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Home My WebLink About192-119MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-51 DUCK IS UNIT MPI 1-51 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 1-51 50-029-22304-00-00 192-119-0 W SPT 9621 1921190 2405 2203 2199 2240 2232 38 38 38 38 4YRTST P Bob Noble 5/16/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 1-51 Inspection Date: Tubing OA Packer Depth 790 2697 2683 2682IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250516160658 MITOP000011025 BBL Pumped:2.8 BBL Returned:2.8 Thursday, July 24, 2025 Page 1 of 1           State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: ��.tp iCo7P MPr- Date: to`34'Z.1 PTD: r� 3d S("o I- S/zi 9z-1i,7-d operator, --- i-e-.�Cy ��{ 4A t.LC- ra7YPe Inspection: I�-r Operator Rep: A_rV►t5 14ej150^j Inspector RlA•i i � Position: CP6ZATd9 Op. Phone: ffd_?_ 4 q _ r 0 18D Correct by (date): /Z.'?(-) Op_ Email: -T-i<C."Lt,50, j a ov cowep. C.0", Follow Up Req'd: a Detailed Description of Deficiencies Date Corrected MI)z i-is XM rWP.r- ! 51 -51 ou.Zo tiE6a N0j &4M W b6 s r�-,.j s �srA�� ❑ / 5 f��. z� � IAK& ac = ORds of ^X ► SM-1.5 f�e-� Attachments:I P"4uZ e5 C7C operator Rep AOGCC inspector •After signing, a copy of this form is to be left with the P tryructions Return tion: Inspection Supervisor] within 7 days of receipt. Include the "[]ate a CM of this Deficiency Report to AOGCC (Atten and attach supporting documentation for each corrective action implemented to address the deficiencies_ If a follow-up ,� P� by AOGCC, include the date and Warne of Inspector. Extensions for corrective actions taking (anger than :the ■pwr� Syr' date must be requested and accompanied by justification [Attention: Inspection Supervisor). Documentation of � t are outside of AOGCC regulatory judsdiction will he forwarded to the appropriate authority for follow-up aet'son. I u..,vmiiml Nd H ilcorn Alaska, u DIU 1-51 (PTD 1921190) JBR; 12-23-2021 Missing well sign MEMORANDUM TO: Jim Regg P.J. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests thkorp Alaska, LLC 1-51 DUCK IS UNIT MPI 1-51 See: Inspector Reviewed By: P.I. Sup" Jw - Comm Well Name DUCK IS UNIT MPI I-51 API Well Number 50-029-22304-00.00 Inspector Name: Bob Noble Permit Number: 192-119-0 Inspection Date: 5/27/2021 . Insp Num: mitRCN210527134034 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-s1 Typelnj µ TVD 9621 Tubing 2500 - 2500 2500 2500 - PTD 1921190 Type Test SPT Test psi 2405 - IA 1081 2670 - 2663 - 2661 - BBL Pumped: 122 - IBBL Returned: 2 OA 0 0 0 0 Interval 4YRTST - P/F P Notes: Tuesday, June 8, 2021 Page 10i I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r7 e,O 4,' DATE: Tuesday,June 20,2017 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 1-51 FROM: Jeff Jones DUCK IS UNIT MPI 1-51 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry`J — NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-51API Well Number 50-029-22304-00-00 Inspector Name: Jeff Jones Permit Number: 192-119-0 Inspection Date: 5/28/2017 Insp Num: mitJJ170618120058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1.51 Type Inj W' TVD 9621 - Tubing 2402 • 2397 ' 2394 " 2282 PTD 1921190 -Type Test SPT Test psi 2405 - IA 964 2648 - 2635 - 2628 " BBL Pumped: 1.5 BBL Returned: 1.8 - OA 80 80 ' 80 - 80 • Interval 4YRTST P/F P Notes: Flow meter not functioning;used tank strap method for BBLS pumped&returned. 1 well inspected,no exceptions noted. SCO NED AUG 3 0 2011. Tuesday,June 20,2017 Page 1 of 1 • • Post Office Box 244027 Anchorage,AK 99524-4027 J U i Hilcorp Alaska,LLC L 3 0 LO I h 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 SCANNE Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 � - 1 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp . Orig • New API_WeIINo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 ;50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 / 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/1(16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 11890340 DUCK IS UNIT MPI 2-22/L14 2-22 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /qO~ -//~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED · [] Logs .of various kinds . [] Other COMMENTS: Scanned by: Beverly Diann~athan Lowell , . _,. 1__ , TO RE'SCAN Notes:. Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. '" m Attn: Well Integrity Coordinator, PRB -20 : L Post Office Box 196612 Anchorage, Alaska 99519 -6612 • 1 � ', U:.3. May 22, 2012 10(g—• / 19 Mr. Jim Regg 1�12/ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, r 2 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD 4 API 4 cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 , 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 /0-15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 , 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 /0 -23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 1 P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 4 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0 -20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 MEMORANDUM TO~ Jim Regg P.I. Supervisor ~L ~'I ~ ((.~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-51/V20 DUCK IS UNIT MPI 1-51/V20 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: DUCK IS UNIT MPI 1-51/V20 Insp Num: mitLG090612113126 Rel Insp Num: API Well Number: 50-029-22304-00-00 Permit Number: 192-119-0 ~ Inspector Name: Lou Grimaldi Inspection Date: 6/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-sl/v2o Type Inj. W TVD 9620 ~ IA 445 2525 ~ 2500 2500 P.T.D 1921190 TypeTest SPT Test psi zoos ~ OA so so ~o ~o Interval a~TST P/F P ~ Tabing 2a~o 2a~o za~o za~o NOtes' Pretest conditions observed for 30 minutes "OK". 3 bbls pumped 2.8 returned. Good test. yy yy $~q .- •~r~ Monday, June 15, 2009 Page 1 of 1 RE: Endicott 1-51 (PTD 192-119) e e Subject: RE: Endicott I-51 (PTD 192-119) From: "NSU, ADW Well rntegrity Engineer" <NSUADWWc1l1ntcgrltyEngincercq}BP.com> ,~atc: Mon, 03 Oc~?005 23:?1 :03, -0800 \ôlt..~loc;' I 0: Jam~s Regg <Jm,lJegg~~~dnll.n.s~ate.ak.us> . ~fl.. . CC: "NSlJ, ADW Well Integnty Engmeer" <NSUADWWcllfntegn[yEngmecr(q?BP.com> Hi Jim, Here is the TIO plot you requested for ENDl-51. Please let me know if you have any questions. Thanks, Anna -----Original Message----- From: J ame s Regg [!:t:!~_g_t9..:i~fi.:l_~~.99~~..0~in:_'?!:9: t e '_~_~_:_L.1_§'] Sent: Friday, September 16, 2005 10:09 AM To: NSU, ADW Well Integrity Engineer Subject: Endicott 1-51 (PTD 192-119) I'd like to have some details about Endicott 1-51 (water injector). Inspector was out there for MIT on 13th; from what is in his report, I'm not convinced the MIT is a pass (eventhough that was his recommendation) since it really did not indicate stabilization (1 hour test) . Please provide TIO plot for the well - at least 3 months. Jim Regg AOGCC TIO Content-Description: ENDl-51 no Plot.ZIP Content-Type: applicationlx -zip-compressed Content-Encoding: base64 ~NED DEC 1. Ö ZGU5 1 of 1 10/25/2005 2:31 PM e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg K,o, 1/1;)/) P.I. Supervisor 1 ~1 'Cr (.i DATE: Friday, September 16, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-51IV20 DUCK IS UNITMPI 1-51IV20 8rc: Inspector FROM: John Spaulding Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: DUCK IS UNIT MPI 1-51N20 API Well Number 50-029-22304-00-00 Inspector Name: John Spaulding Insp Num: mitlS050916065539 Permit Number: 192-119-0 Inspection Date: 9/13/2005 Rei Insp N um Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-51IV20 ¡Type Inj. I 1 iTVD I 9620 i IA j 140 i 2620 2600 ¡ 2580 i I P.T. I 1921I90 iTypeTest I SPT j Test psi I 2405 lOA I 50 ¡ 50 50 I 50 I Interval 4YRTST P/F P Tubing I 1950 I 1950 I 1950 I 1900 ¡ Notes The well was shut in to lower injection pressures tTom 2460psi. The test was run for an hour as the 1st 1/2 hour did not indicate stabilization as tubing psi was decreasing. The second 1/2 hour showed somewhat better number but the tubing was still decreasing with IA tracking nearly the same. L(tt.,-t{r .J:.Ú refer ~tANNEl (. ~ 2Q05 Friday, September 16, 2005 Page I of I Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott 03/18/03 Color Well Job # Log Description Date Blueline Prints CD A-20 I ~c4/. <=~ 'O/,.~ GLS 03105103 1 PWDW2-1 ] "7 (~-(~t~ ,'~ LDL 02/07/03 1 V-03 ,~:':'~-,c':~ I ~ - STATIC SURVEY/TEMP/PRESS 03103/03 '1 1-51N-20 I q~- 1)C~ INJECTION PROFILE 03/07103 1 R-14A c~'~'~- i~(~ 23086 LDWG EDIT ARC RESISTIVITY DATA 1'1111102 1 R-'14A ' 23086 MD VISION RESISTIVITY t1111/02 1 R-'14A 23086 TVD VISION RESISTIVITY 11/11/02 1 R-14A ..,/ 23086 MD VISION RESISTIVITY (BHP) 11/11/02 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~._~_ ~ r-~ ~ ~*~ j~'~ ~") Date Delivered: SOAII I E :; SEP 5 2003 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive_ J MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie HeUsser ~'\,,~,~' DATE: May 28, 2001 Commissioner I~ ~v~~UBJECT: Mechanical IntegrityTests THRU: Tom Maunder BPX P.I. Supervisor MPI (¢[~-O \ Duck Island Unit FROM: Jeff Jones Endicott Field Petroleum Inspector Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2-70 I Typelnj.[ S [ T.V.D. I 9200 I Tubing I 2600 I 2600 i 2700 I 2700 I lntervall 4 P'T'D'I 188-153 ITypetestl P ITestpsi[ 2300 I'Casingl 1675I 2550I 2540 Notes: Pre-test pressures monitored for 30 min. & observed to be stable. w,e,,I 2-22 I Type,nj.I N I T.V.D. 19460 I Tubing I 1400 12750 I 2550 I 2525 J lnterval! 4 P.T.D.I 189-034 ITypetestl P ITestpsil 2365 ICasingI 1240I 2630I 2450 Notes: Well has known communication between casing & IA. OA pressure increased 660 psi during MIT. WellI 1-51 I Typelnj. I S I T.V.D. I 8785 I Tubing I 2650 ] 2675 ! 2650 I 2650 I lntervall 4' P.T.D.I 192-119 ITypetestl P ITestpsil 2196 ICasingI 1120'I 2550I 2540I 2535I P/FI_Pi Notes: Pre-test pressures monitored for 30 min. & observed to be stable. We,,I 1-43 Type,nj.I S I T:V.D.I 9540 ITubing)2500 I 2400 I 2450 I 245O J'nterva'I 4 P.T.D.I 188-105 Type testJ P I Testpsil 2385 I CasingI 600 I 2525 I 2440 I 2375 I P/F NoteS: Pre-test pressures monitored for 30 min. & observed to be stable, i I I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday, May 28, 2001: I traveled to BPX's Duck Island Unit Main Production Island to witness 4 year MIT's on wells 2- 70, 2-22, 1-51 and 1-43. Mark Sauve was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable and then 4 MIT's were performed with one failure witnessed. Well 2-22 has a known communication between the tubing and the inner annulus and a tubing tail plug had been installed for the test. I noted that over the 30 minute test on well 2-22 the tubing and IA pressures equalized and tracked closely and the OA pressure increased from 0 psi to 660 psi and did not stabilize. Summary: I witnessed 3 successfUl MIT's and well 2-22 failed it's MIT at BPX's DIU MPI Endicott Field. M.I.T.'s performed: _4 Number of Failures: 1_ Total Time during tests: 3 hrs. Attachments: cc: MIT BPX DIU MPI 5-28-01 JJ 6/9/01 STATE OF ALASKA ALAS'-~-~- OIL AND GAS CONSERVATION COMMISSI~'¢' REPORT L..: SUNDRY WELL OPL..ATIONS 1 Operations performed' Operation shutdown m Stimulate m Plugging__ Pull tubing ~ Alter casing Repair well Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 2180' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratlgraphic Service .. 6. Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-51/V-20 At top of productive interval 2366' SNL, 4162' WEL, Sec. 1, T11N, R16E At effective depth 2746' SNL, 4308' WEL, Sec. 1, T11N, R16E At total depth 2762' SNL, 4312' WEL, Sec. 1, TIIN, R16E 9. Permit number/approval number 92-119 (See attached letter) 10. APl number 50- 029-22304 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12763' feet 10332'BKB feet 12741' feet 10316'BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 76' 2738' 103/4" 1193 c.f. Permafrost 2777' 2720' 12098' 75/8" 2336 c.f. Class "G' 12137' 9818' measured 890' 51/2" 201 c.f. Class "G" 11860'-12750' 9619'-10244' 12586'-12610', 12248'-12278', 12346'-12354', 12362'-12366', 12376'~12410', 12414'-12446', 12536'- 12558'; 12682'- 12699' true vertical (Subsea) 10135'-10152', 9898'-9920', 9969'-9974', 9980'-9983', 9990'-10014', 10017'-10039', 10101'-10117'; 10200'-10211' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft. NTo80S, TDS tubing with 4 1/2" tailp/pe to 11859' Packers and SSSV (type and measured depth) 7 5/8" TIW HBBP Packer set at 11788'; 4 1/2" SSSV set ~¢~1~.0! 13. Stimulation or cement squeeze summary Intervals treated (measured) ..~$ d'(_!; 1 ~'i !~i7 Treatment description including volumes used and final pressure !'~':0iJ .~%~ ([i;.!S ~,'~0i!S, l[;0~i'~li'ii.~; 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1514 1505 Tubing Pressure 1710 1741 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations X Oil__ Gas__ Suspended 7. ~ certify.that t~e~ f~re,going i~ tr~e and correct to the best of my knowledge. : ig ~ Title Reninr T~_chnica1,4.~.~i~tant IV Form 10-4~1~ev-0~/1~;/~8 ' -- -- l Service W~tp_r In/p_ctnr Date 7/16/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 6/22/97 WELL N°: 1-51N-20 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT Lovelace HB&R TIME OPERATIONS SUMMARY 1424 RIG UP HB&R AND P-TEST LINES TO 3500 PSIG SIP=1700 IA=480 OA=150 1426 BEGIN PUMPING METHANOL AT .5 BPM 1431 12 BBLS AWAY. IA = 2590 SIP = 1700 OA = 0. MONITOR. 1437 IA=2560 SIP=1700 OA=0. GOOD TEST. 1453 IA BLED DOWN TO 250 PSIG. RIG DOWN HB&R. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 5, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. B. Wondzell Dear Mr. Wondzell Attached, please find three Reportsof Sundry Well Operations for Endicott Wells 1-41/O-23, 2-70/U-15 and 1-51/V-20 (in duplicate). These three wells are water injection wells that have had perforations added, without prior approval. We apologize for this mishap, due to a change in personnel within the Endicott group. Please feel free to contact myself at 564-5734 if you require further information. Sincerely,,,~. J~u/tie A. MTIler Endicott Development attachments (3) JAM cc: File 06.10 STATE OF ALASKA ALAbr,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate m Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 2180' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-51/V-20 At top of productive interval 2366' SNL, 4162' WEL, Sec. 1, T11N, R16E At effective depth 2746' SNL, 4308' WEL, Sec. 1, T11N, R16E At total depth 2762' SNL, 4312' WEL, Sec. 1, TIIN, R16E ORIGINAL 9. Permit number/approval number 92-119 (See attached letter) 10. APl number 50- 029-22304 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 12763' feet Plugs (measured) 10332'BKB feet 12741' feet Junk (measured) 10316'BKB feet Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 76' 2738' 103/4" · 1193 c.f. Permafrost 2777' 2720' 12098' 75/8" 2336 c.f. Class "G" 12137' 9818' measured 890' 51/2" 201 c.L Class "G" 11860~12750' 9619~10244' 12586~12610~ 12248L12278~ 12346'-12354~ 12362L12366~ 12376'-12410~ 12414'-12446~ ~ 12536~12558~ 12682~12699' true vertical (Subsea) 10135~10152~ 9898'-9920~ 9969~9974~ 9980'-9983~ 9990~10014~ 10017'-10039~ 10101~10117~ 10200~10211' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft. NT-80S, TDS tubing with 4 1/2" tailpipe to 11859' Packers and SSSV (type and measured depth) 7 5/8" TIW HBBP Packer set at 11788'; 4 1/2" SSSV set at 1480' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Aia:;i.'.;". ~.' Prior to well operation Subsequent to operation Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 2816 3172 '~'i~i ~;~" F;l:bssu re 2o56 2012 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas Suspended Service Water Injector 17. I hereby certify thct the foregoing i~t~e and correct to the best of my knowledge. S~ned .¢~-¢~.--.~.'~_~ (.L--' ¢ - ~¢~.<-*- ~ Title Senior Technical Assistant II Date 9/5/96 Form 10-404.~J:~ev 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department Additional Perforations DATE: 4~25~96 WELL N-°: 1-51/V-20 BP EXPLORATION REP: VARBLE SERVICE COMPANY: ATLAS (RICHARDS, DAHL) DATE/TIME OPERATIONS SUMMARY 1430 MIRU ATLAS 1550 RIH WITH PFC/20' GUN (TOP 3' OF GUN NOT LOADED) 1700 ON BTM. LOG UP & TIE INTO CNL/GR DATED 4/22/93. ADD 23'. TD IS @ 12705' MD 1736 MARK DRUM & LOG UP FROM 12696'- 12635' MD ADD .5' 1740 ON DEPTH. LOG INTO PLACE & HANG CCL @ 12676.5 (5' FROM CCL TO TOP SHOT) 1745 SHOOT GUN FROM 12681.5'- 12698.5' MD. GOOD CAP BREAK & PRESSURE LOSS. LOG OFF 1750 POOH 1835 OOH 1850 ALL SHOTS FIRED 2000 RDMO POI TO FOC PERFORATION SUMMARY: GUN INTERVAL(CNL/GR) FEET SUBZONE 12681.5'-12698.5' ] 17 3B1 ALL INTERVALS WERE SHOT USING 3 3/8 ALPHA JET GUNS @ 6 SPF 60 DEG. PHASING & RANDOM ORIENTATION. ORIGINAL PROGRAM CALLED FOR ZONE TO BE SHOT FROM 12,680' - 12,700' MD. DUE TO LIMITED RAT HOLE & THE POSSIBLITY. OF NOT ENOUGH RAT HOLE, IT WAS DECIDE TO SHOOT A 17' GUN. TURNS OUT THERE WAS ENOUGH ROOM TO SHOOT 20'. SPLIT THE DIFFERENCE & SHOT FROM 12681.5' - 12698.5' MD. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-29/J-32 ~-/i'~ 1-51/V-20 (MPI) ql-i({ DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run ~ i 5933.06 Run # 1 5937.10 Received by: Please sign and return to: Attn. Rodney D. Paulson -- Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, ~K 99518 Or~) 563-7803 Date: 1996 ~aska 0]1 & 6as Cans, .~chomge LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. DaSe: 7 ~4ay 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF Fi}:AL BL+RF L--Run ~ I PFC/PERF FINAL BL+RF C-~Run # ! PFC/PERF FINAL BL+RF JRun # 1 PLS FINAL BL+RF Run # ! ECC No. 5725.06 5937.09 6355.07 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: Anchorage, AK 99518 (907) 563-7803 . '- , ,DaZe: ...... ~.,~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE , ANCHORAGE AK, 99501. Date: 25 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PLS FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FNL BL+RF PFC/PERF FINAL BL+RF PLS/STP FINAL BL+RF ECC No. Run # 1 5937.08 Run # 1 6397.05 Run # 1 6397.06 Run # 1 Run # 1 6397.07 Run # 1 6412.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and Petrotechnical Data Cente~ BP Exploration (Alaska) In~ 900 Ea,~t Benson Boulevard ~'~ ~o~ b~ ' - .... ''~~' PERMIT DATA 92-119 5714 92-119 CBL 92-119 CBL 92-119 CNL/GR/CCL 92-119 DIL/SFL/GR 92-119 DLL/MSFL 92-119 PFC/CCL 92-119 PFC/CCL 92-119 PFC/CCL(PERF) 92-119 PFC/GR 92-119 PLS(INJS) 92-119 PROD Are dry ditch samples Was the well cored? AOGCC Individual Well Geological Materials Inventory T DATA_PLUS C~RRUN 1 (J~"Rl,10000-12721 ~A/Rl,l1900-12694 ~'R1,10000-12721 ~ R1,11200-12740 L OH ~ ~_~ L-L 12350-12600 C/~ 12350-12600 L3~'"5",12400-12681 ~L R1,11300-12691 ~/~2100-12650 vZ 3600-12700 Are well tests required? yes ~Received? Well is in compliance ~ Initial COMMENTS required? yes ~.And received? yes no Analysis & description received? Page' Date' 04/04/95 RUN DATE_RECVD 07/26/1993 05/20/1993 05/20/1993 05/20/1993 05/20/1993 03/25/1993 06/11/1993 06/11/1993 11/12/1993 05/20/1993 01/18/1994 09/20/1993 no yes no STATE OF ALASKA ,-,,_,~oKA OIL AND GAS CONSERVATION COMM~.. _ ~1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X ~L./ ~-' ~. ~ . Other X 6. Datum elevation (DF or KB) KBE = 55 3 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 2366' SNL, 4162' WEL, Sec. 1, T11N, R16E At effective depth 2746' SNL, 4308' WEL, Sec. 1, T11N, R16E At total depth 2762' SNL, 4312' WEL, Sec. 1, TIlN, R16E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Strat~graphic Service . 7. Unit or Property name Duck Island Unit/Endicott 8. Well number Casing Length Structural Conductor 92' Surface 2738' Intermediate 12098' Production Liner 9. Permit number/approval number 92-119/Not required 10. APl number 50- O29-223O4 11. Field/Pool Endicott Field/Endicott Pool 12763' feet 10332'BKB feet Plugs (measured) 12741' feet 10316'BKB feet Junk (measured) Size Cemented Measured depth True ve,.rti.c...al depth BKB 30" Driven 131' 76' 103/4" 1193 c.f. Permafrost 2777' 2720' 75/8" 2336 c.f. Class "G" 12137' 9818' Perforation depth: measured 890' 51/2" 201 c.f. Class "G" 11860'-12750' 9619'-10244' 12586'-12610', 12248'-12278', 12346'-12354', 12362'-12366', 12376'-12410', 12414'-12446', 12536'- 12558' true vertical (Subsea) 10135'-10152', 9898'-9920', 9969'-9974', 9980'-9983', 9990'-10014', 10017'-10039', 10101'-10117' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft. NT-80S, TDS tubing with 4 1/2" tailpipe to 11859' Packers and SSSV (type and measured depth) 75/8' TIW HBBP Packer set at 11788'; 4 1/2" SSSV set at 1480' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 236 168 6206 0 Tubing Pressure 26O 2119 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil Gas Suspended Service. Water Injector 17. I hereby certify that the foregoing is true.and correct to the best of my knowledge. Signed ~_~/'7~//7_.~.. ~. /~~ ~.~'(.~ Title Senior Technical Assistant ll Form 1 ~0~;4 Rev 06/15/88 Date /b~)/~' L//' SUBMIT IN DOPU1CATE ~ ./ Endicott -~ Production Engineering Department DATE: 10/31/93 WELL N~: 1-51/V-20 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations HOBBS ATLAS INOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODUCTION TREEI ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH. CLEAN UP ANY~ CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE· ~ I[" 'DATE/TIME OPERATIONS SUMMARY 0800 RU. Post radio Silence signs at the entrance to island and next to well site. 0930 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 1030 Install SSV fusible cap. SIWHP = 2000 psig. lAP = 600 psig. OAP = 0 psig. Choke =SI. 1050 Pressure test lubricator to wellhead pressure. 1055 RIH with Gun #1 (24 feet). SIWHP = 2000 psig. 1215 Tie in to CBL dated 4/22/93. All of the depths liste8 below are from the open hole reference log. 1230 Hang gun #1 Top Shot at 12586' MDBKB. WHP-1900 PSI. 1232 Shoot gun #1 from 12586-12610' MDBKB. WHP-1850 PSI. 1234 SI well and log collars through sliding sleeve while POH. 1410 RIH with Gun #2 (24 feet). SIWHP = 1840 psig. 1515 Tie in to CBT logging up. Shoot gun # 2 from 12422-12446' 1645 RIH with Gun #3/18 feet Switched). SlWHP = 1880 psig. 1745 Tie in to CBT logging up. Shoot top gun of switched gun # 3 from 12400-12410' MDBKB. 1830 Tie in to CBT logging up. Shoot bottom gun of switched gun # 3 from 12414- 12422' MDBKB. Log collars up. SIWHP-1877 psi. 1945 RIH with Gun #4 (24 feetI. SIWHP = 1875 psig. 2050 Tie in to CBT logging up. Shoot gun # 4 from 12376-12400' MDBKB. Log · . collars up. SIWHP-1868 psi. 2055 POOH. SlWHP = i855 psig. Confirm all shots fired. 2215 End radio silence. 2230 RDMO. SIP-1845, lAP-600, OAP-0. PERFORATION SUMMARY: GUN INTERVAL(DLL) CBL DEPTH FEET SUBZONE. I 12586-12610 12586-12610 24 3B2 2 12422-12446 12442-12446 24 3C1 3A 12400-12410 12400-12410 1 0 3C2 3B 12414-12422 12414-12422 8 3Cl 4 12376-12400 12376-12400 24 3C2 All intervals were shot using 3 3/8" carrier guns at 6 spf, 60/120 degree phasing and random orientation. Endicott Production Engineering Departme,nt , Operations Report DATE' I 1/7/93 WELL N°. 1-51/V-20 ~ . TYPE OF OPERATION MIT BP EXPLORATION REP' MCBRIDE SERVICE COMPANY' LITTLE RED I. TIME .... OPERATIONS SUMMARY ] 1 300 RIG UP LI-I-]-LE RED TO IA A~D P-'TEST LINES TO 4000 PSIG. ' -" SIP = 2010 PSI IA=650PSI' OA=50PSIG 1400 BEGIN PUMPING DIESEL AT 2.5 BPM. , 1425 PRESSURED IATO2500 PSI SIP=2010 OA 50 14'~0 IA = 2400. BUMP UP TO 2500 1450 IA = 2250. BUMP UP TO 2600. COMPRESSING GAS. ,_ 1505 IA = 2300. 1520 BUMP UP TO 2525 PSIG. 1550 IA = 25!0 SIP = 2010 0A = 50 ' GOO'D TEST. MIT WAS WITNESSED BY I AOGCC REP. DOUG AMO,.S 1600 IA BLED DOWN TO 340 PSIG. RIG DOWN LI-]-FLE RED. i · Endicott Production Engineering Department , ..Operations Report DATE' I 1/10/93 WELL N-°: 1-51/V-20 ~TYPE OF OPERATION' B'P EXPLORATION REP' SERVICE COMPANY' KILL WELL FOR INJECTION KIMMETT LITTLE RED 'TIME ,- ':'' ..... Oi~ERATIONS sL~MMARY 1 915 RIG UP LITTLE RED AND P-TEST LINES TO 4000 PSIG. SIP = 2100 PSI IA=350PSI OA=0PSIG 1934 BEGIN PUMPING DIESEL AT 4.2 BPM. 1940 PUMPING AT 6 BPM. PRESSURE UP TO 2150 PSI AT 50 BBL AWAY. DROP RATE. 2030 150BBL SEAWATER AND 5 BBL MEOH PUMPED. WHP 1300 PSI. POI. 2030 WELL SEEMS TO BE ACCEPTING WA~ER. RIG DOWN LITTLE RED. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 January 1994 RE: Transmittal of Data ECC #: 5937.07 Data: PL Dear Si~/Madam, Reference: BP 1-51/V-20 MPI ~:~ ENDICOTT Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PLS INJSURV.FINAL RF PLS~NJSURV~FINAL BL Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: '7~?./../,~.~x~ Date: This is to acknowledge_ receipt of the following L _nts and negatives. COMPANY: STATE OF ALASKA ATTENTION: LARRY GRANT FIELD: ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA 1-51/V-20 (PERF~PFC CCL 5" ~%~%o~p 1~ VLt~\ 0 1 2-66/SD-12 SBT/GR/CCL ~, ~AqO _~1 \5~q~ 0 1 3-05/0-29 PLS CINJECTION~ 5" 1 0 1 3-11/M-30 PDK-100/G~/~L%- ~,, 1%700 1_ J2~5 0 1 · RfCE, w -D Please retu one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT/RTNCARD1 STATE OF ALASKA t, ./-,A OIL AND GAS CONSERVATION COMMI~ _ N ~' _. . REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing Stimulate X Plugging Perforate Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 2180' WEL, Sec. 36, T12N, R 16E 5. Type of Well: Development Exploratory StratJgraphic Service 6. Datum elevation (DF or KB)" "'.:.' /' KBE = 55.3m. feet 7. Unit or Property name Duck/s/and Unit/Endicott 8. Well number 1-51A/-20 /V~ Ioi. At top of productive interval 2366'SNL, 4162' WEL, Sec. 1, T11N, R16E At effective depth 2746' SNL, 4308' WEL, Sec. 1, T11N, R16E At total depth 2762' SNL, 4312' WEL, Sec. 1, T/IN, R16E 9. Permit number/approval number 92-119/Not required 10. APl number 50- 029-22304 11. Field/Pool Endicott Fie/d/Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 92' 2738' 12098' 890' 12763' feet Plugs (measured) 10332'BKB feet 12741' feet Junk (measured) 10316'BKB feet Size Cemented 30' Driven 103/4" 1193 c.f. Permafrost 75/8" 2336 c.f. Class "G" 0 CT 1 9 199; Alaska 0il & Gas Cons. Anchorage Measured depth True ve~l depth BKB 131' 76' 2777' 2720' 12137' 9818' measured 51/2" 201 c.f. Class "G" 11860'-12750' 9619'-10244' 12586'-12610'(Squeezed), 12248'- 12278', 12346'- 12354', 12362'- 12366', 12376'-12410', 12414'- 12446', 12536'- 12558' true vertical (Subsea) 10135'-10152'(Squeezed), 9898'-9920', 9969'-9974', 9980'-9983', 9990'-10014', 10017'-10039', 10101'-10117' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft. NT-80S, TDS tubing with 4 1/2" tailpipe to 11859' Packers and SSSV (type and measured depth) 7 5/8" TIW HBBP Packer set at 11788'; 4 1/2' SSSV set at 1480' 13. Stimulation or cement squeeze summary Mud acid stimulation Intervals treated (measured) 12248'-12278', 12346'-12354', 12362'-12366', 12376'-12410', 12414'-12446', 12536'-12558' Treatment description including volumes used and final pressure 249 Bbls. seawater, 10 Bbls. xylene, 15 Bbls. NH4CL, 20.2 Bbls. 15% HCl, 45.2 Bbls 12%-3% Mud Acid NH4CL over/lush. FWSlP = 420 psig. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 242 3138 1775 0 314 39 3266 1264 0 297 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedd"---'~/;2~'.~.~L2__.., ~,~, . ~.~.¢~' Title Senior Technical Assistant ll Form 10-4~'~e~/'0~/15/88 Date/O//~/~:? SUBMIT IN DUP'LIO/~TE- BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 16, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AC)GCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ~enior Technical Assistant II JLH Enclosures xc: File 06.10 WELL NAME DATE 1-09/J-18 8/22/93 INTERVALS LOG NAME RUN NO COMPANY NAME 11200'-11945' PDK-100 LOG 1 ATLAS WIRELINE ~--" 5:~ 3-17/J-30 oK:~ ~"~ 2-18/L-16 ct'0 -2..~ 2-36/O-14 ~'~ I,~ c'/ 1-35/O-25 ~-~'~ ~ 2-28/P- 19 ~-~ 1-15/P-25 %~q 3-47/Q-35 ~lt~ ~-51/V-20 7/27/93 9/5/93 8/20/93 8/25/93 8/28/93 9/4/93 9/6/93 8/21/93 13400%13950, 10900'- 11200' 10800'- 11250' 12700'-13261' 9800'-10320' 12400'- 12860' 100'-10450' 3600'-12700' PRODUCTION LOGGING SERVICES PFC/GR/CCL PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES I ATLAS WIRELINE I ATLAS WIRELINE 1 ATLAS WIRELINE I ATLAS WIRELINE I ATLAS WIRELINE I ATLAS WlRELINE I ATLAS WIRELINE I ATLAS WIRELINE STATE OF ALASKA ..... SKA OIL AND GAS CONSERVATION COMM~_,..,ON :.,- 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 BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service . Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 8. 2163' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 2402' SNL, 4056' WEL, Sec. 1, T11N, R16E At effective depth 2746' SNL, 4308' WEL, Sec. 1, T11N, R16E At total depth 2762' SNL, 4312' WEL, Sec. 1, TIIN, R16E 12. Present well condition summary Total depth: measured true vertical AUG 2 5 1995 Alaska Oij & Gas Cons. Commission Annhnra0e 12763' feet Plugs (measured) 10332'BKB feet Well number 1-51/V-20 9. Permit number/approval number 92-119/Not required 10. APl number 50- 029-22304 11. Field/Pool Endicott Field/Endicott Pool Effective depth: measured true vertical 12741' feet 10316'BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~l depth BKB 92' 30" Driven 131' 76' 2738' 103/4" 1193 c.f. Permafrost 2777' 2720' 12098' 75/8" 2336 c.f. Class "G" 12137' 9818' measured 890' 51/2" 201 c.f. Class "G" 11860'-12750' 9619;10244' 12586; 12610'(Squeezed), 12248; 12278', 12346; 12354', 12362'- 12366', 12376'- 12410', 12414'- 12446', 12536'- 12558' true vertical (Subsea) 10135'-10152'(Squeezed), 9898;9920', 9969;9974', 9980'-9983', 9990'-10014', 10017'-10039', 10101'-10117' Tubing (size, grade, and measured depth) 4 1/2" 12.6tt/ft. NT-80S, TDS tubing with 4 1/2" tailpipe to 11859' Packers and SSSV (type and measured depth) 7 5/8" TIW HBBP Packer set at 11788'; 4 I/2" SSSV set at 1480' 13. Stimulation or cement squeeze summary Coiled Tubing Squeeze for water shut off Intervals treated (measured) 12586'-12610' Treatment description including volumes used and final pressure 819 Bbls. seawater, 24 Bbls. 15% HCL, 28 Bbls. effluent water, 10 Bbls. Class "G" Cement, and 32 Bbls. methanol; FWHP = 2400 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 9 .-2143 1768 0 344 ""/ 5374 1220 0 Tubing Pressure 321 385 15. Attachments Copies of Logs and Surveys run Daily Report of Well Qperations 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10,~74 Rev 06/15/88 SUBMITIN DUPLI6ATE .~_?, ? Endicott Production Engineering Department DATE: 5/16/93 WELL N°: 1-51/V-20 BP EXPLORATION REP: SERVICE COMPANY: Post Squqvz¢ PCrfQrations Luedke-Chan AWS (Brunner) INOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODUCTION TREEI ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH. CLEAN UP ANY I CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE. DATE/TIME OPERATIONS SUMMARY 0530 MIRU Hot Oil Services. Pump methanol down IA for hydrate prevention. 0730 MIRU AWS. Post radio silence signs at the entrance to the island and adiacent to the well site. 0800 Install SSV fusible cap. The SSSV is Out. FWHP = 300 psig. IAP 1850 psi#. OAP = 0 psi#. 0800 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify. rig, security). 0815 SI Well. 0845 Pressure test lubricator to wellhead pressure. 0849 RIH with Gun gl (22 feet). 1 0 10 Open wing and choke to 40 beans. Turn gas lift on (temporary line, so unsure of rate) 1 030 Tie in to SBT dated 4/22/93. All of the depths listed below are from the open hole reference log,. Flag line. FWHP = 240 psi# . 1045 Hang gun gl Top Shot at 12536' MDBKB. 1053 Shoot gun gl from 12536-12558' MDBKB. FWHP = 1040 psi#. 1 1 15 SI well and POOH. 1225 RIH with Gun #2 (20 feet). SIWHP = 1650 psi#. 1 320 Open wing valve and choke to 40 beans. 1340 Tie in to CBT logging up. Shoot gun # 2 from 12426-12446' MDBKB. FWHP = 1210 psi#. 1 404 SI well and POH. 1530 RIH with Gun #3 (12+10 feet). SIWHP = 1550 psi#. 1 630 Open wing valve and choke to 40 beans. 1650 Tie in to CBT logging up. Shoot gun # 3a from 12414-12426' MDBKB. FWHP = 890 psi#. 1704 Tie in to CBT logging up. Shoot gun # 3b from 12400-12410' MDBKB. FWHP = 900-1250 psi#. 1 745 SI well and POH. 1940 RIH with Gun #4 (24 feet). SIWHP = 1505 psi#. 2045 Open wing valve . FWHP = 640 psi#. 2 109 Tie in to CBT logging up. Shoot gun # 4 from 12376-12400' MDBKB. FWHP = 980 psi#. 2 125 SI well and POOH. .. 2300 RDMO to do SBT on 1-15. Turn well over to production operations. Wilt return after rig is finished with AWS unit. 5/18/93 0915 MIRU AWS. Post radio silence signs at the entrance to the island and adjacent to the well site. 1010 Install SSV fusible cap. The SSSV is Out. FWHP = 364 psi#. FWHT = 126 de# F. IAP = 950 psi#. OAP = 0 psi#. 1 0 11 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify rig,, security). 1 04 5 SI Well. ., 1048 Pressure test lubricator to wellhead Pressure. - 1 050 RIH with Gun #5 (20' body w/ 8' & 4' ). SIWHP = 1234 psig. Alaska. Oil & Gas Cons. Cornrnission Anchorage DATE: WELL N°: 5/18/93 1-51/V-20 1 140 Open wing valve and choke to 55 beans. FWHP = 520 psi#. 1205 Tie in to CBT logging up. Shoot gun # 5 from 12362-12366' and 12346-12354' MDBKB. FWHP = 420 psi#. 1 2 2 0 SI well and POOH. 1 330 RIH with Gun #6 (,30 feet). SIWHP = 1023 psi#. 1425 Open wing valve and choke to 55 beans. FWHP = 260 psi#. 1449 Tie in to CBT logging up. Shoot gun # 6 from 12248-12278' MDBKB. FWHP = 350 psi#. 1500 SI well and POH. SIWHP = 1200 psig. Confirm all shots fired. Note: on 10' of gun #6, shots were 180 deg off. Were in same directions, only not through scallops. 1 63 0 End radio silence. 1 6 3 0 RDMO. POP. PERFORATION SUMMARY: GUN INTERVAL(DLL) CBL DEPTH FEET ~ 1 12536-12558 12536-12558 22 3B3 2 12426-12446 12426-12446 2 0 3C1 ~'~ 3A 12414-12426 12414-12426 1 2 3C1 3B 12400-12410 12400-12410 1 0 3C2 4 12376-12400 12376-12400 2 4 3C2 -'"'--'~A 12362-12366 12362-12366 4 3C2 /74x% 5B 12346-12354 12346-12354 8 3C3 .~ 6 12248-12278 12248-12278 3 0 3C4 All intervals were shot using 3-3/8" hollow carrier guns at 4 spf, 90 degree phasing, 0 orientation and 21 gram charges. Sec I EH = 0.47", TTP = 22.8". Sec II EH = 0.51", TTP = 20.37". The tie-in log was on depth with the open hole reference log. ,g/as/fa Oil & Gas Cons. 6ommiss~o,, Anchora,qe BP EXPLORATION ARCO Alaska, Inc. To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: August 23, 1993 Attention: Steve McMains Subject: DS 1-51N-20 Corrected Completion Notice Enclosed, in duplicate, is a corrected copy of the completion notice for the above referenced well. The bottom hole, and top of the producing interval legal descriptions have been altered to reflect a Gyro survey run on May 3, 1993. These locations had previously been reported from an MWD survey run in March, 1993. Yours Sincerely, Russ Strickland Drilling Administration Supervisor MS CC. Jeanne Haas Well file A U G 2 4 1993 ~[aS~l 0JJ & Gas Cons. Commission Anchorage " STATE OF ALASKA ALASK/-, OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEhDED [] ABAN~ED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-119 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22304 4. Location of well at surlace 9. Unit or Lease Name 2163'SNL, 2180' WEL, SEC. 36, T12N, R16E ~C.A'¢~ Duck Island Unit/Endicott At Top Producing Interval , VElitlFI~)~...;~..~. 10. Well Number 1-51/V-20 At Total Depth ! Endicott Field/Endicott Pool 2763' SNL, 4311' WEL, SEC. 1, T11N, R16E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 55.3' I ADL 34646 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. ~ Aband. 115. Water Depth, if offshore 116. No. of Completions 3/21/93 4/5/93 5/18/93'I 6-12' MSL feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Direclional Survey ]20. Depth where SSSV set ]21. Thickness of Permafrost 12763' MD/10332' TVD 12741' MD/10316' TVD YES [] NC) []! 1480' feet MD 11466'(Approx.) 22. Type Electric or Other Logs Run D I T/S G T/~I-C C?A M S 23. CASING, LINER AND CEMENTING RECORD SE-FrlNG D~ MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive Surface 131' 30" Drive 10-3/4" 45# J55 Surface 2777' 13-1/2" 1193 cu ft "F"/290 cu ft "G" 7-5/8" 29. 7# NT95 Surface 12137' 9-7/8" 2336 cu fl Class "G" 5-1/2" 17# L-80 11860' 12750' 6-3/4" 291 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TL~ RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD/ Gun Diameter 3-3/8" 4 spf MD TVD 4-1/2" 11859' 11788' 12248'-12278' 9963'-9985' 12346'-12354' 10033'-10039' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12362'-12366' 10045'-10048' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 12376'-12410' 10054'-10079' 12414'-12446' 10082'-10105' 12536'-12558' 10169'-10185' 27. PRODUCTION TEST iDate First Production IMethod of Operation (Flowing, gas lift, etc.) 5/4/93: I Gas Lift Date of Test Hours Tested iPRODUCTION ,~-OR OIL-BBL ~.GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD ~' I Flow Tubing Casing Pressure CALCULATED OlL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. A U ¢~ 2 4 !99:~ Alas_~a .0il & Gas Cons. O0r~rnissi0° ~Anch0rage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate : _~. 30. GEOLOGIC MARKEF, . ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Base HRZ 11600' 9489' Kekiktuk 12175' 9911' .: .. . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~--z~-~,TitleDri/Jin.qEn.qineerSupervisor pate INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. SUbmit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' lr:dicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. k E E E IV i~ D Item 28: If no cores taken, indicate "none". Form 10-407 Alaska Oi~ & Gas Cons. Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 20 July 1993 RE: Transmittal of Data ECC #: 5937.00 Data: LDWG Dear Sir/Madam, Reference: BP 1-51/V-20 MPI ENDICOTT ; Enclosed, please find the data as described below: Tapes/Diskettes: Sent by U.S. MAIL 1 LDWG TAPE+LIST. AOGC Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Att . Rodney D. Paulson Received Z~~~~/ Date: f/V ~ RECEIVED JUL ~ ~ 199~ ~s~ Oil & Gas Oons. ¢omml~n Anchorage STATE -' 0 RIG INA L ALASKA OIL AND GAS CONSERVATION COMMISSION WF_! ! COMPt ETLON OR REOOMP LETION REPORT AND LOG 1. Status of Well Classification of BP Exploration 92-119-" 7'~,~ 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22304 4. Location of well ~ surface 9. Unit or Le~e Name 2163' SN~ 2180' WEL, SEC. 36, T12N, R16 :~ ........ ' .... I ~'fiP' ¢TIO. ' ~~ Duck Isled UniEEndico. . -- ' ~ ~ '~~ ~ 10. Well Number At Top Producing Inte~ ~ _~t. TE¢ ~ ~ ~~ ~ 1-51~-20 2402' SN~ 4056' WEL, SEC. 1, TI IN, R16~~ :~ ~[~J 11. Field ~d P~I Pool 5. Bovation in [~t {indicato KB, DF, ~tc.) ~. Co~o ~osi~nation and 8od~ ~o. KBE ~ 55.~' AD~ ~4~4~ 12. Date Spudded 13. Dae T.D. Ro~ 14. Date Comp., Su~. ~ Abed. ~15. Water Depth, il offshore ~16. No. of Completions 3~1~3 4~3 5/18/93~ 6-12'MSL feet MSL JOne 17. Total Depth (MD+TVD) 18. Plug Ba~ D~th (MD+TVD) 19. Directional Su~ey ~0. Depth where SSSV set ~1. Thickness of Perm~rost 12763' MD/IO~2' ~D 12741' MD/10316' ~D ~ ~ ~ D~ 1480' feet MD ~1466' (Approx.) 22. Type El~tric or Oth~ L~s Run DIT/SG T~CC/AMS ,23. CAS~, LINER ~D CEM~I~ ~ ~ D~ MD CASING SBE ~. ~R ~. G~E T~ ~M ~E ~ C~~ R~D ~~ ~D 30" St~ct. Ddve Surface 131' 30" Drive 10-3/4" 45~ J55 Surface 2777' 13-1~" 1193 cu ~ "F"~90 cu ~ "G" 7-5/8" 29.7~ NT95 Sudace 12137' 9-7/8" 2~C cu fl Class "G" 5-1/2" 17~ L-80 11860' 12750' 6-3/4" 291 cu ~ Class "G" 24. Perorations o~n to Production (MD+TVD of T~ ~d Bottom ~d 25. ~GR~ORD inte~al, size and number) SBE DEP~ S~(MD) PACKER S~ Gun Diameter 3-3/8" 4 spf MD ~ 4-1/2" 11859' 11788' 122~12278' 99~99~' 12346~12~4' 100~10039' 26. ACID, ~C~RE, C~ ~UE~. ~C. 12362~12366' 10~100~' DEP~ I~ERVAL (MD) AMOU~ & KIND OF MATERI~ 12376~12410' 10054~10079' 12414~12~6' 10082~I0105' 12536~12558' 10169~101~' 27. ~O~N ~ST Date First Production JMethod of Operation (Flowing, gas lilt, etc.) 5/4~3 l Gas L~ Date of Test Hours Tested PRO~TI~ FOR OIL-BBL ~S-MCF WATER-BBL iC~S~ IGAS-OIL ~TIO ~T P~D ~ I Flow Tubing Casing Pre~ure C~CU~TED OIL-BBL ~S-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-~UR ~TE ~ 28. CORE DATA Briel description of lilhology, porosity, lractur~, ~arent dips, an¢ pr~ence ol oil, gas or water. ~ubmil ~re ~ips. R E VEb AJaska 0il & Gas Cons. Anchorage ........ -'erin 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKEF~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Base HRZ 11600' 9489' Kekiktuk 12175' 9911' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~/- ' //JJ~/ ~/.. /¢~,.~.~ ~;/" TitleDrl/lin.qEn.qinoerSupervisor pate INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ,.~ ~'" ~'t~/' ~ h" Item 28: If no cores taken, indicate "none". ' "'-' ~ ~" Form 10-407 Alaska Oil & Gas Cons. 6ommissio~ Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SDI 1-51/V-20 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50-029-22304 PERMIT: APPROVAL: ACCEPT: 03/21/93 06:00 SPUD: 03/21/93 07:00 RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 03/22/93 (1) TD: 1500' (1500) 03/23/93 (2) TD: 2792' (1292) 03/24/93 (3) TD: 2792' ( 0) 03/25/93 (4) TD: 4405' (1613) 03/26/93 (5) TD: 4706' ( 301) 03/27/93 ( 6) TD: 4706' ( 0) DRLG 13-1/2" SLIMHOLE MW: 8.9 VIS:ll8 MIX SPUD MUD, R/U ROCK WASHER & BAGGER, GYRO, P/U STAB BLADES, SPUD & DRILL W/GYRO & MWD TO 1500'MD RIH W/ 10-3/4 CSG MW: 9.3 VIS:iii DRLG 13-1/2" HOLE. CIRC HI VIS SWEEP. TRIP OUT. CLEAN CLAY BALL FROM STAB & BIT. TRIP IN FOR WIPER TRIP. WASH & REAM TO 2790. PUMP HI VIS SWEEP TO SURFACE, CIRC & COND HOLE FOR CSG. R/U TO RUN 10-3/4. RIH W/ CSG FILL EVERY JT. P/U BHA. MW: 9.3 VIS: 90 RIH W/ 10-3/4" CSG. CIRC. CMT CSG. DISP W/ MUD. N/D DIVERTER. TOP JOB. N/U BOPE. TEST BOPE. P/U BHA. DRLG. MW: 9.2 VIS: 45 RIH. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. LOT (15.6 PPG EMW). DRLG F/ 2804'-3500' SHORT TRIP TO 2700'. DRLG F/ 3500'-4128' SHORT TRIP TO 2725' DRLG F/ 4128'-4405'. REPAIR HYDROMATIC. MW: 9.3 VIS: 47 DRLG F/ 4405'-4706' CIRC. POOH TO SHOE. REPAIR HYDROMATIC. REPAIR HYDROMATIC REPAIR HYDROMATIC. MW: 9.3 VIS: 45 03/28/93 (7) TD: 5163' ( 457) 03/29/93 (8) TD: 6623' (1460) 03/30/93 (9) TD: 7560'( 937) RIG SERVICE MW: 9.4 VIS: 53 REPAIR HYDROMATIC. RIH. REAM F/ 3939'-4706' DRLG F/ 4706'-5163' POOH. CHANGE BIT. RIH. DRLG. MW: 9.5 VIS: 46 RIH. REAM TO 5163'. DRLG F/ 5163'-5748' SHORT TRIP 8 STDS. DRLG F/ 5748'-6523' SHORT TRIP TO 5569' DRLG F/ 6523'-6623' DRLG. MW: 9.6 VIS: 47 DRLG F/ 6623'-7062'. POOH. CHANGE BIT, BHA. RIH. DRLG F/ 7062'-7560' 4lask..a Oil & Gas Cons. Corm'nissioi-~ WELL : SDI 1-51 OPERATION: RIG : DOYON 15 PAGE: 2 03/31/93 (10) TD: 8234'( 674) 04/01/93 (11) TD: 8836'( 602) 04/02/93 (12) TD: 9650' ( 814) 04/03/93 (13) TD:10648' ( 998) RIH. MW: 9 5 VIS: 46 DRLG F/ 7560'-7859' SHORT TRIP TO 7062' DRLG F/ 7859'-8234' POOH. CHANGE BHA. TEST BOPE. RIH. POOH. RIH. DRLG F/ 8234'-8705' 8705'-8836' CIRC. POOH. MW: 9 5 VIS: 46 SHORT TRIP TO 8000' DRLG F/ DRLG. POOH. RIH. DRLG F/ 8836'-9500' F/ 9500'-9650' MW: 9 6 VIS: 45 SHORT TRIP 7 STDS. DRLG POOH. DRLG F/ 9650'-10648' CBU. POOH. MW: 9 8 VIS: 47 04/04/93 (14) TD:10910' ( 262) DRLG. MW: 9 8 VIS: 43 POOH. CHANGE BHA. RIHo DRLG F/ 10648'-109!0' 04/05/93 (15) TD:11264' ( 354) DRLG. MW: 9 9 VIS: 48 CBU. POOH. CHANGE BHA. RIH. DRLG F/ 10910'-11264' 04/06/93 (16) TD:11758' ( 494) 04/07/93 (17) TD:l1908' ( 150) 04/08/93 (18) TD:12040' ( 132) 04/09/93 (19) TD:12243' ( 203) TRIP @ 11758' MW: 9 9 VIS: 45 DRILLING FROM 11264 TO 11471. SHT TRIP TO 10910. DRILLING FROM 11471 TO 11758. PUMP PILL. TRIP OUT. DRILLING MW: 9 9 VIS: 44 LAY DOWN DYNA DRILL PULL WEAR RING INSPECT SAME, INSTALL. RIH TO 2765, WITH BIT #9. SERVICE RIG, TEST MWD TOOL. CONT. RIH TO 11758. DRILL AND SURVEY 9 7/8 HOLE TO 11908. DRILLING MW: 9.9 VIS: 45 DRILL AND SURVEY 9 7/8 HOLE TO 12004. POH FOR BIT AND BHA CHANGE. SERVICE WEAR RING. MADE UP BIT #10 CHANGE BHA, RIH TO 2550. SLIP AND CUT DILLING LINE, TEST MWD. RIH TO 12004. DRILL AND SURVEY 9 7/8 HOLE TO 12040. SHORT TRIP. DRLG TO 12243' MW: 9.9 VIS: 46 CBU. 10 STDS SHORT TRIP. 04/10/93 (20) TD:12243' ( 0) CMT 7-5/8" CSG. MW: 9.9 VIS: 47 CBU. POOH. L/D BHA. TEST BOPE. RIH W/ 7-5/8" CSG. CIRC. 04/11/93 (21) TD:12243' ( 0) RIH. MW: 9.9 VIS: 42 CMT CSG. BUMP PLUG W/ 2000 PSI. INSTALL & TEST PACKOFF. TEST BOPE. RIH. Oil & Gas Cons, Anchor:~qe WELL : SDI 1-51 OPERATION: RIG : DOYON 15 PAGE: 3 04/12/93 (22) TD:12340' ( 97) 04/13/93 (23) TD:12420' ( 80) DRLG. MW: 9.4 VIS: 40 RIH. TAG CMT. CIRC. TEST CSG. OK. DRLG CMT, FC, FS TO 12254' CIRC. FIT (13.1 PPG EMW) . DRLG TO 12340' DRLG. DRLG TO 12343' MW: 9.3 VIS: 41 POOH. CHANGE BITS. RIH. DRLG TO 12420' 04/14/93 (24) TD:12635' ( 215) DRLG. DRLG TO 12636' MW: 9.5 VIS: 44 04/15/93 (25) TD:12755' ( 120) 04/16/93 (26) TD: 12763' ( 8) 04/17/93 (27) TD: 12763' ( 0) 04/18/93 (28) TD: 12763' ( 0) 04/19/93 (29) TD:12763' ( 0) 04/20/93 (30) TD: 12763 PB: 0 DRLG. MW: 9.3 VIS: 52 DRLG TO 12655' POOH. CHANGE BIT. RIH. DRLG TO 12700' CIRC. DRLG TO 12755' OH LOGS. MW: 9.8 VIS: 41 DRLG TO 12763' TD WELL @ 08:00HRS, 4/15/93. CBU. POOH 2 STDS. WELL FLOW. RIH. CIRC & RAISE MUD WT TO 9.6 PPG. SHORT TRIP TO SHOE. CIRC. SHORT TRIP TO SHOE. POOH. R/U SWS. LOG RUN: MFSL/DLL/GR. RIH W/ LOGGING TOOLS. MW: 9.8 VIS: 44 LOG RUN: MFSL/DLL/GR. RIH W/ BHA. CBU @ TD. POOH. LOG RUN: MFSL/DLL/GR. HIT LEDGE. POOH. RIH W/ LOGGING TOOLS ON DP. RIH. MW: 9.7 VIS: 46 RIH W/ LOGS ON DP. RIH W/ W/L. RIH TO 12178' NO GO PAST. POOH. L/D LOGGING TOOLS. RIH W/ BHA. REAM F/ 12137'-12288'. LOGGING. MW: 9.8 VIS: 43 REAM F/ 12379'-12763' CBU. SHORT TRIP TO SHOE. CBU. POOH. R/U SWS. LOG RUN ON DP: DIT/SGT/TCC/AMS/DWCH. RIH TO 12761' POOH & LOG WELL. RIH W/ LNR. MW: 9.8 WBM POOH W/ W/L. POOH W/ DP. R/D SWS. RIH. CIRC. SHORT TRIP TO SHOE. CBU. POOH. RIH W/ 5-1/2" LNR ON DP. 04/21/93 (31) TD:12763 PB: 0 RIH. MW: 9.8 WBM RIH W/ 5-1/2" LNR ON DP. CIRC. R/U HOWCO. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 52 BBLS CMT. DISP W/ MUD. SET PKR W/ 4200 PSI'. RELEASE F/ LNR. POOH. RIH W/ BIT. Oil & Gas Cons. Commission Anchorage WELL : SDI 1-51 OPERATION: RIG : DOYON 15 PAGE: 4 04/22/93 (32) TD:12763 PB:12741 04/23/93 (33) TD:12763 PB:12741 POOH. MW: 8.6 Seawater RIH TO TOL @ 11865' WASH THRU TOL. RIH TO 12670'. TEST LNR. OK. DRLG LC TO 12741' CIRC. POOH. RIH W/ CSG SCRAPER, BIT. CIRC. DISP TO SEAWATER. POOH. RUN 4-1/2: COMP. MW: 8.6 Seawater POOH. L/D DP. L/D BHA. R/U ATLAS. LOG RUN: CCL/GR/CNL/SBT. R/D ATLAS. RIH W/ 4-1/2" TBG. 04/24/93 (34) TD:12763 PB:12741 RIG RELEASED. MW: 8.6 Seawater RIH W/ 4-1/2" COMP STRING. SPACE OUT TBG. P/U HGR. LAND TBG. SET PKR. TEST TBG TO 4000'PSI. OK. TEST ANNULUS. OK. N/D BOPE. N/U TREE. PUMP 65 BBLS DN TBG. SECURE WELL. RIG RELEASED @ 02:30 HRS, 4/24/93. SIGNATURE: (drilling superintendent) DATE: ;~iaska OJJ & 6as Oons, Oom~r~issi.s~ ;~nchorape ~LL HE~, Lc:r:~%C~J: ........ L~T(H,.'-S:: wvv'*' ~"~ DEf'(D-W) TIE IH POi~%<TiP) : TRUE VERT DEFTH 1'30,03 IHi:LI~Ti~ ~!~t~ 0~00 DEPA~TURE(E/-W> Alaska Oil & Gas Cons. 6ommissiOn Anchorage ¥1 O ,"79 !170,14 ,,f.&..;..~ t .. I,*~-':' 1551,42 1745 ~'~ 272.18 4[. E~54,8~ 387-9 ,?4 -~03',- .~, o=. O 975,40 1074, 95,3 -- --- -..7~z. 95 '74,5 .5.825 94,.~ 37'_13,30 96,7 4'X~t,17 . it 6e~ 6% ft ft O, 0'3 3,:.].':' O~ 00 0,:~3 (,.,0r:.. 0; 0rJ ':, O0 -0,42 0,30 77,00 0,17 0,74 0,76 77, ~-: , --r, '. 2~.?; -~ +47 %09 2~ ~4 102,$i -0,30 '.'..,: v ~-' , ', '-' ' ' ,... .,~: r. ; '": 3,5Z 7,?~ ~'--"-- n,:~ !,20 ,._,: ,8-: '-,.'-~ 1:63 2,40 !47 ~%- -3,6i .ieq/ IOOf: 0,31 0,44 !,70 ~A "'~ '~ '" "== ~''~ -~.,53 Z?,t3 47.13 144,,~ 0,42 ~',89 3,09 145,~' -43.16 Ei,94 ~,~z ~w,z- -- 32,24 2 ,7 140 ~= -~.>~ 32,57 56,'?~ N5,C8 1,00 :.>,~ 1,Z' !51,54 -49,%4 ~,24 59,55 !45,05 0,Bi 34,96 0,47 i:~.vo -:,~.,..v ~-- -- ' nD~ ~t')~. as ~; ~ 35-, 15 62,20 145,59 0,i! 35,70 - :-' .--'-" '- · --, A.-',.:. ,. 145,84 0,13 ~,,0: O,Z ~,,'-'~' '"' ' ...?, =.~ re, ~ '.I 62,82 14A,02 08 38,43 O,l'? 187+~ '-'"'~'.' ¢-' ' ~.,67 0,1: I~,!0 -5,2,57 35.,,!5 63,24 q>, .~.I o,Z,~ 8~5, 3A -.,; ,, 1 35,6? 63 ,,r 14., ,-~O ), 13 · . -',,--- ' ' ¢ 0,!? 3:,,~ 0,5~., 97,75. -52,6;.. '"' >'' 64,&. 144,78 l,:v ,.:.~ -.~.~,4,, 38,17 AS,Aa "*'~ .... 67,80 35'-M 3.5? 1~,..7r .r4. ~e 'W,.~.: - -,' 47,02 :,iO - .-,: ,~ /o ~a c,, ',s, ,~ [5! ~ .... -,', 159,31 0, 47 63,59 5,rZ' !~3! -79~14 .;:,SE 84,59 73,15 6,41 196,~ -8~,4t ~,41 5~,5E. 162~7E 1,~ 8i,8A 8,21 ~7.~ -?9.63 22,96 102,47 166,48 !,97 11'?.27 13,18 i?~,66 -13~,45 ::,43 '~'" ~ 74,71 !71,?E. 19,:;5 - :,~,~.9 -4,7'? !81,95 18.1 51 ~ ~ .~', =4<:,=- =6,~4 *,~ -' -~3,D -~,43 ~,07 i85,72 2,87 3,93 3,25 2.19 2,50 *~,:-~'-*~****~ CIRCULAR iRC TARGET S~ATiO'fi AlleLe4 ~TiT:D: fr ~eq ~eg 57:',40 74', 5~ 196.30 -~; s~ 6~),99 ~o~,,,, ~: ~o 198,49 -6~3,4i AT_IMU..:H deg !72,4.~ !':'-'2,95 i Y.:~, :,~. 194,25 DLS d=.o" 10Cfr 1 1,48 2,59 5!84 5274 5370,00 95,0 5046,08 96,5 51!7,14 ~:.~t.' ~ ~. ~i ..-' . _ - ~.~; ~ ~ 946,~9 43,22 197,56 -922,4~ 10i0,32 42,~ I~,10 -98! ,52 5757, vt; .-~ .=.855,42 5955,22 96,6 5!-?,6" 92,9 10!,7 53~',37 07,7 99,8 5472,3~ -3i7,94 i210,gl 155,23 -~7,47 !Z?4,~ 195,36 -359,13 i343,82 15'5,50 -379,!0 14!0,87 195,59 -~99,04 1480,05 0,56 2, i7 6141,73 6236.14 633i :91 96,0 560~., .c..'.~: .c5,~ 5745,3'.;' 83~0 ~05,18 1537 '~= 43,73 i97,13 tz,'o ,..,.2, ,, 4-..:~e, !97,~ - 154g, 3',. 1668,1B 43,2! 197.17 -!6!0.20 · . 4,::.,~ '~'~, i673, 17~,~.~ ""= .,., 51 - 14 179! ,06 ~,M !97..!4 -172-5,43 0,44 0,2! 0,47 1,1'? 2,16 64~,,47 6612,32 671! 680&,77 15,5 5814,21 ~4~7 5876,26 97,1 5945,05 99,6 6015,i2 96,9 &9~2,24 1DI,~ ~,74 I96,8i -173~,87 IgM ~ 45,~; ~97.',/~ -17qS,94 i~90,~ ~,8! !97,03 -1861,34~ 2000,78 45,76 i'79.~ -!~8,54 4e.,o~ ig~,og -1%'4,29 2076.z= ' ~, 0,87 2,04 0,86 6902,90 6991,05 7086,02 7!~i, 26 7Z97,73 8g,i 6207,53 ;~,0 6272,45 96,5 6402,77 213&,9! 46,49 198,~ -2~8,73 Z~.;:Z, ? 46,80 199,4~ 2272,27 .~,97 202,52 -2!84,05 ~42,0i 47,20 1~',8~. '2249,07 2412,86 47.74 D2,20 -~ -~d,77 2144,88 196,29 -6~,63 ?.208,90 15'6,37 -647,42 ?_Z77,98 !96,5! -672,63 2347,50 196,65 -69B,06 2418,16 I96,78 1,09 ~,77 2,39 1,05 1,77 7477 7673.05 7765 95,2 6467,17 IC~.B 6537,~ 99,7 &603,97 55-~7 6667.93 92,9 67~3.24 2560,50 4S,03 20.[~,~ -2452,B8 26C~,'~, 48,39 ~3i,16 -252,2Z Z774,90 4-8,C4 199,8! -2654,i2 -723,~? 2486,05 196,9i ~ :' ~65 !~7 ' -., .., .;8 ,47 , o4 -~ ~ 2i:~:,AO 197,15 -~02,~.. . ~-~m~,65.,~ 197,22 'Szo,~. 2779,50 !97,27 0,94 2,04 7856,~ 7855,56 795!,94 8044,!2 28,~ g10,25 66,4 .~,55,$0 92,2 96,5 6986,?I 2842,5-5 48.~ ~4,~ -27!7,70 2&~3,~2 46,~0 l??,4f -~737,7~ ~12,29 47,02 ~7~50 -2783,25 25'76,8! 45,37 ~0,03 -2845,66 3047,69 45,81 !98,37 -29!0,72 -848,52 2847,08 197,~M -B55,74 28~,,32 i97,3~ -&72,21 2716,75 !97,40 -918,00 3052,05 !97,50 0,46 !,19 1,30 t-517J-20 ft ft .... ,~, . .-.: ~a, 7054,75 ~.- o~,? 7';7.,C.,~97 8333,J-; ,_, 84?8:60 5'5_--,3 7:A".,,~., :r:,.~ 3~-~,74 10!J 73~2,65 TARGET STATION ~2I.~H ft de.~ deg ft 3!,&6,10 45,7i 19~-,95 '3042,03 3254,29 ~ TM ~'s~ ~ -31C~A.~2 D£F'Af:TL~:£ DZZPL~E~NT ft it 4'40,I'4 -962,04 3190,53 -984,gi 3~,_ .:.:.'"-' -!032,44 3[4'7 DLS d. eq/ iO~t 0,3! 0,40 0,65 34~,94 4%2,< 19. ,.,.,.., ~25,!I 45,2-.'-' I'~,08 -3361,D .';.~'74,4-2- 45,04 !99,64 -3426,6! 366!,08 44/?'0 !98,88 -3~9,~ '"7'"' ~,r 44,,'7 z,e..,8~. ,.,....:,:, . -!054,36 M62,i9 197,73 1,24 -!07A,44 .......~27,% ~Y/"',76 0,15 - 1097, ~ ~' .: 3598,67 !9'7,7? 0,47 -i!42,80 373!,45 197,8.? 9188,24 9379,27 9471,8~ 9~3,42 95,0 778%72 /O2w~,.,V 92,5 79~,i0 !0!,8 7%'8,42 3794,01 ~,67 !97,98 -36!5,58 ~4.0,45 44,18 19B,82 ~27,31 44,17 197~? -3742,25 3971,56 43,93 197,7~ -38_%3,55 406!_~9 ~q ~ ~., ~.0: -3870,6? -I163, '2r 3798,~:°' !97,84 ~ : .~- ~. ,, ~:%.. ~_. -I~C,5,79 3~31o7! !?7,86 -122S.31 ~%,04 -!2q6,35 ~66,~ i77,~5 0,65 0,8! 0,31 0,56 %67,1i 9763,7? 9953,26 4126,~ 43,28 198,63 -393L08 413!,72 4~ 41¥z,.~ .,. 199,72 4-32.2,%: 43,37 200,05 -41i7, !6 - 1266,6~5 41[<!-"~' ~m--' 177,~=~. -1267,82 41S6,38 !97,85 -1267,85 4!97,30 !97,87 -i310,42 4262,76 197,90 13~,9~ ~? ~ 197,94 !,28 0,86 0,62 0,42 10-"."34.-9 10238 10333 96,3 ~3~,24 ~3,2 84!2,46 95,5 8452,S5 ·. . D~''A'~* , ~,o 8624,71 4389,,~vnr' 43:. 19 ~C.?-, 22 %179,12 4452,47 ~, .,:, , ,. -42~B, ~' 4517,c~3 ~ ~ ~,I8 -~20~'.7S 4581,37 42,24 I%',96 -4360,3~ 4M5,46 41,8i !%,07 -!355,72 4~73,52 197,97 =~ -1377,30 .,,>on A= 4521,51 19P,,02 -1420,20 4585,~ f?o r,~ -i44i,09 4649,94 !98,05 0,27 1,39 t~26,98 i~'73.,50 !0665,04 t06~,, _.:. ,t-b, 3 o,' 4.,': '..,'." 94,5 8817,13 'T 4,, ,~- 85'21,47 47!(;-",11 .~ == !~7,81 .aao--., ~', 4754,39 42 '"" '~ '"" '" '~ 200, "" 4,',:~ -4584 50 4oz: ,,/ 4882,2! 43,29 1.c.5:.B9 -4645,06 ~';' 14, A':,' 4:-,.~., 26! ,3'~. 64 ,, - -~4,.,1,03 47i4,/-,/ i96,05 -!474,87 4,'-'5B,78 196,05 -14'75,81. 4.,,'~,37 !%,07 -15!7,87 4886,~ ~,~_.._,,..ln -,.~.:., ,..,. 49.~r,4z. !$'6,!1 0,32 !,01 !,00 2,28 11094.53 11285,20 67,5 8970,31 96,1 '~"' ,'/t:'~ ~ ,80 95,2 9182,80 4961,56 43,~4 !??,73 -4719,34 50E,91 43,59 20i,52 -4781,50 ~°'~u:v,.,? ~' 42,78 201,41 516i.17 42,70 200,1~., -~oa:.7~.,..~.. , ~ AS 42,97 203,~: -49^5,gz -1545,77 4966,~ 198,!4 -!567,!7 50~,40 !96,17 -!594,28 5!00,9! 19~,21 -16!7,!8 5!65,42 i9~,24 -1641,08 5~9,80 198,~ ~.'0 1,3! O. Bl ",33,: 92,0 %2i,42 98,2 9394+70 92,5 ?$,7 ?537, 70,5 ~9i,23 ~">A", 25 c~,.n9 90;:,,02 .Kr;?1,75 5352,43 41.37 24-"2.,.'?0 -5081, ~ ~ ,-:,,.~,.. 40,72 ~c,.'::,OZ -5!37,i3 5476, C,4 40,5? 203,45 -5 !':;"!- .. 02 5_5..~, 0.~. "'l, ,...,,..,",n 203 ,8-4 -~2R7,24_ _ -1666.89 525'i,17 196.36 -1673,'.;'4 ~:q~ TM 19B. -!7i7 z~ ~z ~o I5'8,47 -174971 ~70 jv ,r.n ..... , ~ .... ~ ,/ LYO,_~q -~/o',;.99 ~;-~,2,.: 15'8,~°.-~ i,5'4 2,24 0:7! 6,30 -- 1-%iV-20 f:.-. ft ft i£017,5~ 12!2!,~ 93:8 9872:45 --. !£162,70 4i TP~5£T E:T~TIO?! SECTi[C~ 'r~.~-, ~.: ft dec 56_='4,60 43:79 20! 5;720,73 44,85 ~J! ~3! ~o~.~ ~'-' "~:, :.:. ...... 202:21 Ni-S Ei-W ft ft ft -r-.Agh~$,7 ~Z.o~ ~7...;,~.7~ -5481 ~ -1861'o~ ~7~o ~ DISPLACEMENT =~... AZIMUTH 1%,72 !93,7.5 !96,78 DLS ~OOft 0,93 2,53 2~07 WELL NAME 3-031J-33 3-41/i<-39 3-35/L-36 1-29/M.25 3-45/M-39 2-14/O-16 '~--- '<~b 1-15/P-25 ~'"' '~'~ 4-08/P-27 I~-t CI 2-12/Q-16 icl -- OLo 1-63/T-22 I~-It q 1-51/v-2o DATE INTERVALS LOG NAME 512319 3 13400'- 13670' PFC/CCL 5/15193 13200'-13655' PFIODUCTION ~ING 5/22193 11900'-12264' PRODUC~ LOGGING 5~24~93 13100'-14071' PDK- 100 5120193 29'-11848' PRODUCTION LOGGING 6/1193 10350'- 10578' PFIOEXJCTION I_OGGING 6~4~93 10350'-10800' P~CTION ~ING 5114~93 11950'- 12960' DUAL LATEROLOG - MSFL 5114193 11950'-12960' , DLL-MSFL-GR SSTVD LOG 5/17/93 11700'-12897' CNL/GR 5/17/93 11700'- 12897' ~t~I~G R/CCL 5/19/93 13000'-13676' PRODUCT[~ LOGGING 5/27/93 10000'-10300' PRODUCTE~ L.OC.-.-.-.-.-.-~iING 5~27~93 9950'-10318' P~TE~ ~ING 5~26~93 12100'-12700' PRODUC~ ~ING 5~26~93 11400'-12200' GR/CCL 511 5~93 11300'-12500' PFC/CCL · 5116193 12350'-12600' PFC/CCL 5/18~93 12350'-12600' PFC/CCL RUN NO COMPANY NAME ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS SCHLUM~ SCHLUMBERGER ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box' 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 10, 1993 Alaska Oil and Gas Conservation commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Dear AC)GCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, en?ne L. Haas or Technical Assistant II JLH Enclosures xc: File 06.10 IV D DiI.& Gas Cons. BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS 1-51/V-20 19/93 4/22/93 4/22/93 5/3/93 1-55/R-25 ~'~ / ,~ 5/15/8/934/93 2-14/0-16 '~f.¢_--'" I q_.~ 4/26/93 2-28/P-19 1~"~t~ 5/2/93 3-29/J-32 g0--' I'~ 5/2/93 3-39/J-39 ~'~} [f~ 4/30/93 3-41/K-39~, I"~L¢ 4/24/93 11200'-1 2740' 10000'-12721' 10000'-12721' 11300'-12691' 11900'-12694' 12900'-13195' 9200'-10585' 10050'-10335' 12290'- 12416' 13930'-14276' 12640'- 12648' LOG NAME RUN NO DIL/SFL/GR CBL CNLJGR/CCL PFC/GR CBL Production Logging Services GR/CCL PFC/GR Production Logging Services PFC/GR Vertilog COMPANY NAME Schlumberger Atlas Wireline Services Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Services Services Services Services Services Services Services Services Services BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 19, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ~a~n-ne L. Haas Senior Technical Assistant II ~,H R'£ C E IV E D Enclosures ~IA¥ 2 0 199,3 xc: File 06.10 .A~tska :{lil& ;6as'~ans. ~la~ STATE OF ALASKA AL~,,KA OIL AND GAS CONSERVATION COMMISS~.-,~ 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 x Pull tubing__ Variance__ Perforate__ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 2180' WEL, SEC. 36, T12N, R16E At top of productive interval 2277' SNL, 4156' WEL, SEC. 1, T11N, R16E At effective depth N/A At total depth 2839'SNL, 4366' WEL, SEC., T11N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) \ KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-51/V-20 9. Permit number 92-119 10. APl number 50- 029-22304 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet feet feet feet Size 20" Plugs (measured) Junk (measured) Cemented Drive Measured depth True vertical depth 131' 131' RECEIVED AJaska Oit & Ga..'-; O0r~s. (.;0r~ll'~ ;~t~ch0rag0 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 4/1/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "_., ~.: , i .. Signed ":'¢~ '','~/' "-' ' ' ~-~. ~¢- /..:x~..¢ p:, Title Drilling Engineer Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test__ Subsequent form required 10- Or~n~n~! ?'--.,~ed BY , ,~.., 'c~~ , Approved by order of the Commission .... i,~ W commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1-51/V-20 (MPI) Surface Casing Revised Surface Casing design 10-3/4", 45.5# J-55 BTC CASING BURST J-55 3580 Design Specifications COLLAPSE PBYS (#) TJYS (#) 2090 715000 796000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 1 4 2700 1 966 Burst S.F. 1.82 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2700 1334 Collapse S.F. 1.57 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3571 PBYS Tension S.F. 5.1 5 Mud Wt. 9.5 ppg TJYS 5.73 String Wt. (#) 138888 Original Surface Casing design 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 31 30 PBYS (#) 1040000 TJYS (#) 1097000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 14 2700 1966 Burst S.F. 2.65 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2700 1334 Collapse S.F. 2.35' Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3571 PBYS Tension S.F. 7.49 Mud Wt. 9.5 ppg TJYS 7.90 String Wt. (#) 138888 WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 31, 1992 Jeff Hall Workover Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 1-51/V-20 BP Exploration Permit No. 92-119 Sur. Loc 2163'SNL, 2180'WEL, Section 36, T12N, R16E, UM Btmhole Loc. 2839'SNL, 4366'WEL, Section 1, TllN, R16E, UM Dear Mr. Hall: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill Elllb. Type of Well. Exploratoryl'q Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenElI Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 34646 4. Location of well at surface 7. Unit or property Name 11. Type Bond(we 20 AAC 25.025) 2163' SNL, 2180' WEL, SEC. 36, T12N, R16E Duck island Unit/Endicott At top of productive interval 8. Well number Number 2277' SNL, 4156' WEL, SEC. 1, T11N, R16E 1-51/1/-20 2S100302630-277 At total depth 9. Approximate spud date Amount 2839' SNL, 4366' WEL, SEC. 1, T11N, R16E 1/20/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(aoand'rVD) property line ADL 47507-4366' feet 1-49/P-21- 10'@ 88'MDfeet 2560 12983' MD/10519' TVDfeet 16. To be completed for deviated wells .17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickott depth 2900 feet Maximum hole angle 44.4 o ;Maximum sudace 3900 pslg At total depth (TVD) 10000'/4890 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75 Surface 131 131' Drive 13-1/2" 10-3/4" 45.5~ NT8OLHE BTC 2757' Surface 2757' 2756' 1426 cu fl PF/290 cu ft "G" 9-7/8" 7-5/8" 29.7# NT95HS NSCC 12055' Surface 12055' 9856' 1818 cu ft Class "G" 6-3/4" 5-1/2" 17# NT-80 FL4S 1178 11805 9678' 12983' 10519' 305cuff Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production OOT ~ f~ Liner Perforation depth: measured Alaska Oil & Gas Cons. 60f~lffljsSiOr~ true vertical Anch0rago 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~i Drilling fluid program [] Time~vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby_ certif,~ that th~ ~reg,C,J~g is true and correct to the best of my knowledge Signed~..._//<.:.._l'"~"~~E ' Title Workover Engineer Supervisor Date..~~¢~.~ [// -- ~ COmmission Use Only Permit Number IAPI number IApproval date ISee cover letter ¢.2.-?/? 15 o- ~, ~. ~ - z 2_ 3 o ~ I ,Ge .--Z~/- ,¢~ , Ifor other requirements Conditions of approval Samples required [] Yes /]~'No Mud Icg required []Yes~No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; ~3M; 1~SM; F'110M; F']15M; Other: by order of Originai S~ned By Approved by Commissioner the commission Date/~-...~/~-~ P,r~v~d W ,johpStO0 .... Form 10-401 Rev.D~J~.85 Submit in triplicatb PROPOSED DRILLING AND COMPLETION PROGRAM WELL 1-51/V-20 (MPI) Objective Well 1-51/V-20 will be drilled as a water injection well. Zone 3C/3B is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to 2757 feet. Run and cement 10-3/4" 45.5#/ft NT-80LHE buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 9-7/8" hole with a 9.0 - 10.2 ppg mud system to the intermediate casing point above the Kekiktuk formation. Run and cement 7-5/8" 29.7#/ft. NT95HS NSCC casing. No abnormal pressures are expected in the 9-7/8" hole section. Pressure test casing. Drill out casing shoe. Drill 6-3/4" hole with a 9.6 ppg mud system to TD. Run open hole logs. Run and cement 5-1/2" 17#/ft NT-80 liner to TD with approximately 250 ft. of lap in the 7-5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaCl packer-fluid. Run CET/CBT/GR/CCL in 5-1/2" liner and CBT/GR/CCL from PBTD to 1000' above 7-5/8 shoe. Complete with a simple type assembly. A subsurface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Perforate well and run GCT/gyro after rig release. Fluids incidental to the drilling of the well will be pumped down the 10-3/4" by 7-5/8" annulus of the well. The 10-3/4" x 7-5/8" annulus will be freeze protected with a non-freezing fluid down to 2000 feet once the rig is released. PC 9-25-92 RE£EiVED OCT ~ 9 1992 Alaska Oil & Gas Cons. 6ommissio~ Anchorage ENDICOTT PRELIMINARY WELL PL,. Well: 1-51/V-20 Island: Main Production Island RT Elev. AMSL: 56 Rig: Doyon #15 BR/100': 2 Location Surface: X=259,020 Y= 5,982,253 2163' SNL, 2180' WEL, Sec. 36, T12N, R16E Target: X= 256,808 Y= 5,976,767 2437' SNL, 4216' WEL, Sec. 1, T11 N, R16E Est. Spud Date: 12/20/92 Operation Days: 30 Max. Angle: 44.41 KOP (BKB): 2900 Target Dep.: 5,915 Target Dir.: S 20.5° W Item TVDss TVD BKB MD BKB DEPARTURE 30" Drive Pipe 75 131 131 Base Permafrost 1,41 0 1,466 1,466 24 10-3/4" Casing 2,700 2,756 2,757 24 E O B 4,847 4,903 5,121 843 Top Tuffs 8,710 8,766 10,529 4,627 Top HRZ 9,195 9,251 11,208 5,102 Top Itkilyariak 9,440 9,496 11,551 5,342 7-5/8" Packer 9,586 9,642 11,755 5,485 5-1/2" Liner Top 9,622 9,678 11,805~ 5,521 7-5/8" NT95HS Casing 9,800 9,856 12,055 5,695 Top Kekiktuk/Top Zone 3C 9,850 9,906 12,125 5,744 GCC 9,854 9,910 12,130 5,748 Target 10,025 10,081 12,370 5,915 Top Zone 3B 10,080 10,136 12,447 5,969 O W C 10,195 10,251 12,608 6,082 Top Zone 3A 10,270 10,326: 12,713 6,155 Top Zone 2B 10,373 10,429 12,857 6,256 Total Depth 5-1/2" 17# Liner 10,463 10,519 12,983 6,345 Logging Program: Open Hole: Final: Cased Hole: 7" Liner: RUN 1: DLL/MSFI_/GR RUN 2: LDT/CNL/GR RUN 3: RFT 5 - 10 points CET/CBT/GR/CCL Gyro survey from PBTD to surface CBT in 9-5/8" casing E EIVED OCT 2 9 1992 Alaska 0il & Gas Cons. Anchorage ENDICO'I-r PROPOSED DIAGI WELL 1-51/V-20 (MPI) NON-FREEZING FLUID TVD (BKB) MD (BKB) 30" DRIVE PIPE 131 FT 131 FT BASE PERMAFROST 1466 FT 1466 FT SSSV 1550 FT 1550 FT 10-3/4" 45.5#/FT NT-80LHE BTC KOP ( DIR: S 20.5° W; ANGLE' 44.4°) 2756FT 2757FT 2900FT BO'I-I'OM OF FREEZE PROTECTION (ESTIMATED) 2000 FT TOP OF 7-5/8" CEMENT (ESTIMATED) 3700 FT 4-1/2", 12.6#/FT L-80 TUBING WITH 4- 1/2" TAILPIPE 7-5/8" PACKER 9642 FT 11755 FT 5-1/2" LINER TOP 9678 FT 11805 FT 7-5/8" 29.7#/FT NT95HS NSCC 9856FT 12055FT Alask~ 011 & G~s Cons. Anchorage PLUG BACK TD 5-1/2" 17#/FT NT-80 LINER 10519 FT 12903 1=3- 12983 FT PC/9-27-92 LAND DIRECTIONAL DRILLING, ±~. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : 1-51/V-20 (P1) Field ........ : ENDICOTT MPI Computation..: MINIMUM CURVATURE Prepared ..... : 10/22/92 Section at...: S,20.48,W KB elevation.: 56.00 LEGAL DESCRIPTION X ASP ZONE 3 Y Surface ...... : 3116 FSL 2180 FEL S36 T12N R16E UM 259020.15 5982253.02 Target ....... : 2842 FSL 4216 FEL S01 TllN R16E UM 256808.33 5976767.48 BHL .......... : 2440 FSL 4366 FEL S01 TllN R16E UM 256645.24 5976370.57 PROPOSED WELL PROFILE STATION IDENTIFICATION MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 100 KB NUDGE 1.5/100 BUILD END 1.5/100 BUILD 0 0.00 0 -56 0 N 0.00 E 0 N 0 E 0.0 600 0.00 600 544 0 S 37.00 E 0 N 0 E 0.0 700 1.50 700 644 1 S 37.00 E 1 S 1 E 1.5 800 3.00 800 744 3 S 37.00 E 4 S 3 E 1.5 900 4.50 900 844 6 S 37.00 E 9 S 7 E 1.5 NUDGE 1.0/100 DROP BASE PERMAFROST 1100 4.50 1099 1043 15 S 37.00 E 22 S 17 E 0.0 1200 3.50 1199 1143 19 S 37.00 E 28 S 21 E 1.0 1300 2.50 1299 1243 21 S 37.00 E 32 S 24 E 1.0 1400 1.50 1399 1343 23 S 37.00 E 34 S 26 E 1.0 1467 0.83 1466 1410 24 S 37.00 E 36 S 27 E 1.0 END 1.0/100 DROP SURFACE CASING KOP BUILD 2.0/100 1500 0.50 1499 1443 24 S 37.00 E 36 S 27 E 1.0 1550 0.00 1549 1493 24 S 37.00 E 36 S 27 E 1.0 2757 0.00 2756 2700 24 S 20.48 W 36 S 27 E 0.0 2900 0.00 2899 2843 24 S 20.48 W 36 S 27 E 0.0 3000 2.00 2999 2943 26 S 20.48 W 38 S 27 E 2.0 3100 4.00 3098 3042 3200 6.00 3198 3142 3300 8.00 3297 3241 3400 10.00 3396 3340 3500 12.00 3494 3438 31 S 20.48 W 43 S 25 E 2.0 · 40 S 20.-48 W 51 S 22 E 2.0 52 S 20.48 W 62 S 17 E 2.0 68 S 20.48 W 77 S 12 E 2.0 87 S 20.48 W 95 S 5 E 2.0 3600 14.00 3592 3536 3700 16.00 3688 3632 3800 18.00 3784 3728 3900 20.00 3878 3822 4000 22.00 3972 3916 4100 24.00 4064 4008 4200 26.00 4154 4098 4300 28.00 4244 4188 4400 30.00 4331 275 4500 32.00 4417 4361 109 S 20.48 W 116 S 135 S 20.48 W 140 S 164 S 20.48 W 167 S 197 S 20.48 W 198 S 233 S 20.48 W 231 S 272 S 20.48 W 314 S 20.48 W 360 S 20.48 W 408 S 20.48 W 460 S 20.48 W 268 S 308 S 350 S 396 S 444 S 3 W 2.0 12 W 2.0 22 W 2.0 33 W 2.0 46 W 2.0 59 W 2.0 74 W 2.0 90 W 2.0 107 W 2.0 125 W 2.0 (GLDD (c)92 151V20 81.36 8:08 AM 2) 1-51/V-20 (P1) 10/22/92 Page 2 PROPOSED WELL PROFILE STATION IDENTIFICATION END 2.0/100 BUILD TOP TUFFS TOP HRZ BASE HRZ TOP ITKILYARIAK CASING POINT TOP KEKIKTUK TOP ZONE 3C EST GOC TARGET TOP ZONE 3B EST TOP TAR TOP ZONE 3A TOP ZONE 2B TD MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD DL/ 100 4600 34.00 4501 4445 4700 36.00 4582 4526 4800 38.00 4662 4606 4900 40.00 4740 4684 5000 42.00 4816 4760 514 S 20.48 W 495 S 144 W 2.0 571 S 20.48 W 549 S 164 W 2.0 632 S 20.48 W 605 S 185 W 2.0 694 S 20.48 W 664 S 207 W 2.0 760 S 20.48 W 725 S 230 W 2.0 5100 44.00 4889 4833 828 S 20.48 W 5121 44.41 4903 4847 843 S 20.48 W 10528 44.41 8766 8710 4627 S 20.48 W 11207 44.41 9251 9195 5102 S 20.48 W 789 S 254 W 2.0 803 S 259 W 2.0 4347 S 1583 W 0.0 4793 S 1749 W 0.0 11550 44.41 9496 9440 11550 44.41 9496 9440 1205~ 44.41 9856 9800 12124 44.41 9906 9850 12124 44.41 9906 9850 5342 S 20.48 W 5342 S 20.48 W 5694 S 20.48 W 5743 S 20.48 W 5743 S 20.48 W 5017 S 1833 W 0.0 5017 S 1833 W 0.0 5348 S 1956 W 0.0 5394 S 1974 W 0.0 5394 S 1974 W 0.0 12129 12369 12446 12670 12712 44.41 9910 9854 44.41 10081 10025 44.41 10136 10080 44.41 10296 10240 44.41 10326 10270 5747 S 20.48 W 5915 S 20.48 W 5969 S 20.48 W 6125 S 20.48 W 6155 S 20.48 W 5397 S 1975 W 0.0 5554 S 2034 W 0.0 5605 S 2052 W 0.0 5752 S 2107 W 0.0 5779 S 2118 W 0.0 12856 1298~ 44.41 10429 10373 44.41 10519 10463 6256 S 20.48 W 6344 S 20.48 W 5874 S 2153 W 0.0 5956 S 2184 W 0.0 OOT 9 !992 ~nchorage (GLDD (c)92 151V20 B1.36 8:08 AM 2) Pr, dBHOE BAY DRILblNG <KB> tBO0 ]-5]/V-20 (PI) VERTICAL SECTION VIEW 1 . ~arker Ident~ficmt~on - ' B) NUDGE !.5/100 BUILD .... . . _ , i ' ' C) MD i.5/lOO BUILD ........ ................... , D) NUDGE i.D?tO0 DRDP ..... E) BiD t.O?~00 DRDP ; F) D~FACE CASING Section at' S 20.48 N TVD Scale.' ! inch = 1200 feet Oep Scale · ! inch - i200 feet Drawn ' 10/22/92 Great Land Directional Drillin£ MD BKB SECTH INCLN 0 0 0 0 O0 600 BO0 0 0 O0 900 900 8 4 50 t!OO 1099 15 4 50 t550 i549 34 0 O0 2757 2758 24 0 O0 ! , - G) KOP 8UILO 2.0/i00 PgOO ~699 ~4 0 O0 , , ......... : ......................... H) END ~.0/100 BUILD 5i~t. 4903 843 44.4! I - : ) - - ~ I) CASING CROSS-OVER i0155 6500 4368 44.4~ · - ) t, - : ! ' - ' : i J) CASING POINT t2054 9858 5694 44.4i 4200--_.~ __. I ...._~.:._~_.: ....... ; ! ........ ----~ .................. ~--~ ...... i K) TARSET i2369 tO08!,' 59&5 44.4! 1 ' [ %. ~ t ; ! · ! ' i ' ~ ', '. ~ ' ' -i '%' i - i · '; ~. ~' ~~.,~' ,~ ' ~ ~ - ~ i ~ , - - ;. · a : :. ..... ~ . . ; i - . I . . ~ , ; . ; :. i . ; . . --- . ...... ; .............. ~ ................ ~ .......... -- ~ - · ~~-~ .... : - I%- ~ -. ~ · ~ · . ~ -..~ . ,, ~ .: % ~ . ~ · · ~. .. 9000 ......... ~ -- ' ' g600- L~ ,.-- 7 7 ~ 7 Z-.- Z7 T ~ ~ - .~ ¢ ~ · ) . I i . ~ ........ ~ ...................... ? .................... , ........ ~ ...... ~-~.~ 4- ~-, ~ ..... ~ ..... , .......... : ..... ~ .......~ .......... ;~ ~ ...... ~ ..... o 6oo izoo 18oo ~oo 3ooo ~6oo 4zoo ~8oo ~4oo 6000 6600 7zoo 7800 Section [~J3~ [.:)92. 151V20 ~t.36 7:44 4N 2!} I-51/v-2o (pi) PLAN VIEW CLOSURE ..... : 6344 ft at S 20.~3 DECLINATION.: 30.00 E SCALE ....... : I inch = 1200 feet DRANN ....... : ~0/22/g2 14arker Ident i f 1cat ton ~ N/S E/N BI ~dl]BE ~.5/tO0 BUILD 600 0 N 0 E Ci ENB ~.5/~00 BUZL~ 900 9 S 7 E DJ ~DGE ~.O/tO0 DR~ ~00 22 S t7 E EJ E~ ~.0/~00 ~OP ~550 36 S 27 E FJ ~ACE CASING 2757 36 S 27 E Gl KOP ~J~ 2.0/~00 2gO0 36 S 27 E HI E~ 2.0/tO0 ,U~ 5,~, eo3s 259~ Il CASI~,~ C.O~-OVE. ,O,~ 4,03S i492. KJ T~G~ ,2369 5554S 2034N L} ~ i~82 5956S 2i84~ PRUDHOE BAY BRILLING I I i 1 I I I I I 1200 ~,800 J. i0200 9600 .I 9000 8400 7BO0 7200 6600 6000 5400 4BO0 1 4200 3600 3000 T~RGE"]: iO~ 'FT RADIUS 2400 ~800 i200 I 1 600 <- NEST 0 600 · EAST-> FROM: GREAT LAND DIR.DRILLING 1U: 5~d'/ bb4 blSd Groat Land ~ rectional Drilling, Inc. Collision Avoidance Analysis Planned Well: 151V20P Pad: MPI Field: NSLOPE Existing Well 10/22/92 i1:13:i4 Closest Approach Sep Depth min ft TVD ft MD ft 100ft [MD's] 25ft Warning band Serious band Start End Start End 212Q16P 286 0 0 li5P25P 210 639 639 250U08P 170 0 0 266SD12P 184 0 0 224M12P 240 0 0 101J19G 275 678 678 105020G 251 744 744 109J18G 239 63 63 illSN4G 229 600 600 ll7SN2G 199 450 450 121K25G 175 618 618 125N22G 159 617 617 127P20G 144 833 833 129M25G 140 1 1 135025G 75 701 70i 137P24G 68 467 467 139P17G 60 1 1 141023G 48 628 628 143P26G 40 21 21 145Q26G 30 1 147Q21G 68 3722 3735 149P21G 10 88 88 155R25G 19 872 872 157R23G 28 379 379 163T22G 60 1 1 167T20G 41 3480 3485 169V19G 80 1497 1499 202P18G 327 576 576 204M19G 319 I 1 206J22G 311 0 0 208K16G 302 210 210 214016G 276 618 618 216M16G 270 218L16G 262 588 588 220L15G 255 0 0 222L14G 247 617 617 226N14G 233 1 1 228P19G 226 595 595 230009G 220 0 0 2325N3G 213 S96 596 234P14G 204 618 618 236014G lg8 496 496 238SN1G 181 574 574 242Pi3G 177 454 454 244R12G 174 570 570 246Q15G 171 426 426 252S14G 169 598 598 254Q12G 170 38 38 258S09G 173 1 1 262Q17G 176 230 230 ~64U10G 179 596 596 268S17G 187 611 611 270U15G 192 274 274 0 3212 1 1175 1 1495 0 3312 1 2491 1 3547 1 3292 3987 1 3511 1 3911 1 1398 1 1232 1 3900 0 2061 1649 930 1092 1-51/V-20 (MPI) Casing Design Specifications SURFACE CASING 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 3130 PBYS (#) 1040000 TJYS (#) 1097000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 1 4 2700 1 966 Burst S.F. 2.65 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2700 1334 Collapse S.F. 2.35 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3571 PBYS Tension S.F. 7.49 Mud Wt, 9.5 ppg TJYS 7.90 String Wt. (#) 138888 RE :E VE OCT z? 9 !992 Aiask~ 0il & Gas Cons. Commission Anchorage 1-51/V-20 (MPi) Casing Design Specifications Intermediate Casing 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 8 0 71 5 0 PBYS (Cf) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SF1-P 3900 Burst S.F. 2.10 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg G as Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 9850 0.1 4239 Collapse S.F. 1.69 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 12O55 PBYS Tension S.F. 2.68 Mud Wt. 10.2 TJYS 2.78 String Wt. (#) 302216 Gas Cons. Oorm-cdssiOn Anchorage 1-51/V-20 (MPI) Casing Design Specifications PRODUCTION LINER 5-1/2", 17#/ft, NT-80 FL4S Casing GRADE BURST COLLAPSE NT-80 7740 6280 PBYS (#) 397000 TJYS (#) 446000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SITP Fluid wt (ppg) 3420 9.4 Burst S.F. 2.33 back up (ppg) Burst Pressure 9.6 3328 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 9850 0.1 3932 Collapse S.F. 1.60 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (F-T) Mud Wt. String Wt. (#) 1 7 1178 9.6 16904 Tension S.F. PBYS TJYS 23.49 26.38 36 TH _~ ; ~.' NEC ~'IOH © '® 36 q5 © 47 0 · 51490 O. · 53. O ,575'~© 615900 656~)© 67 0 RECEIVED Aiaska Oil & g.'~,.:; Ool]s. Anchorage N 0 res ' 56 CERTIFICATE OF SURVEYOR I hearby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents an proposed iocation for the 'Well numbers shown above. All surveying was done by me or under my supervision, and that all dimensions and details are correct. DRW. 116-85 SHEET 2_ of I0 REV. 0 Indicates well Indicates Calc;Jlated Section Corner Position Indicates Perpendicular Offset Distance Indicates Perpendicular Offset Distance perpendicular distance varies tar each well PLAT OF MPI PROPOSED WELL LOCATIONS LOCATED IN SEC. 56, T. IZ N., R. 16 E. UNIAT N. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY F.R. BELL 8, ASSOC, ' PRUDHOE BA_Y OFFICE ~RUDHOE BA'Y, ALASKA DATE' NOV- I~, 1985 _ SCALE' I'''= 60' DRAWN BY: R.G.T. CHECKED BY' B.E. "#EL6:'; ABP ZONE ;)'. UtM ZONE 6 LATITUDE LONBITUDE DIGT . .. , . ~ - _. '~::~ Y= 5982482~7· :N- 7805524.'5I .70o21'10.0670,'~ 147°57'20.4660"-~ ..1928.40 2¢2~.&~" X- 2~I~0,7~ E-~~ 2 Y- 598257~.88 N-;7805~5~.'52 70°2I't0.'981~" 147°57'24.6257" 18~5.4~ 2168,94 X= 259~75.01 E"'~ 464%55,65 ~- 4 Y= 5982571.69 N= ~7805550~99' 70°21'10.B991" 147057'24.7856" 1845.80 2174.4t 5 Y= 5982465.99 N='=TB05519.4b 70°2t '09. 9025" 147°5'7'20.7857" 1945. i5 X= 25~t~.27 E=. 4~4155.~5 6 Y= 5982565.50 N=~7805548.47 70e2i '10.8168" 147°57'24.9454" 1852.17 2t79.88 X= 25~050.02 E% 4640~1.04 . 7 Y" 5982457.80 N=~780551~.94 70°21"09.8200" 147°57'20.9455" 1955.52 2045.06 .. X- 2591~5.54 E-i~ 4641~2.24 8 Y- 5982555.50 N=...7805545.94 70o2~"10.7544" ~47o57'25.105~" 18~0.54 2185.~5 X= 259024.29 E=;j 464089.55 9 Y= 5~82449.~'1 N=~7805514.41 70°21'09.757~" 147°57'21.J054" 1961.89 2048.55 l0 Y= 5~82547.11 N=~7805545.42 70o21'10.~521" 147o57'25.2~5~" ~8~8.91 X= 25~0t8.55 E¢i.- 4~4.087.~2 11 Y= 5982441.42 N=?7805JII.89 70o21'09.~555" 147o57'21.2655" 1970.26 2054.00 ~= 25~152.07 E=.;: 464t28.85 12 Y= 5982558.92 N=..7805540.90 70°21'10.5~97" 147°57'25.4250'' 1877.28 ~ 2196.50 X= 259012.82 E= 464085.92 I 15 Y: 5982455,25 N: 7805509.56 70021'09.5750" 147°57'21.4251" 1978.65j2059.47 I X= 259146.55 E= 464127.12 14 Y= 5982550.75 N=' 7805558.57 70°21'10.4874" 147057'25.5849" 1885.66 2201.77 X= 259007,0B E= 464084-21 15 Y= 5982425.05 N= 7805506.84 70°21'09.4906'' 147°57'21.5850" 1987.00 2064.94 -',¢ "' X= .... 259140.60 ~ 464125~-42', .... ?~:':...::,,:'-::~;'::r:~:';:,:~-::.:;"-:: .... ,; ...... '.' '" .... · · '" ..... :'~:;'"",'..:.-' 16 Y= 5982522.54 N=' 7805555.85 70°21'10.4051" 147°57'25,7447'' 1894.05 2207,24 I X= 259154,86 E= 464125,71 I I X= 2591'29.15 E=;~ 464122.00 J. 20 Y= 5982506.16 N=J 7805550.80 70°21'10.2404" 147057'26.0644" 1910.77 2218.18 X= 258989.87 E=; 464079.09 21 Y= 5982400.46 J N='7805299.27 70°21'09.2456" J 147°57'22.0646'' 2012.12 2081.56 ., X= 259125.59J E=i 464120.50 I' I ~-..¢~- ..,,4_~1~ LOCATED ~N S~C. ;~,T.~ZN.,R.~E. U,~AT F~ ~ 'r ~ . %~ fro' L/bi & ~ ~¢~ P RE PAR ED FOR F .49~~'',, ~ _~,,..r~' "~Cons.~omm~ssog -~ ~~~~~ ~~.~~-~~~%~'""~"--'--~"~~" ~' Anchorage SOHIO ALASKA PETROLEUM CO. J ..~. ~. ... ~ DRW. NO. 116-85 PREPARED BY DATE:NOV. 15, 1985 ~"~¢~'"-~;~ ~ ¢ ........ F.R. BELL &ASSOC. ~J-~¢~o~vn~L~, ~ ~ . SHE ET ~ Of ~U SCALE ' N/A ~%~~ ~ P RU DHOE BAY OFFICE ~DRAWN BY: ' REV. O PRUDHOE BAY~ALASKA _ · iCHECKED BYt B.E. I , I I I I I HELL ASP ZONE 3 UTM ZONE 6 LATI-TLLDE LDNBITi.I~E' DI X= -25~045.,0~ E= 46409~.4~ 44 Y- 5982~B~,29 N= 7B05292,~ 70o2['0~,0054' t47°57'28,462~" 20~,~6 230'0,26 X= 25~03,~4 E= .46405~,50 45' Y' 5982277,59 N= 7805261.'40 70o21'0B.'0086" 147°57'24,~625"' 21~,7.70 2163'~4~' X= 2590~7,36 E= 464094,7~ - '46 Y= 5982~75,10 N= 7805290,41- 70o21'08.9250" 147°57'28,6221" 2044,75 2~05,7~ X= 258898,1i E= 464051.79 47 Y= 5982269,40 N= 7805258,8~ 70o21'07,9263" 147057'24,6223" 2146,07 2168.91 X= 2590~1.62 E= 464092.99 ,, ,, 4B Y~ 5982~66.91. N= 7805287.89 70o21'08.8407" 147°57'28.7~20"' 20'5~.10 2311.20 ~= 258892.~7 E= 464050.08 49 Y= 5982261.21 N= 7805256.35 70o21"07.8459" 147o57'24.7B22" · 2154.44 2174.3B x= 259025. B9 E= 464091.29 ~ 50 Y= 5982~58.71 N= 78052B5.~ 70o21"b8.7584" I47°57'28.9418" '2061.47 2~16.6~ x= 2588~6.6~ E= 464048. ~8 51 Y= 598225~.02 N= 780525~.B3 70o21'07.7616" 147o57'24.9420" '2162.81 2179.B~ : ..... x= 259020. ~5 E= 464089.58 ........ ~' '. .... 52 Y= 59~2~50.52 N= 78052~2.84 70021'08.6760" 'i47o57'29.1017" 2069.85 2~22.14 x= 258880.90 E= 464046.67 5~ Y= 5982244.8~ N= 7~05251.~1 70°21'07.6793" 147°57'25.1019" 2171.19 2185.~S x= ,259014.41 E= 4640~7.SS 54 Y= 59S2~42.~ N= 7805280.~1 70021"08.5937'' 147o57'29.2615" 207B.22 2S27.62 ~= 258S75.16 E= 464044.96 55 Y= 59822S6.64 N= 780524S.7S 70o21'07.5969." 147o57'25.2617" 2179.56 2190.80 x= 25900~. 6~ E= 4~4086.17 56 Y= 59823~4.14 N= 7805277.79 70o21'08.5113'' 147°57'29.4214" 2086.59 2~3.0~ X= 25886?. 45 E= 464043.26 57 Y= 5982228.44 N= 7805246.26 70o21'07.5146" 147°57'25.4216" 2187.~5 2196.27 X= 258865.69 E= 464041.55 59 ~Y= 5982220.25 ~ N= 7805245.75 70021'07.4525'' 147°57'25.5814'' 2196.50 2201.74 iX= 258997 21 ,~ E= 464082 76 60 Y= 5982~17.76 N= 7805272.74 70021'08.5467'' 147°57'29.7411" 2105.55 2544.05 X= 258857.96 E= 464039.85 61 Y= 5982212.06 N= 7805241.21 70o21'07.~4~9'' 147°57'25.7415'' 2204.67 2207.21 X= 258991.47 E= 464081.05 62 Y= 5982309.57 N= 7805270.22 70°21'08.264~'' 147057'29.900?" 2111.71 2~49.50 X= 258852.22 E= 464038. 14 63 Y= 598220~.87 N= 7805258.69 70o21'07.2676" 147o57'25.9011" 221'3.05 2212.69 X= 258985.74 [ E= 464079.~4 ~~ ,~,, ~_ I LOCATED IN SEC. 56,T. 12N.,R. IGE. UMIAT M. '~~~ ~ PRUDHOE BAY OFFICE DRAWN BY : R~.I REV. O- PRUDHOE ~Y~ALAS.~ CHECKED BY: B.E- i_ i i i i i _ IIELL ASP ZONE 3 UTI~ ZONE & LATITUDE LONSITUDE DIST~ DIBT(~ . . 64 Y= 5~82301.3~ 'fl- 780~267.6~ 70o21'08,1820' 147°~7'30.0608' 2120,08 2354.97 . , X- 258846,48 E- 464056.45 -- 65 Y- ~821~5.6B N- 78052~6,16 70o21'07.1852" 147°~7'26,0610" 2221.43 22~8.16 X- 2~8980,00 E- 464077,64 - 66 Y- 5~822q~,18 N- 7B05265,17 70o21'08,09~7" 147°57'~0,2206" 212B.4~ 2360.45 X= 25B840.75 E= 464034,73 -- 67- Y= 5~B2187.4~ N: 7805253.64 70o21'07.1029'' 147o57'2~,220B'' 2229.80 2223.63 X= 258974.26 E= 464075.93 ~ 68 Y= 5~B2284.~9 N= 7805262,64 70o21'08,017~'' 147o57'30.~805" 2136.B2 2365.92 X- 2588~5.01 E= 464033.02 69 Y-'5~8217~.~0 N~ 78052~1,11 70021'07.0206" 147o57'26.~B07" 22~B,17 222~.I0 X- 258968,53 E- 464074,23 70 Y- 5~82276.80 N- 7805260,12 70o21'07,~350" J'147o57'~0.540~" 2145.19 2~71.3~ X- 25882~,28 E~ 46403~,~ 1 ................. . . . , ::.- ....1 . . -.~...- . .,-.. . . ~PI P~O~SED WEUL LOC~TION UIST 4/h, u~,~9~9~ ~oc~o,,sEc.~,~.,z~.,~.,~.u~,~. · .~ 2".~~sk~ O~i & ~as Cons. ~ommission ~*/49~~ ,~.,~ Anchorage ~R~ ~,R~O ~'"~'"'-~"'~'--a SOHIO ALASKA PETROLEUM CO. '~ ~ ~ 6717~ ~'~ DRW. NO. li6-85 PREPARED BY DATE: NOV.[3, 1985 ~i~a-~- -~~ F.R BELL & ASSOC ~ ~_~-~-,~- ~ SHEET 6 of I0 · · SCALE : N/A ~E~L~ P R U DHOE BAY OF FICE ~ ~~~ DRAWN BY' R.G~. _ R~. o PRUDHOE BAY, ALASKA CHECKED BY: · i i i id i ii i r i i ii I ENDICO'I MP! 1-51/V-20 CEMEN' PROGRAM 10 3/4" SURFACE CASING CASING SIZE' 10-3/4", 45.5# CIRC, TEMP; 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD'2.17 ft3/sx APPROX #SACKS- 660 . PUMP TIME' 4:30 hrs MIX WATER' 11.63 gps FW Mix water temp' 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD-l.16 ft3/sx APPROX #SACKS: 250 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD'0.94 ft3/sx MIX WATER' 3.5 gps FW APPROX #SACKS: 250 PUMP TIME' 2:30 hrs Mix water temp' 50-65 F ~ 100 bbls fresh Water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. Lead slurry to surface w/40% excess. 2. Tail slurry volume 250 sx 3. Top job volume +/- 250 sx. 7 5/8" INTERMEDIATE CASING CASING SIZE; 7 5/8", 29.7# CIRC. TEMP 135°F LEAD CEMENT TYPE' Class 'G' WEIGHT: 12.0 ppg APPROX #SACKS' 490 TAIL CEMENT TYPE: CLASS G WEIGHT: .15.8 ppg APPROX #SACKS: 200 YIELD:3.24 ft3/sx PUMP TIME' 4:30 hrs YIELD'1.15 ft3/sx PUMP TIME: 4 hrs MIX WATER' 11.63 gps FW Mix water temp' 50~65F MIX WATER: 5.00 gps FW Mix water temp: 70-80 F SPACERS: Pump 20 bbls ARCO Preflush; 50 bbls ARCO spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix lead and tail slurries. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry is designed to cover Cretaceous injection interval. 2. Tail Slurry to 500' MD above shoe w/30% excess. 5-1/2" LINER CASING SIZE' 5-1/2°', 17# CIRC. TEMP: 135° F CEMENT TYPE: CLASS G WEIGHT: 15.8 ppg APPROX #SACKS- 250 Mix water temp' 70-80 YIELD'I.20 ft3/sx MIX WATER' 5.0 gps PUMP TIME: 3:30 hrs + 1 hr mixing @surface F PREFLUSH' 20 bbls ARCO preflush SPACER: 50 bbls ARCO spacer weighted to 11 ppg OTHER CONSIDERATIONS' Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME Calculated volume+ 100% excess. ~.. ~! C ~IV ~ ~ Alaska. Oil & Gas Cons. Anchorage ENDICO'I MPI 1-51/V-20 CEMEN', PROGRAM 10 3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 60°F LEAD. CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 660 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD:l.16 ft3/sx APPROX #SACKS: 250 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps FW APPROX #SACKS: 250 PUMP TIME: 2:30 hrs Mix water temp: 50-65 F - ~ SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. Lead slurry to surface w/40% excess. 2. Tail slurry volume 250 sx 3. Top job volume +/- 250 sx. 7 5/8" INTERMEDIATE CASING CASING SIZE: 7 5/8", 29.7# CIRC. TEMP 135°F I,.EAD CEMENT TYPE: Class 'G' WEIGHT: 12.0 ppg APPROX #SACKS: 490 YIELD:3.24 ft3/sx PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G WEIGHT: 15.8 ppg APPROX #SACKS: 200 YIELD:1.15 ft3/sx PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 70-80 F SPACERS: Pump 20 bbls ARCO Preflush; 50 bbls ARCO spacer @ 11 ppg. OTHER CON,C;IDERATIONS: Continuously mix lead and tail slurries. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry is designed to cover Cretaceous injection interval. 2. Tail Slurry to 500' MD above shoe w/30% excess. 5-1/2" LINER CASING SIZE: 5-1/2", 17# CIRC. TEMP: 135° F CEMENT TYPE: CLASS G · WEIGHT: 15.8 ppg APPROX #SACKS: 250 Mix water temp: 70-80 YIELD'I.20 ft3/sx MIX WATER: 5.0 gps PUMP TIME: 3:30 hrs + 1 hr mixing @surface F PREFLUSH: 20 bbls ARCO preflush SPACER: 50 bbls ARCO spacer weighted to 11 ppg OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME Calculated volume+ 100% excess. Alaska Oil & Gas Cons, Anchorage State: Alaska Borough: Well: 1-5i / V-20 Field: Endicott St. Perm ~ 92-119 Pa~ 1 .... - Date 11/23/92 Engr: M. Minder DIUV-20.XLS Casing Interval Interval Size Boffom Top Length 1A 10.75 2756 35 2757 2A 7.625 9856 35 12055 3A 5.5 10519 9687 1178 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description D e~criptionTension Lbs Grade Thread Lbs 4~.5 NTBOLHE BTC 0 29.7 NT95HS NSCC 0 17 NT-80 FL4S 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/fi 1B 9.5 0.494 2B 10.2 0.530 8B 9.6 0.499 4B 0.0 0.000 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 88 0.0 0.000 9B 0.0 0.000 10B 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF 3900 5210 1.3 3900 8180 2.1 3900 7740 2.0 0 0 #DlVl0! 0 0 #DlVl0! o o #DN/0! 0 0 #DIV/0! 0 0 #DN/0! 0 0 #DiVI0! 0 0 #DN/0! Tension Strength K/Lbs 1C 125.4435 2C 858.0335 3C 20.026 40 0 5C 0 6C 0 7C 0 80 0 9C 0 i0C 0 K/Lbs TDF 1040 8.29 8110 22.65 3970 198.24 0 #DIV/O! 0 #DN/O! o #DiV/0; 0 #DIV/O! 0 #DIV/O! 0 #DN/0! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 1361 313O Z.Z99 5229 715O 1.368 5251 6280 1.196 0 0 #DN./0! 0 0 #DIV/O! 0 0 #DN/0! 0 0 #DrVi0! 0 0 #DrVI0! 0 0 #DIVI0! 0 0 ! ~7~'7 ! __ ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE [~thru 8]" . "]]~ thru' 1'3} 10. 11. [10 & 13] 12.. 13. E14 thru 22] 15. (5) BOPE [23 thru 28] Company Lease & Well YES NO 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is well bore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26.. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed .... Is administrative approval needed. Is lease n~rnber appropriate .......................................... Does well have a unique n~..e & n~nber ................................ Is conductor string provided ......................................... ~ .. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ~ .. Will all casing give adequate safety in collapse, tension, and burst. /~( Is well to be kicked off from an existing wellbore ................... ~ Is old wellbore.abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of-C_.~'--~.::3 BOPE attached .... /~ ... Does BOPE have sufficient pressure rating -- test to~O~O~sig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... ~ REMARKS Other E29 thru '31} (7) Contact /~/z/~ 29. 30. 31. 32. 33. rev 08/18/92 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data ~presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions D~esented... Name and phone n~nber' of contact to supply weekly progress data ...... Additional POOL requirements ............................................. ~ ~.'s ,l~l=-/J~,.,i~l<.--,.~/-rPclr C./ ~ . ~ , i, ' ' ' ~,/,.~ ........... - .~.c.~ ~li~e~ ~ ~ ~p~,~, ol. Additional remarks:/ CLASS STATUS AREA ~ SHORE l-&l,./u -.zo Well Histo,ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ., No special'effort has been made to chronologically organize this category of information. Run 1' 22 - April - 1993 CN/OR Cased Hole 9944 2690 ~'ape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1-51/V-20 MPI 500292230400 BP EXPLORATION (ALASKA) INC ATLAS WIRELINE SERVICES 18-JUN-93 5937.00 R. ECK G. HOBBS 36 12N 16E 2163 2180 56.00 10.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.875 7.625 12137.0 PRODUCTION STRING 6.750 5.500 12741.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS 2435 GRCH 1 22-APR-93 ATLAS WIRELINE SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: CN/GR Cased Hole. EQUIVALENT UNSHIFTED DEPTH 29.70 17.00 DATA FROM 5.5" & 7.625" CASING PASSES WAS MERGED TO- GETHER TO FORM ONE CONTINUOUS DATA SET FROM TOP- LOG-INTERVAL TO T.D. THE PASSES WERE SPLICED TO- GETHER @ 11830'. GAMMA RAY FROM THE MERGED PASS IS THE DEPTH REFERENCE FOR THIS WELL. 7-5/8" CASING LEAD CEMENT TYPE IS PREMIUM, ADDITIVES WERE: 0.5% CFR-3 3.0% ECONOLITE 0.4% HALAD-344 APPROX. 650 SACKS. 5-1/2" CASING LEAD CEMENT TYPE IS PREMIUM, ADDITIVES WERE: 0.2% CFR-3 2.0% KCL 0.9% LAP-1 0.3% ECONOLITE 0.4% HALAD-344 0.01 GPS STABILIZER 434B 0.01 GPS D-AIR 3 HR-5 APPROX. 250 SACKS. CN LOGGED IN COMBINATION WITH SBT. GR ANOMALLY AT 12429' WAS DUE TO NEUTRON ACTIVATION WHILE STOPPED IN HOLE AFTER REPEAT. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9945.0 2435 9993.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 3 BASELINE DEPTH NPHI 9935.0 9935.0 10010.0 10009.5 10049.0 10049.0 10057.0 10057.0 10078.0 10078.0 10088.0 10088.5 10127.5 10127.5 10206.5 10206.5 10257.0 10257.5 10284.5 10285.0 10324.0 10323.5 10414.0 10413.5 10417.0 10417.5 10425.5 10425.5 10439.5 10439.0 10479.0 10479.0 10629.0 10630.0 10638.5 10639.0 10648.5 10648.0 10674.5 10674.0 10706.5 10705.5 10741.0 10741.5 10746.5 10748.0 10750.0 10751.0 10752.5 10753.5 10773.5 10774.0 10785.0 10785.0 10792.5 10792.0 10837.0 10838.0 10843.5 10845.0 10854.5 10855.0 10912.5 10912.5 10987.0 10987.0 11064.0 11064.5 11072.0 11072.0 11103.5 11103.5 11130.0 11130.0 11159.5 11159.5 11180.5 11181.0 for each pass in separate STOP DEPTH 12684.0 12690.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- files. 11185.5 11202.0 11213.5 11235.5 11260.5 11285.5 11339.0 11345.0 11392.0 11414.5 11472.5 11503.5 11507.0 11523.0 11532.5 11568.5 11642.5 11649.5 11652.5 11661.5 11680.5 11692.5 11725.0 11731.0 11762.0 11816.0 11912.5 11920.0 11958.0 11965.5 11969.5 11987.0 11995.5 12100.0 12169.5 12178.0 12183.5 12196.0 12203.0 12211.5 12237.5 12255.5 12293.5 12312.0 12344.5 12364.5 12374.0 12411.5 12449.0 12479.0 12622.0 12650.5 12741.0 $ REFaIRK S: 11185.5 11202.5 11213.5 11235.5 11260.5 11285.5 11338.5 11345.0 11392.5 11415.5 11472.5 11502.5 11506.0 11523.5 11533.0 11568.5 11643.0 11649.5 11654.0 11660.0 11680.5 11692.5 11725.5 11730.0 11762.0 11816.0 11912.5 11920.0 11958.5 11966.5 11970.0 11986.5 11995.0 12100.0 12169.0 12178.0 12184.0 12196.0 12202.5 12211.5 12237.0 12255.5 12293.5 12312.0 12345.0 12364.5 12374.0 12411.5 12449.5 12479.0 12622.0 12650.5 12741.0 MERGED MAIN PASS. DATA FROM 5.5" & 7.625" CASING PASSES WAS MERGED TO- GETHER TO FORM ONE CONTINUOUS DATA SET FROM TOP- LOG-INTERVAL TO T.D. THE PASSES WERE SPLICED TO- GETHER @ 11830'. CN WN FN COUN STAT FUCT & NUCT WERE SHIFTED WITH NPHI. $ : BP EXPLORATION : 1-51/V-20 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 113 Tape File Start Depth = 12741.000000 Tape File End Depth = 9935.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28066 datums Tape Subfile: 2 316 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9944.0 2435 9993.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR CN KNJT KNJT ACC CENT SBT CENT VDL CENT $ STOP DEPTH 11838.0 11844.0 CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT ACOUSTIC COMMON CENTROLLER WTS SEGMENTED BOND TOOL CENTROLLER WTS VDL SUB CENTROLLER WTS 22-APR-93 FSYS REV. J001 VER. 1.1 2202 22-APR-93 12741.0 12729.0 10000.0 12721.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 2435XA 392 iNA 392 INA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 12741.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 8.60 0.0 187.0 0 0.0 0.000 0. 000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 0.00 9.875 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): 0.0 REMARKS: MAIN PASS (UPPER) 7.625" CASING. BIT SIZE WAS 9.875" DOWN TO 12243' & 6.75" FROM THERE TO TD. NEUTRON WAS CASING CORRECTED: CASING THICKNESS = 0.38" CEMENT THICKNESS = 1.13" CHISM FILTERING WAS NOT ACTIVE. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-51/V-20 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 SPD 2435 68 1 F/MN 4 7 CCL 2435 68 1 4 8 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 90 640 78 6 4 19 912 29 5 32 * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 281 Tape File Start Depth = 11895.000000 Tape File End Depth = 9935.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70570 datums Tape Subfile: 3 369 records... Minimum record length: 42 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0. 2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11779.0 2435 11828.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR CN KNJT KNJT ACC CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT ACOUSTIC COMMON CENTROLLER WTS SEGMENTED BOND TOOL CENTROLLER WTS VDL SUB CENTROLLER WTS STOP DEPTH 12684.0 12690.0 22-APR-93 FSYS REV. J001 VER. 1.1 2114 22-APR-93 12741.0 12729.0 10000.0 12721.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 2435XA 3921NA 3921NA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 12741.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 8.60 0.0 187.0 0 0.0 O.O00 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 0.00 9.875 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN) : 0.0 REMARKS: MAIN PASS (LOWER) 5.5" CASING. NEUTRON HOLE CORRECTION: 9.875" from 11766 - 12245' 6.75 " from 12245 - 12741'. NEUTRON WAS CASING CORRECTED: CASING THICKNESS = 0.30" CEMENT THICKNESS = 2.19" from 11766 - 12245' CEMENT THICKNESS = 0.63" from 12245 - 12741'. CHISM FILTERING WAS NOT ACTIVE. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-51/V-20 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 SPD 2435 68 1 F/MN 4 7 CCL 2435 68 1 4 8 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 90 640 78 6 4 19 912 29 5 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 140 Tape File Start Depth = 12741.000000 Tape File End Depth = 11765.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63212 datums Tape Subfile: 4 229 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0. 2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12434.0 2435 12483.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) : STOP DEPTH 12682.0 12688.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR CN KNJT KNJT ACC CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT ACOUSTIC COMMON CENTROLLER WTS SEGMENTED BOND TOOL CENTROLLERWTS VDL SUB CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 22-APR-93 FSYS REV. J001 VER. 1.1 2053 22-APR-93 12741.0 1272~.0 10000.0 12721.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 2435XA 3921NA 3921NA 1633EA 1424XA 1424PA 6.750 12741.0 0.0 BRINE 8.60 0.0 187.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 0.00 6.750 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS. NEUTRON WAS CASING CORRECTED: CASING THICKNESS = 0.30" CEMENT THICKNESS = 0.63" CHISM FILTERING WAS NOT ACTIVE. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-51/V-20 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 SPD 2435 68 1 F/MN 4 7 CCL 2435 68 1 4 8 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 90 640 78 6 4 19 912 29 5 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 46 Tape File Start Depth = 12739.000000 Tape File End Depth = 12419.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82100 datums Tape Subfile: 5 132 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 93/ 6/18 01 **** REEL TRAILER **** 93/ 6/20 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 20 JUN 93 9:02p Elapsed execution time = 44.76 seconds. SYSTEM RETURN CODE = 0