out. August 31: Trip in with cement retainer and set at 9415'. Communicated with annulus at 1-1/4 BPM and 1600 psi. Pump 10 barrels fresh water, 100 sacks Class G cement and .1% HR-7 followed by 10 barrels fresh water and 158 barrels workover fluid. Maintain annulus pressure at 1200 psi. Initial cement pressure 1875 psi, final 1875 psi, maximum 2250 psi. Cement in place 1135 hours, August 30. Unsting from retainer and reverse out 8 barrels water cut cement. Pull up to 8800' and circulate. Trip out and WOC. Trip in with 8-1/2" bit, two junk subs and 15 joints Hevi- Wate drillpipe. Tag cement at 9348'. Drill medium-hard cement 9348- 9415'. Drill retainer with medium-hard cement 9415-9442' and push to top of bridge plug at 9575'. Circulate and trip out. Lay down bit, junk subs and Hevi-Wate drillpipe. Pick up retrievable test packer. September 1: Test casing to 1500 psi for 5 minutes, okay. Pressure to 2000 psi, bled to 1700 psi in 9 minutes. Trip in and set retrievable packer at 9400'. Pressure drillpipe to 2150 psi and bled to 1700 psi in 5 minutes. No communication with annulus. Pressure drillpipe to 2100 psi and bled to 1750 psi in 7 minutes. No communication with annulus. Reset packer at 9135' and pressure annulus to 2100 psi. Bled to 1900 psi in 7 minutes. No communication with drillpipe. Reset packer at 8700' and pressure annulus to 2050 psi, 10 minutes, okay. Trip out. Trip in with 8-1/2" bit, two junk subs and 15 joints Hevi-Wate drillpipe. Drill out bridge plug at 9575' and push to 10,412'. Trip out. Pick up 9-5/8" casing scraper and trip in to 10,272' and circulate. September 2: Trip out and lay down bit and casing scraper. Pick up DST tools and trip in with 2000' salt water cushion. Set RTTS packer at 9660' for DST No. 4. Tools open at 1637 hours. Good blow on 3-1/2 hour flow test. No fluid to surface. Tools closed at 2007 hours for final -6- 4-hour shut-in. Reverse out 2000' salt water cushion and 5653', or 104 barrels, 7.4-8.3 ppg gas cut salt water with slight film oil. Trip out and lay down test tools. Inside recorder: Initial hydrostatic 4238 psi, initial flow 1138 psi, final flow 3290 psi, initial shut-in 3833 psi, final hydrostatic 4238 psi. Outside recorder: initial hydro- static 4251 psi, initial flow 1138 psi, final flow 3297 psi, initial shut-in 3847 psi, final hydrostatic 4251 psi. Lab analysis of one-quart sample: Chlorides 17,542 ppm, resistivity 29 ohm-cm at 70°. September 3: Run CBL 10,277-7200'. Good bond across squeezed perfora- tions. Set 9-5/8" cement retainer at 9735' with wireline. Trip in with cement tool on drillpipe and sting into retainer. Pressure drillpipe to 3000 psi at 1/4 BPM. Pressure annulus to 1000 psi and drillpipe to 3900 psi. Broke circulation. Release drillpipe pressure, annulus bled to 0 psi. Pump l0 barrels fresh water, 75 sacks Class G cement and 0.1% HR-7 (15.8 ppg) and 5 barrels fresh water. Displace with 169 barrels salt water. Initial pressure 1800 psi, final pressure 2300 psi at 2 BPM. Cement in place 2200 hours, September 2. Pull up to 9705' and reverse out 10 barrels cement. Pull up to 9275' and pressure casing to 500 psi for 4 hours. Trip out. Change Hydril rubber. september 4-7: Trip in with 8-1/2" bit and 9-5/8" casing scraper. Drill stringers 9606-9729' and hard cement 9729-35'. Circulate and trip out. Rig up and perforate with 4" casing gun and 4JSPF 8932-95'. Trip in to 9735' with bit and scraper, circulate and trip out. Trip in with bridge plug and RTTS tool for DST No. 5. Bridge plug set at 9150'. Packer set at 8892'. 2000' water cushion in drillpipe. Open tools at 1240 hours, September 4. Slight blow through 3-hour flow period. No fluid to surface. IO 3 hours, ISI 4 hours. Pick up and reverse out 2000' salt water cushion with 8.5 barrels 8.5 ppg salt water and no oil or gas. Trip out with RTTS packer. Inside recorder: IOF 962-1101, IHP 3900, FHP 3900, ISIP 1801. Outside recorder: IOF 981-1121, IHP 3921, FHP 3921, ISIP 1821. Chart from below bridge plug: IOF 3555-3721, IHP 3996, FHP 4033, ISIP 3660. Sample chamber recovery: salt water, chlorides 52,930 ppm, resistivity 13.2 ohm-cm at 70°. Pit fluid: chlorides 53,173, resistivity 13.1 ohm-cm at 70°. Trip in with re- trievable packer and pick up bridge plug and reset bridge plug at 9000'. Packer set at 8892'. Pressure drillpipe to 3000 psi and bled to 2400 psi in 4 minutes, 2200 psi in 6 minutes, 1250 psi in 15 minutes. Release packer, pick up bridge plug and trip out. Bridge plug chart indicated communication or leak in bridge plug. Perforate with 4" casing guns and 4JSPF 9680-9724', 9536-60', 9430-86', 9348-74', 9005-85'. Change rams, Trip in with 27 joints (848') 2-7/8" tubing tailpipe, 3" Type "B" OPF Kobe bottom hole assembly and dual 3-1/2" Buttress tubing. Broach every 1000'. Install tubing hangers and land tubing at 9685'. Top of Kobe cavity 8817'. Nipple down BOP, nipple up and test tree. - 7- September 8: Install tree and test to 5000 psi. Rig released 1200 hours, September 7. Displace well with 645 barrels power oil. Run standing valve and Kobe pump. 1200 BPOPD, 1550 psi, 56 SPM. September 9: Pump stopped stroking. Reverse pump out. Pump plugged with mill scale and three seals bad. Circulate tubing. September 10: Spot check 5 BOPH, 7% BS&W, 1300 BPOPD at 2650 psi, 54 SPM. September 11-13: 12-hour test: 237 BOPD, 61 BWPD, 0 MCFD, gravity 40.5°, 1150 BPOPD at 2450 psi, tubing pressure 75 psi, SPM 50, last stroke pressure 1950 psi. September 14: 24-hour test: 346 BOPD, 50 BWPD, 0 MCFD, gravity 40.5°, 1150 BPOPD at 2450 psi, SPM 62, last stroke pressure 1900 psi. September 15-16: Pumping, no gauge. September 17: Estimated production 350 BOPD, 350 BWPD, 1200 BPOPD at 2350 psi and 54 SPM. September 18-20: 24-hour pump test: 379 BOPD and 310 BWPD, 162 MCFD, 45% BS&W, 1200 BPOPD at 2400 psi at 54 SPM. September 21-22: Pumping, no gauge. September 23: Change pump. September 24: Pulled pump and standing valve with wireline. Prepare to run sinker bar. September 25-27: Changed pump and standing valve. Pumping, no gauge. September 28: Pump on test. September 29: Pumping, no gauge. September 30: IPP 448 BOPD, 570 BWPD, 1300 BPOPD at 2300 psi, 58 SPM, last stroke pressure 2000 psi. Final Report. Eastman/ ~-~ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ON,4 L SURVEY Amoco Production Co. COMPANY Leg 3 Slot 6 Well #21 WELL NAME Platform Anna LOCATION JOB NUMBER A676 GO1 34 TYPE OF SURVEY Gyro DATE 8-5-76 SURVEY BY Shyam Talwar OFFICE Alaska COMPLETION REPORT AUGUST 4~ 1976 AMOCO PRODUCTION CO. PLATFORM ANNA LEG 3 SLOT 6 WELL NO, 21 GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION K, B. ELEV, 105. FT COMPUTED FOR EASTHAN WHIPSTOCK INC. BY F. Mm LINDSEY AND ASSOC. RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE M~AS. DRIFT VERTICAL TH ANGLE DEPTH D M SUB DRIFT SEA DIREC DES, 0 0 0 100 0 10 99.99 200 0 [5 199,99 300 0 [0 299,99 400 0 10 399e99 600 0 [0 599,99 700 3 15 699,93 800 ~ 10 799.72 900 4 15 899.45 1000 4 20 9'99.17 0,00 '105,00 $47,00W '5,00 $47,00W 94,99 S73,00W 194,99 S89,00W 294,99 $5[.00W 394,99 N89,00W 494,99 $50.00W 594e93 $ 8.00E 69~.72 S 5.50E 794,.45 $ 3.0:OE 894,17 $ 2.50E 1100 ~ 20 1098,88 993,88 $ 2,00E 1200 4 30 1198,59 1093,59 S O,OOE '~0.0 4 20 1298,29 1193,29 S i*OOW 30 4 15 1398.01 1293,01 $ 1.50W 1500 4 ~0 1497.71 1~92,7! $ 1.50W 1600 ~ 45 1~97,37 1492,37 $ 2,50W 1700 4 ~5 1697,02 1592,02 $ 2,50W 1800 4 50 1796,67 1691.67 $ 4eOOE 1900 5 25 1896e27 1791,27 $15,50E 2000 5 45 1995e80 1890,80 $15,00E 2100 6 45 2095e20 1990m20 Sli.OOE 2200 ? 40 2194,4! 2089.~! 2300 9 5 2293,3~ 2188,34 $11,50E 2400 10 15 2391,92 2'286,92 TOTAL COORDINATES 0,00 S 0,00 W 0,10 S 0,10 W 0,28 S 0,42 W 0,34 $ 0.78 W 0,43 S 1.05 W 0,62 $ le59 W 0.81 $ 2,13 W 3.48 $ 3,16 W 9,91S 2.40 W !7,23 S 1,85 W 24,71 S 1e49 W 32,27 $ 1.20 W 39,97 S 1,06 W 47e68 S le13 W 55,17 S' 1.29 W 6.2,94 $ leSO W 71e15 S le78 W 79e~2 S 2,1~ W 87e77 S 2,05 W 96,58 $ 0,52 W 105e98 S 2,03 E I16'58 S ~.48 E 128e90 $ 6e87 E 143e20 $ 9e72 E 159,70 S 12,85 E CLOSURES DISTANCE ANGLE D M S 0.00 $ 0 0 0 W 0,14 S 47 0 0 W 0,50 $ 56 14 24 W 0.85 S 66 33 12 W 1,1~ S 67 25 45 W 1.71 $ 68 37 10 W 2,28 S 69 5 21W ~,70 $ 42 13 30 W 10.19 $ 13 37 38 W 17,33 $ 6 9 23 W 24.75 $ 3 28 19 W 32,29 S 2 8 0 W 3g,99 S i 31 47 W 47,69 $ 1 21 48 W 55.18 S 1 20 53 W 62.96 S 1 22 0 W 71e17 S i 26 23 W 79,45 $ 1 33 1W 87~80 $ 1 19 53 W 96.58 S 0 18 45 W 106,00 $ 1 6 0 E 116.67 S 2 12 8 E 129.09 S 3 3 15 E i43,53 $ 3 53 0 E I60.21S 4 36 6 £ DOG LEG SEVERITY DEG/IOOFT 0.000 0.170 0.080 0.080 0,111 0,330 0.330 3.086 0.920 0.081 0.090 0,038 0.160 0.160 0.090 0,420 0,080 0.000 0,101 0,59g 0,320 1.002 0.920 1,420 1,161 SECTION DISTANCE 0,00 0,13 0,~3 0.63 0,83 1.23 1.63 10,0t 16.44 23.09 29.85 36,80 ~3.84 50.72 57.87 65e45 73,13 80.68 88.06 95,5~ 104e17 11~.~8 126.20 139,91 RECORD Of SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONXC COMPUTER TRUE MEAS, DRIFT VERTXCAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 2500 li 40 2490,09 2385,09 S 6.50E 7600 13 35 2587,67 2482.67 S 4,50E O0 15 5 2684.55 2579,55 S 5,00E zSO0 17 55 2780,42 2675,42 S 2.50E 2900 20 30 2874,84 2769.84 S 2,50E 3000 23 5 2967,68 2862.68 5 2.50E 3100 23 50 3059e41 2954.41 S 2.00E 3200 24 0 3150.82 3045.82 S 2.00E 3300 24 15 3242.09 3137.09 5 O.50E 3400 24 45 3'333,08 3228,08 $ 0.50E 3500 24 5 3424.14 3319.14 S 0.50E 3600 24 15 3515.37 3410.37 S O.OOE 3700 23 45 3606.72 3501.72 S 0.50W 3800 24 15 3698.08 3593.08 $ l.OOW 3900 23 45 3789.43 3684.43 $ 1,00W 4000 23 35 3881.02 3776e02 $ leSOW 4100 23 30 3972.69 3867,69 S 1.50W 4200 23 20 4064e46 3959e46 $ leSOW '~0'0 22 45 4i5&.47 ~051e47 $ 2eOOW JO 21 55 4248.97 4143e97 S 2eSOW 4500 22 35 4341e52 4236e52 S 2eSOW 4600 21 45 4700 21 45 4527.00 4422e00 S 4.SOW 178.51 $ 15.58 E 200.27 5 17.67 E 224,95 5 19.72 E 253.91 $ 21.58 E 286.18 $ 23.02 E 323.27 S 24.64 E 363.06 S 26.20 E ~03.58 S 27.61 E 485.91 $ 28.87 E 527,25 S 29.23 E 568.20 $ 29.41 E 608.87 $ 29.23 E 6~9,54 S 28.70 E 690e21 S 27.99 E 730,3~ $ 27.11 E 770,28 S 26.07 E 810,01 S 25e03 E 849e14 S 23.83 E 887.12 S 22e34 E 9'24e96 $ 20.69 E 962.64 S 18,55 E 999.59 S 15.80 E 12.80 E 8.80 E 3.89 E 1.28 W 6.92 W 13.03 W ~800 20 45 4620.20 4515,20 S 5,OOW 1035,71 4900 20 35 4713.76 4608.76 $ 8.00W 1070.78 5000 20 ~5 4807.33 4702.33 S 8eOOW 1105.73 5100 20 15 490'0.99 4795e99 S 9.00W 1140e37 5200 19 45 4994e96 4889e96 SIOeOOW 1174,10 5300 19 25 5089.18 ~984.18 $11.OOW 1207,07 CLOSURES DISTANCE ANGLE D M S 179,19 S 4 59 18 E 201.05 S 5 2 38 E 225.82 S 5 0 42 E 254,22 S ~ 52 15 E 287ell S 4 35 57 E 324.21 $ ~ 21 31 E 364e01S 4 7 ~1E a0~.53 S 3 54 53 E 445.36 S ~ 40 13 E 486e77 S 3 24 1 E 528,06 S 3 10 24 E 568,96 S 2 57 47 E 609.57 5 2 4~ 56 E 650,17 S 2 31 48 E 690.77 $ 2 19 20 E 730.85 S 2 7 34 E 770,72 S 1 56 18 E 810.40 S 1 46 11E 849e47 S 1 36 28 E 887.40 S 1 26 33 E 925.19 $ 1 16 53 E 962e82 $ 1 6 14 E 999.72 $ 0 54 21E 1095.79 S 0 42 29 E 1070.81S 0 28 16 5 1105.7~ $ 0 12 $ £ i140.37 S 0 3 51W 1174.12 5 0 20 14 W 1207.1~ S 0 ~7 7 W DOG LEG SEVERITY DEG/IOOFT 1.427 1.923 1.500 2.850 2.570 2.590 0.75~ 0.150 0,356 0,500 0,660 0,181 0,507 0.507 0.500 0.179 o.ogo 0,160 0.595 0,823 0.660 0.865 0,185 1.0-02 0,~0~ 0.160 0.514 0,513 0,339 SECTION DISTANCI 155.88 174,81 196,40 221.42 250.72 283.79 319.33 355e59 392e39 429.95 504,57 541*64 578.85 616.13 653.00 689.76 726,33 762,~1 797.58 832.68 867,84 902,59 936e69 970.25 1004,08 1037.73 1070,76 1103.28 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5400 19 15 5183.53 5078,53 $12.50W 1239.49 S ~500 19 30 5277,87 5172,87 S13,00W 1271,85 S O0 19 ~5 5372,06 5267,06 SiS.50W 1304e40 S ~?00 19 ~5 5~66.18 5361,18 S16.00W 1336.92 S 5800 20 0 5560,22 5455,22 SlT,OOW 1369e52 S 5900 19 25 565~,36 5549.36 $18eSOW 1401.64 $ 6000 20 15 5748.~2 5643,42 $19.50W 1433,73 6100 20 ~5 5842.09 5737e09 $21.50w 1~66.53 S 6200 21 30 5935.37 5830.37 $23eOOW 1499,89 S 6300 22 35 6028.06 5923.06 S2~.OOW 1534.31 $ 6400 22 15 6120.50 6015,50 $24.50W 1569.08 S 6500 21 15 6213.38 6i08,38 $25.00W 1602.73 S 6:600 21 25 6306,52 6201.52 $24,00~ 1635,85 6700 21 20 6399.6~ 6294.64 S25.00W 1669.03 6800 20 ~5 6492.97 6387.97 S26,00W 1701,44 S 6'90;0 20 45 6586,48 6481.48 S26.50W 1733.21 $ 7000 20 15 6680.15 6575.15 $28.00W 1764.35 S 7100 20 15 6773.96 6668.96 SSO.50W 1794.54 $ '~00 20 5 6867.83 6762.83 S33.00W 1823.86 $ JO 19 15 6962.00 6857,00 $35e50W 1851,68 $ 7400 17 15 7056.96 6951,96 $30,00~ 1878.01 7500 16 50 7152,57 70~7,57 $31,00W 1903,26 S 7600 17 15 7248.18 7143,18 531e50~ 1928,32 S 7700 18 5 7343.46 7238,~6 S31,50~ 1954,20 S 7800 18 55 7~38.28 7333,28 SSO,50W 1981,~2 S 7900 19 15 7532,78 ?427,78 $32,50W 2009,30 S 8000 20 15 7626.90 7521,90 $35,00~ 2037,39 S 8100 20 5'5 7720,51 7615,5! $36,50W 2065,93 S 8200 20 45 7813,97 7708,97 S37,00W '2094,k.4 S 19.77 W 27,10 W 35.36 W 54.19 W 75,52 W 87.79 W 101.~3 W I16e40 W 1)2~06 W 147e58 W 162.67 W 177.79 W 19).25 W 208.92 W 224,~5 W 260.01 W 278,95 W 295,88 W 310,76 W 325,97 W 341,83 W 358,I8 W ~75e26 W 435,87 W CLOSURES DISTANCE ANGLE D M S 1239.65 S 0 54 51 W 1272.1~ S 1 13 lA W 1304.88 S 1 33 I1 W 1337e66 S 1 54 29 W 1370,59 S 2 15 58 W 1~03,12 S 2 38 1 W 1435e72 S 3. 0 55 W 1469e16 S 3 25 33 W 1503,32 S 3 52 8 W 1538,72 S 4 20 18 W 1609.51 S 5 15 39 W 167'8,~7 $ 6 ~ 49 W 1712e38 S ~ 28 47 W 17~5.76 S 6 52 23 W 1778.63 $ 7 15 57 W 1810,77 S 7 40 33 W 18~2.~0 S 8 6 48 W 1872,58 S 8 34 1W 1901.17 S 8 57 12 W 1928,47 $ 9 16 24 W 1955,58 S 9 35 41W 1983888 S 9 55 18 W 2013.53 $ 10 14 48 W 20~,04 S 10 3~ ~4 W 207~e15 S 10 96 45 W 2107,12 $ 11 20 50 W 2139,.31S 11 ~5 21W DOG LEG SEVERITY DEG/IOOFT 0.2~+~ 0.256 0.~79 0,169 0.276 0.59~ 0.829 0.559 0.777 1.100 0.347 1.002 0.224 0,160 0.603 O* 17:7 0e531 0,865 0,336 0.883 2.058 0,419 0,412 0,840 O, 847 0,387 1.04~+ 0,706 0.191 SECTION DISTANCE 1135.58 1168.05 1201.09 1234,48 1268.14 1301.64 1406.36 1482,02 1519.08 1555,a7 1627.84 166~.25 1698,23 1732.72 1766.93 1800,11 1831,09 1889.36 1919.49 1983'50 2016.85 20~1.35 2085,13 RECORD Of SURVEY ALL CALCULATIONS PERFORMED BY I B H ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DXREC DEG, TOTAL COORDINATES 830-0 20 55 7907.43 7802,43 S37.00W 2122,85 R400 20 45 8000.88 7895.88 S38.SOW 2150,98 66 20 55 8062.57 7957,57 $~8.50W 2[69.36 .SO0 21 0 8094.32 7989.32 S39.00W 2[78.84 8600 20 50 8[87.72 8082.72 S41eSOW 2206e09 8700 20 45 8281,21 8176,21 8800 20 5 8374.92 8269.92 S46.50W 2257.36 8876 [9 45 8446e38 83'4'[.38 S48.00W 2274.93 8900 19 45 8468.97 8363e97 $49eSOW 2280,28 9000 20 45 8562,78 8457,78 S51.00W 2302,41 9100 21 25 8656.08 855[.08 552.50W 9200 22 0 8748e99 9300 23 5 8841,34 8736e34 $56,00W 2368,81 9400 23 15 8933.28 8828,28 $58,50W 2390,10 9500 22 45 9025,33 8920,33 S58,00W 24[0,66 9600 23 45 9117,21 9012.21 $59.OOW 2431.28 9700 24 40 9208.4[ 9[03e4[ $59.00W 2452.40 9800 25 15 9299.07 9194,07 S60eSOW 2473.66 ~00 26 5 9389,20 9284e20 $61.50W 249~,66 ~ O0 26 5 9479.0! 457,28 W ~79.06 W ~93,67 W 501.29 W 524.36 W 548,11 W 572~56 W 591.58 W 597,67 W 624,28 W 652.54 W 682, [9 W 71~e59 W 779,90 W 813.56 W 848,71 W 885,16 W 923.05 W 961,97 W 10100 25 30 9569.05 9464,05 $64,50W 2534,39 S 1001'00 W 10200 25 45 9659,21 95~4,2! SbSeOOW 2551,80 S 1040,57 W 10300 26 0 9749e18 9644,18 $68eSOW 2567e97 S 1081,11 W 10400 26 5 9839e03 9734.03 568,50W 2584e06 S 1121e96 W 10470 26 15 9901,85 9796e85 $68eOOW 2595e50 S 1150.64 W 10575 26 30 9995.92 9890,92 $68.50W 2612e79 S 119~,96 W CLOSURES DISTANCE ANGLE D M $ 2171e55 S 12 9 22 W 2203,68 S 12 33 21 W 2224,82 S 12 49 13 W 22~5.77 S 12 57 24 W 2267.5~ S 13 22 13 W 2298.78 S 13 47 39 W 2328,84 $ 14 13 57 W 2350,59 S 14 3~ 35 W 2357.~1S 14 ~1 14 W 2385,55 S 15 10 1~ W 2643e97 S 16 12 30 W 2473e96 S 16 45 52 W 2504,02 S 17 20 56 W 2533,68 S 17 55 39 W 2563,79 S 18 30 5 W 2595,11 S 19 5 21W 2627.27 $ 19 41 20 W 2659e96 S 20 18 18 W 2692e83 S 20 55 49 W 272~.91S 21 33 8 W 2755e81S 22 11 5 W 2786e27 S 22 49 51W 2817,12 S 23 28 11 W 2839,12 S 23 56 31W 2872e67 S 2~ 33 32 W DOG LEG SEVERITY DEG/iOOFT 0,180 0,260 0.273 0.279 0,355 0.154 0.811 0,501 2,112 1.018 0.709 0.608 1,133 0.421 0.506 1,013 0.920 0,641 0,862 0'660 0.652 0.706 0'268 0,090 0,268 0.256 SECTION DISTANCI 2120,87 2155,50 2178,29 2190.08 2224,46 2258.33 2291,12 2315.01 2322.41 2353,59 2385,60 2418,05 2451.11 2516.73 2549e48 2583,30 2617,78 2652,63 2687,43 2721,15 2785,00 2816.62 28}8,94 2872,67 BOT~TOM HOLE CLOSURE 2872.67 FEET AT S 24 33 32 W MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 205 205. 100 0 0 305 305. 200 0 0 405 405. 300 0 0 505 505. 400 0 0 605 605. 500 0 0 705 705. 600 0 0 805 805. 700 0 0 906 905, 800 0 0 1006 1005, 900 1 1 1106 1105, 1000 1 0 1206 1205. llO0 1 0 1307 1305. 1200 2 1 1407 1~05. 1300 2 0 1507 1505e 1400 2 0 1608 1605e 1500 3 1 1708 1705. 1600 2 -1 1808 1805, 1700 3 1 1909 1905, 1800 3 0 2009 2005. 1900 2110 2105. 2000 4 0 2211 2205. 2100 5 1 2312 2305. 2200 6 1 2413 2405. 2300 8 2 2515 2505. 2400 10 2 2618 2605. 2500 12 2 2721 2705, 2600 16 2826 2805, 2700 20 2932 2905. 2800 27 7 3041 3005, 2900 35 8 3150 3105, 3000 4.4 9 3259 3205, 3100 54 I0 3369 3305, 3200 6~ 10 3479 3405, 3300 74 10 3589 3505, 3400 83 9 3698 3605, 3500 93 10 0,28 0.34 0.44 0.62 0,83 3,76 10.27 17.64 25.15 32.72 40.~ ~8.19 55,69 63.51 71.78 80.08 88,45 97.38 106.86 117.73 130.32 I~5.0~ 162.00 181,56 230,51 297e60 339.29 383.23 427.64 472.97 518.66 563.52 608.06 0.44 W 0.79 W 1.06 W 1.64 W 2.15 W 3.12 W 2.37 W 1.83 W 1,48 W le18 W leO6 W 1,14 W 1.30 W 1.5I W 1,81W 2.17 W 1.98 W 0,31 W 2.26 E 4,70 E 7.15 E 10.07 E 13.24 E 15,89 E 17,97 E 20*I8 E 21e87 E 23.~2 E 25.20 E 26,90 E 28.21 E 28.51 E 28,87 E 29.23 E 29.41 E HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERT!CAL SUB MD-TVD VERT!CAL DEPTH DEPTH SEA DIFFERENCE CORRECT!ON TOTAL COORDINATES 3808 3705. 3600 103 3917 3805. 3700 112 9 4026 3905. 3800 121 9 4135 4005. 3900 130 9 ~244 4105. 4000 139 9 4352 4205. 4100 147 8 4569 4405. 4300 164 9 4676 4505. ~400 171 7 4784 4605e 4500 179 8 4891 4705. 4600 186 7 4997 4805. 4700 192 6 5104 4905. 4800 199 7 5211 5005. 4900 206 7 5317 5105. 5000 212 6 5423 5205, 5100 217 5 5529 5305. 5200 223 6 5635 5405. 5300 230 7 5741 5505. 5400 236 6 5848 5605. 5500 243 7 5954 5705. 5600 248 5 5060 5805. 5700 255 7 6167 5905. 5800 262 7 6275 6005. 5900 270 6383 6105. 6000 278 8 6491 6205, 610.0 286 8 5598 6305, 5200 293 7 6706 6405, 6300 301 8 6813 6505. 6400 308 7 6920 6605, 6500 315 7 7026 6705, 6600 321 6 7133 6805, 670:0 328 7 7239 6905. 6800 334 6 7345 70:05. 6900 340 6 7450 7105, 7000 345 5 652.65 697.05 740.74 784.22 827.34 869.05 909.70 950.97 990.73 1067,51 1104.67 1141,73 I177.64 1212.53 1246.83 1281,21 1315e81 1350.26 1384e96 1418 · 80 1~53.43 1488.85 1525.57 1563.26 1635e17 1670.92 t705e53 1739.49 1772.27 1804.37 1834.95 1863.72 1890.74 28.64 E 27.87 E 26.93 E 25.82 E 24.66 E 23.14 E 21e55 E 19.47 E 16,58 E 13,45 E 9e26 E ~.0~ E 1.49 W 7.55 W 14.10 W 21.35 W 29.31W 38.46 W 48.41W 58.98 W 70,14 W 82.54 W 96,66 W 112.54 W 129e29 W 146.05 W 162,37 W 178,67 W 195,25 W 212.01W 229.21W 247.65 W 267.32 W 287.03 W 303.31W NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH .SEA DIFFERENCE CORRECTION TOTAL ¢OORD/NATE$ 7555 7205. 7100 349 7660 7305. 7200 354 5 7765 7~05. 7300 359 5 7871 7505. 7400 365 6 7977 7605. 7500 371 ~083 7705. 7600 378 7 8190 7805. 7700 385 7 8297 7905. 7800 392 7 8404 8005e 7900 399 7 8511 8105. 8000 406 7 8618 8205e 8100 413 7 8725 8305, 8200 420 7 8832 8405, 8300 427 7 8938 8505. 8400 ~33 9045 8605, 8500 440 7 9153 8705. 8600 447 7 9261 8805, 8700 455 8 9369 8905. 8800 464 9 9478 9005e 8900 473 9 9587 9105, 90,00 481 8 9696 9Z05. 9100 491 10 9806 9305, 9200 501 9918 9405, 9300 513 12 10029 9505. 9400 524 11 10140 9605. 9500 534 10251 9705. 9600 545 10362 9805m 9700 557 12 10473 9905e 9800 568 1916.96 1943.68 1971,76 2001.20 2030.87 2061.11 2091.69 2121.99 2152.10 2181.90 2210.92 2238.98 2264,91 2288.72 2312.47 2336.45 2360.15 2383.71 2406,27 2~28,52 2451.54 2498.39 2520.86 2541.70 2560.10 2578.16 2596.00 318,99 W 335.19 W 352.24 W 369.93 W 389,35 W 410.90 W 433.61 W ~56,63 W 479.93 W 503.77 W 528.56 W 554.07 W 580.50 W 607,51 W 636.80 W 667.89 W 700.94 W 736.25 W 772,56 W 808,98 W 887.38 W 929.82 W 973,28 W 1016e5~ W 1061,11 W 1106.33 W 1151.87 W INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASUREB DEPTH. TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999. 894. 2000 1995. 1890. 3000 2967. 2862. 4000 3881, 3776. 5000 4807, 4702. 6000 5748. 5643, 7000 6680. 6575. 8000 7626. 7521, 9000 8562. 8457. 10000 9479. 9374~ 24.70 105.98 323.28 1105.73 1~3~.82 1764.42 2037,~8 2515.30 1.53 W 1,99 E 24.31 E 27.29 E 3.89 E 75.24 W 224,82 W 393.91 W 624.19 W 961.87 W HORIZONTAL VIEW SCALE I" = 500' AMOCO PRODUCTION CO. PLATFORM ANNA-WELL NO. 21 GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD 2400 '2800 3200 3600 ALL DEPTHS SHOWN ARE TVD 4O0O 4400 4800 52OO 6000 6800 7200 7600 f 8000 J- 8800 / ~ - 9800 I0,000 ! TVD = 9,996 TMD= 10,575' 4OO 800 1200 1600 -2000 2400 VERTICAL SECTION SCALE= I"= I000' AMOCO PRODUCTION CO. PLATFORM ANNA-WELL NO. 21 GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD 00 200 ALL DEPTHS SHOWN O0 ARE .T.V.D. O0 600 ~8400 TMD" 9,996' 10,575' Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent August. 30,. 1976 File: GJR- 662-WF Mr. Hoyle Hamilton, Acting Director Division of Oil and Gas' Department of Natural Resources State 'of Alaska 3001 Porcupine Drive Anchorage,' Alaska 99501 Dear Sir: Re: Monthly RePort of Drilling and WorkOver Operations Granite'Point 1874.2 .Well No. 21 We haveinadvertently overlooked sending you our P-4 forms for the 'month'of June. Please accept our apologies. Attached are the Forms P-4 summarizing the status of Granite Point 1~8.742 ,Well No. :21 'for the months' of June and July. YOurs ver'y truly, . George J. Ross Area Superintendent Attachments R,L'V, 3' 1-70 STATE Ot ~ASKA SUBMrT I~ DUPLICA'I~ OIL AND GAS C©NSERVATi©N CO/v~H-[EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS :. ,,~- or OPm~.~TOR Amoco Production COmpany il A]DDR~SS OF OPEP. ATOR P. O. Box 779, Anchorage, Alaska 99510 LOCATION OF Leg 3, Slot 6, Granite Point PlatfOrm Anna, 834' FNL, 676' .FEL, Sec~ 12, T10N; R12W, S.M. '~" .',}"I NU.VIEHICAL CODE 50-133-20291 LEASE DESIGNATION AND SEq{IAL NO ADL-18742 IF INDIA)4' ALOT/Lk OR TRIBE NAME B L'NIT FAIR~! (>Fi I,EASE NAME Granite Point State 18742 g wELL NO 21 ]o .~IELD A_ND POOL OR XVII.DCAT Granite Point Il SEC T R M (BOT'TOM HO1.E OrOECTIVE) Sec. 12, TiON, R12W, S.M. 12 Pi~,JVlIT NO 76-49 13,REPORT TOTAL DE]P'rH AT END OF MONT'H. CHANGES IN H('~LE SIZE. CA,glNG AND C~NTING JOBS INCIA~DING DEPTH SET A~ VOL~ USED PF.~OHATIONS, ~.STN ~ RESULTS FISHINrG JO~ JL~K ~ HOLE AND SIDE-TR.ACKED HOLE ~D ~Y O~R SIGN1FIC~T ~G~ IN HO~ CO~ITIONS Status as of July 31, 1976: July 1-3: July 4: July 5: TD 7350'. July 6-24: TD 10,575' July 25: TD 10,575' · Dipmeter. July 26-27: July 28-31: PBD 10,484', swabbing casing. ~TD 7271'. Directionally drill and survey 12-1/4" hole. TD 7343'. Trip in with Turbodrill and drill from 7271- 7343'. Trip out and lost one cone. Drill on junk. · Drill, trip and survey 12-1/4" hole. · Run Sonic log, DIL log, Density log and Rig up and run 9-5/8" casing. Run 240 joints of 47#, 43.5# and 40# casing. Land casing at 10,573'. PBD 10,484'- Swabbing casing. hereb that the for g and eo ~i~ ~,~_[_/~.A.~...7_.~ Area Superintendent August 30. 1976 NOTE --Report on thie form i~ required for each calendar ~nth& reqordle~t ~f the Itntus nf omeratlo~, and mu~t ~ flied In duDliCale ~ifh the otl and got eon~ervatlon commlflee bythe 15~ of the ~uec~ding menth,unle~ efh~rwl~e ~ir~cfed, STATE OF ALASKA S'vBMrr m' g~..n:,'~,cA~ OIL AND GAS CONSERVATION COMMII~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPEI:t.A. TOR Amoco Production Company 3. "'A]~DRESS OF P. O. Box 779, Anchorage, Alaska 99510 4 LOCATION OF WELL Leg 3, Slot 6, Granite Point Platform Anna, 834' FNL, 676' FEL, Sec~ 12, T10N, R12W, S.M. APl NUJ{ERICAL ~ODE 50-133-20291 ~; LF~.SE DESiGN'ATION AND SEIRIA'L NO ADL-18742 IF INDIAkT Ai~3% IE~ OB TRIBE NAME Granite Point State 18742 9 WELL .NO 21 I0 FIFJ~D A_ND POOl,, OR WILDC~%T Granite Point 1t SEC T, R, M ('BO'I"I'oM HO1.E Sec. 12, T10N, R12W, S.M. 12 P~qAqlT ~O 76-49 13. REPORT TOTAL DEPTH AT END OF MONS~. CHAJqGF-.S IN HOLE SIZE, CASING AND CID/IF. NTINGJOBS IN'CLITDING DEPTH SET ~ VOL~ USD P~ORATIONS. ~STS ~ ~5ULTS FISHING JO~ JI~K ~ HOLE AND SIDE-~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HOI~ CODITIONS Status as of June 30, 1976: TD 6476', drilling 12-1/4" hole. June 16: June 17-19: June 20-22: June 23-24: Spud Granite Point 18742 Well No'. 21. TD 3000'. Directionally drill 12-1/4" hole to 3000'. TD 3000'. Open 12-1/4" hole to 17-1/2" hole. Rig up and run 77 joints of 13-3/8", 68#, 61# and 54.5# casing. Land at 2979' and cement to surface. TD 3000', nipple up and test BOP's. Test rams, manifold and Hydril to 3000 psi. Test blind rams and casing to 1500 psi. Test witnessed and okayed by Russ Douglas, Alaska Division of Oil and Gas. June 25-30: TD 6476'. Directionally drill and survey 12-1/4" hole from 2979' to 6476'. ~":~:~~~~.~ Area Superintendent n~, August 30 1976 NOTE ~Report ~n thi~ form is required for e~ch collndar ~nth~ regordless ~f [~a status ~f o~,ratie~s, ond mu~t ~ filed In duplicote with the oil ond gas conlervotion commiHee by the 15~ of lha suoc~ing m~n~, ~le~ ~therwi~e d~r~ctad. G, J. Ross Area Superintendent July 22, 1976 File: GJR-578-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company f ~ Box f -ic. '/ Dear Sir: Re: Change of Plans Granite Point 18742 Well No. 21 Reference is to a telephone conversation of June 16, 1976 between your Mr. John Miller and Amoco's Gary Utrecht regarding proposed changes in the casing program for the above referenced well. We had requested and received verbal approval to set 13-3/8" casing at approximately 3000' TMD rather than 3500' as proposed by Form 10-401, approved June 11, 1976. The original casing depth was not necessary as we were able to complete our directional work shallower than originally planned. We have run 2979' of 68#, 61# and 54.5# K-55 casing in this well. Attached is Form 10-403 confirming this change. Yours very truly, George J. Ross Area Superintendent Attachment Form 10 - 403 REV. I - 10-W5 "Intentions" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I'TEE SUNDRY NOTIC'ES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR /~'ERI~IT-2-'' '/or such 'proposals.) · WELL' WELL OTHER 2. NAME OF OPERATOR Amoco Production Compan7 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4.LOCATION OF W~L Atsurface Leg 3, Slot 6, Granite Point Platform Anna, 834' FNL, 676' FEL, Section 12, T10N, R12W, S.M. __ 5. APl NUM-F-A~CAL CODE 50-133-20291 6, LE~S~, DI~iIGNATION A. ND SEItlAL NO. ADL-18742 7.' 'IF iNDIAI~, AiJ.~OTTEE OR TIt. IBE NA.I~tE 8. UNIT, FARM OIt LEASE NAME Granite Point State 18742 9. WI~LL NO. 21 10. FI_El. AD A,ND POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N~ R12W~ S.M..' 13. ELEVA'F!ONS (Show' whether DF, RT, OR, etc. 12. PERIVIIT NO. RDB 105' above MSL 76-49 t4. Check Appropriate I~x To Indicate Nature of NOtice, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE 8H00T OR ACIDIZ~ ABANDONS REPAIR WELL CHANOE PLANSI ~ Other) BU BSlllQU~NT R~P0~,T OF: WATER. SHUT-OF, REPAIRINO WlgLL FRACTt'RII TREATMENT ALTERINO CASINO 8HOOTING OR ACIDIZINO {, ] ABANDONMgHT· (Other) (NOT~: Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) 15. DERCRIBE I'ROPOS£D OR COMPLETED OPERATION8 (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an5' proposed work, Confirming telephone conversation on June 16, 1976 between your Mr. John Miller and Amoco's Gary Uttecht, Amoco hereby requests written approval to set 13-3/8" casing at 2979' TMD rather than 3500' as proposed by Form 10-401, approved June 11, 1976. The original casing depth was not necessary as we were able to com- plete our directional work shallower than originally planned. 16. I hereby ce_rti/y thst the fort~0~ is true and correct Area Superintendent (This.space for State ofllere: use) · See Instructions On Reverse Side July 22, 1976 02~1B of ALASKA DEPARTMENT OF .~-~ATUP~.L RESOURCES Division of Oil and Gas TO: F-- FROM: O. K. Gi!breth, Jr Director Thru- Hoyl e H. Hamil ton,~~':~ Acting DirectOr ~W' DATE June 25, 1976 Russell A. Douglass Petroleum Engineering Consultant SUBJECT: [~itness P, OPE test, Amoco Granite Point State #21 Tu~esday, June 22, 1976 - Traveled to 2~oco platfom~ "Anna" via Kenai 'a-nd-~i~h~hel]P~)rt. purpose of my trip was to Yzitness testing of the BOP equip~nt on Granite iPoint State well #21. Arrived on platform "Anna" at 4:15 PM and met with Billy Cole, Amoco drilling supervisor. He told me they were finishing their cement job and that they expected to be nippled up sometirr~ next morning. [~ednesday, ...June 23, !976 - Parker pusher came for me. about ~:00 AH. ['tent out to the floor to sta'r't testing the BOPE. The 13 3/~" casing was set at 2979" H.D. They were testing with water using the Haliburton pumps. Test plu~ ~as set and the first test was to be on the lower set of pipe rams. A leak was noticed i-n .the ring gasket directly below the lm-¢er pipe rams. To replace the gasket the entire stack had to be picked up causin~ som~ delay. When they reset the test plug it would not hold. Finally poured a sack of barite on tog," of the plug and resumed testinq., at 5-15 P"~,~.. Tested BOP stack to 3000 psi including valves on the spool to 3000 psi(:! with check valve disabled. Hydril tested t.o 2200 psig. Tested the choke i)~nifold to 3000 psig, replaced the check valve and tested to 3000 psig. Upper and lower kelly valve tested to 3000 psig. Tested the blind rams to !500 lbs. without the test. plug in tJhe hole. I discussed this with Bill Cole and accepted this as an aoe,uate test. The reasonine being if the pipe rams were closed and the pressure exceeded 1500 psig the casing or shoe would fail before tim blind rams would. i filled out a field inspection report and gave. it to ?~r. ~'' Cole. A cody, has been sent to Bill Halverson and a copy is attached. In summary, I witnessed a successful BOPE test on the ~,P., #21 ¥;ell on Am~,oco's ptatfon~'~ "Anna". Attachment A ~r l~ ~Oil and Gas Conservation C. ~ Fi'eld InspeCtion Report ..... RePresented bY" ~'o,~_ ~t, L s pecti onSa ti is'Fac tory Satisfactory '' Yes~, ( . 3', Reserve Pit'( ) )filled qatfm Number Type Inspe, ction )' oil (~ ' ) Lu. urilling spool~ "outlets (.) ( ) 21,'~Kill Li~e-(~)':'CheCk 'valve ~:~': (.), ( ) 5. Wells (.) () 6. Subsurface,No. Wells Test Data (~ ( ) 22. Choke Flowline (,-~-HCR 'valve ( ) ( ) , , , (~ ( ) 23. Choke Manifold No. valvslcTflas ..i.~ ( ) ( ) 8. Hrs. bser, ~~ -(~)~ '( ) 24. Chokes,(,q'Remote(~-~POs.(~-dj~' '~'~. ( ) ( )"9'~ B.S&w .~:~'-'~ ..,~, , ...... (~ .() .25'..Test PlugZ(.~ellhd('-'~'- )csa( ')nOne : ( ) ( ) lO. Gr, B~ -~, , 26'. Annular breventer,z..,~,,o,,ps~g ( ) Final' Abandonment 27. Bl J. nd Rams .~,~p'., sl'g.,~',~,,~ el 1 y & Ke ~',c~,c. o p~ i g Y quip. fa, (..).. ( ' 11. P&A Marker 1:2..Water well-( )Capped( )plugged (:) _ ~: · ." -" d k'." · · . ' ' '~' '; ' -~ ..... " ....> ~ ' ·, ' ~ cc'./~...:,~4....z~.:7.~,~,..~..~_~. Notl. fy In . days o.r..when :re. adv.. In,~n.~.r~a h,,.</ ,'... ~t?' . n~: ;,.. i...- .,.,.. ~.. . ' .. .,. '.. · - ~. .... ..' .... '.. ' :.. ~. '. .... '.'. ; .':.' .' ~..- ~ . ~.r"~ .... ~r'=..~2:...~,:,..~...,.,~b,,~..4~,....~ ~:.~.:-~,<~.;.: ~ ..' ~ .['?:/.;' ']':." ..' :'. ":' ' '.L .:. · :..'.'.',.;;..'. ":.. ' ~.' .T. "'?:~:?~z't':'",,' "." ,.'..":,:::..'..,,.':'....L...%..t' :.'. 7:,:..',...':.....-.':..L.:...?..~::'.'...... /....:.:.....,. ...'. "[; ..... .' · · . '. · .: . : '.. . ~] · · . .,...'. ~," :. · . .. ;.. '.'. Division of 0tl and Gas 3001 Porcupine Drive, Amchorage, Alaska 99501 June 11, 1976 Re: Granite Point State 18742 #21 Amoco Production Company State Pemit No. 76-49 George j. Ross Area Superintendent Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 12, Township lON, Range 12W, S.M. Well samples, core chips and a mud log are not required. A directional survey is required. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations, prolmulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. ~eorge J. Ross -2- June 11, 1976 In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~yle H. Hmil~n ~laska 0~1 and Enclosure cc: Depar~nt of Fish and Game, Habitat Section w/o encl. Depar~nt of Environmental Conservation w/o encl. Depar~nt of Labor, Supervisor, Labor Law Compliance Division w/o encl. 1976 Pile: GJR-410-WF ~. A. P. LoBrecht Mobil Oil Corporation P. O. Box $444 Terminal Annex Denver, Colorado 80217 Gentlemen: Signature of A~proval to.Drill Granite Point State 18742 Well No. 21I- Amoco Production Company P. O. Box 779 ~ Anchorage, Alaska 995101~dl Attached is a copy of the application to drill Granite Point 18742 Well No. 21. This well will be directionally drilled from Leg 3, Slot 6 of Platform Aa%ha to a bottom hole location 1900' FSL, 1575' FEL, Sec. 12 T10N, ~13W, S.M. ' 'We are' requesting that you furnish non-operator approval of the subject drilling application. Please signify your approval to drilling of the subject well by signtmg below and forwarding two copies to this office. Very truly yours, Orighnal Signed by ~! ..... BGE J. ROSS George J. Ross Area Superintendent Approve of drilling Granite Point State 18742 ~eil ;~;o. 21 as described above. MOBIL OIL COMPANY By: Date: cc: }ir. O. K. Gilbreth, Director Division of Oil and Cas Department of Natural Resources DIV~StON OF ~,. &ND Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent May 1!, 1976 File: G JR- 399=WF Mr. O' K. Gi!breth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Reference is to Mr. Gilbreth's letter dated May 10, 1976, regarding our failure to send the application for permit to drill Granite Point State 18742 Well #21 in triplicate. Attached you will find the original and one copy of the subject application. We thank you for drawing this to our attention, and apologize for any in. convenience we have caused you. Yours very truly,, George J. Ross Area Superintendent At t achment s SCALE: T Ol',I i2 13 II 7 LEG. NO I LEG. NO. 2 LEG. NO. 3 LEG. k'O. 4 LAT. 60055'3756'' LAT. 60°58'3S9~'' tAT 60~58'2553'' tAT 60~58'37 12" LO;4G.151°18'46.OO'' LONG 151°18'45 28" tO%O.151°IS'46 82" LONG 151° ~8'~7 48" Y : ~,551,4~3 Y: 2,55~,352 Y : ~.55~.310 Y: ~.551,37I X = 266,816 X: 266.850 .X : 256,774 X : 2(6.742 FROM NJ. 2au., rROV NJ. COq =OM NE. CO~. FgC',' '*E CO~ 729' SOUTH ~ 790' SOUTH 5 824' SOUTH 8 714' SOUTH 6~6' ~'[ST 600' WES'T 676' ~[Sr 709' ,. CERTIFICATE OF SURVEYOR I hereby certify thai I om properly registered and licensed to practice land surveying in the Slate of A!osko and that this plat represents o locution survey mode by me or under my supervision and that oll dimensions or'd other doloils ore correct. Date FINAL PLAT OF ,-¢,' ,I' \/ % ,' / ~4;~"~ ¢., ~!':~ ;':.i ~ ~.. · ., __ ~. ~&-~ ......... SURVEY£D FCR N O I'E The locolion of platform legs ,','.os occompl shed Iriongu:lclion stations Dud, Trin fy, and Tyonek P'AN AMERIC^N PETROL.FUM CONr: PO BOx: 779 A~ICHORAGE, ;,LASKA .............. · s,b h-¥~.'~,'S o ' L/;' ................... F{ M LINDSEY C~ ASSOC LAhlD SURVEYORS ~ CIVIL E~(;I:JEER5 320~ ARCTIC ~,LVD AN C. klOf~hO[~, ALAS<,', ............. Amoco Pr(,duction Comp".'~'?/ ,:, -. ENGINEERING CHART FILE APPN DATE: ENGINEERING CHART II LEG. NO I LEG. NO. 2 LEG. NO. 3 SCALE: LEG. NO. 4 LAT. 60058'37.56'' LAT. 60058'3595" tAT 60m58']553'' LAT 60~56'37 12" L0;,1(~.151°18' 4G,O0'' LO~1G 151°18'45 28" LONG. I51°IG'4G 82" LONG 15~© 18'47 ~8" Y : 2,55~,413 Y: 2,55~,352 Y : 2,55~,310 Y: ~,551,371 X ': 266,916 X : 266,~50 ' ,~ : 256,774 X : 2EG,742 ~ROM N5. 20~. ~gOg NE. COg ;=O~J NS. CO~. FRO',' '~E CO~ 7~9' SOUTH ~ 7901 SOUTH 5 824' SOUTH ~ 774' SOUTH ~ 636' WEST 600' WESiT 676' ~[ST 709' WEST ,. CERTIFICATE OF SURVEYOR I hereby certify thai t om properly registered and licensed fo practice land surveying in the State of A!osko and that this plol repres6nts o location survey made by me or under my supervision and th,"]I oll dimensions ord olher deloils are correcl. . Date Surveyor NOTE , The location of platform legs /,,as occomolished b.~ us~n9 triangu;Iclion stations Dud, Trinity, and Tyonek'Offsel. ....... - FINAL PL¢,T OF' ;;~?oN%k PLATFORM "A" SURVEYED FCR PO BOX 779 AHCttO¢?AGE, ;,LbSKA F{ M. LINDSEY S ASSOC. LAND SUi~V E YOF~S $20~ ARCTIC BLVD ANCHORAOE, AL.A~EA FILE APPN DATE ElY :" "I P' ,pi; '", t SUBJECT . ..~ 'fA ENGINEERING CHART / I~tF_.L L ~--,o.q.o" /Cfp~..ft~ F3....(.._c' ~c.. ~.~lvislon of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 3~r. George J, '~-~oss Area guperintend, ent ~%oco Production Company P. O. Box 779 Anchoraget Alaska 99510 ~e have rece~ve~ your apDIx~atlon for permit to drill but received .only one copy. An original and one other copy is neede~ as ~h~s ~ust be submitted in tr~li~a~.~ Yours truly Director Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent May 6, 1976 File: GJR-390-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Re: Application for Permit to Drill Granite Point State 18742 Well No. 21 Attached is an application to drill the aboVereferenced well. We plan to directionally drill Well No. 21 from Leg'3,' Slot 6 of Platform Anna, to a bottom hole location of 1900' FSL, 1575' FEL, Sec. 12, T10N, R12W, S.M. This well is reqUired to drain trapped reserves inthe Granite Point field. Also attached are BOP specifications, a plat showing the legal description of the platfOrm !egs and the bottom hole location, and our draft for the $100 filing fee. Very truly yours, George J. Ross Area Superintendent Attachments D'~¥'IS!ON OP OIL AND GAS l~rm 10-- 401 REV. I-I-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SLtiBMIT IN TRIP (Other mstructior. reverse side) PERMIT TO DRILL OR DEEPEN DEEPEN r-1 IB. ?YPI~ OJ' WOlIK DRILL [] b. TYPI~ OF W~LL OIL ~---] 0~,8 ~] 8{NOL{ ~ MI'I,TIPI,J ~ 2. NAME OF OP~TOR ~oco Production Company P O. Box 779, Anchorage, Alaska 99510 4.~OCATION O~ W~ ~f~ Leg 3, Slot 6, GranSte Point Platfom Anna, 83~~ F~L, 676~ FEL, Sec. 12, T10~, R12~, S.~. At pro~ed prod. zone 1900~ FSL, 1575~ FEL, Sec. 12, T10~, R12~, S.~. at 9~80~ T~ API # 50-133-20291 6. LJ~ASE DI~IGNATION ~ S~.L~LL, NO. ADL-18742 7. IF INDIAN, AI.~'l-i-{~ OR TRL~E 8. UNIT FARM OR LEASE NAME Granite Point State 18742 9. WELL NO. 21 10. F'IELD AND POOL. OR WILDCAT Granite Point 11. SEC., T., R.. M., f BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R12W, S.M. 13. DISTANCE IN MILES AND DIRECT[ON ROM NEAREST TOWN OR POST OFFICE* 7-1/2 miles southwest of Tyonek, Alaska 12. 14. BOND INFORMATION: Blanket bond in force TYPE Surety and/or No. DISTANCE FROM PROPOSED* LOCATION TO NEAREST 1900 FSL of PROPERTY OR LEASE LINE, (Also tO nearest drig. unit. if any) ADL 18742 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1231' NE of G.P. 18742 Well #9 21. ELEVATIONS (Show Whethcr DF, RT, CH, etc. RDB 105" above MSL ']16. NO. OF ACRES IN LEASE 5060 lg. PROPOSED DEPTH 10,500 ~-,o~t$100~000 17. NO. ACRES ASSIGNED TO THiS WELL 8O 20. ROTARY OR CABLE TOOLS Rotary APPROX. DATE WORK WILL START* May 15, 1976 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER rOOT GRADE SETTING DEPTH quantity of cement 26" 20" "94# ~-40 610' 1285 sx (previously set) 17-1/2" 13-3/8'" 61# & 68# K-55 3500' TMD Cement to surface 12-1/4" 9-5/8" 43.5#~ 40# S-95 & 10500 TMD min. 500' above top of pay' N-80 , Plat and BOP specifications are attached. Operator proposes to directionally drill well from existing 20" casing in Leg 3, Slot 6, Platform Anna. There are no affected operators. Invervals of interest will be perforated and may be stimulated following IN ABOV~ SPAC1g D]~CI~IBE P'ROPOSED PROGRAM: If ~1 Is to dee~n ~tve ~ on present p~u~lve tone ve~ieal dept. Give blo~ul preventer p~ram. ~.I hereb~ify that the Foregone ~ Corre~ (This space for S~te ~lee u~) CONDITIONS 01~ APPROVAL, IF AN'Y: SAMPLES AND CORE CHIPS R.EQULRJ:O { M'U'D LO'O OTH]~ KEQUIREMI~ITS: []~ ~No J mY~ ~o DI~ION~ SURVEY R~~ ~ Y~ ~ NO ~ NO 76-49 , ~ov~ .~o~ ~v --~' *~ In--on, ~ Rev,~ Side jA.P.I. NUMERICAL CODI~ 50-133-20291 June ll, 1976 June ll, 1976 CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks 1.Is ~the permit fee attached Lease & Well No 2. Is well to be located in'a defined pool .............. ~/,~/c' 3. Is a registered survey plat attached ................. 4, Is well located proper distance from property line . . .· ...... ~ 5. Is well located proper distance from other wells .......... ~ 6. Is ·sufficient undedicated acreage available in this pool ...... ~ ?~d,.~.~Is well to be deviated ....................... ~. Is operator the only affected party ................ Can permit be approved before ten-day wait ....... ' O. Does operator have a bond in force ................. _/~d~ 1. Is a conservation order needed ................... 2. Is admi·nistrative approval.needed ................. 13, Is conductor string provided ......... · ........... I~. Is enough cement used to circulate on conductor and surface . . 15. Will cement tie in surface and intermediate or production strings 16. ill cement cover all known productive horizons .......... l~. Will ·surface Casing protect fresh water zones ........... ~8. Will all casing give adequate safety in collapse, tension & burst ~9. Does BOPE have sufficient pressure rating ........ - ..... ~dditional Requirements' Approval Recommended' Geoloqy Enaineering- TRM ~ HWK OK~ JAL LCS Revised 1/15/75