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Home My WebLink About197-057MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-49A DUCK IS UNIT SDI 3-49A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 3-49A 50-029-21735-02-00 197-057-0 W SPT 9712 1970570 2428 2120 2113 2090 2095 55 259 260 257 REQVAR P Kam StJohn 8/6/2025 2 Year MIT-IA as per AIO 1.013 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 SDI 3-49A Inspection Date: Tubing OA Packer Depth 725 2700 2673 2663IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250806142823 BBL Pumped:4.6 BBL Returned:4.6 Monday, September 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 29, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-49A DUCK IS UNIT SDI 3-49A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/29/2023 3-49A 50-029-21735-02-00 197-057-0 W SPT 9712 1970570 2428 2155 2131 2157 2172 94 300 300 295 REQVAR P Bob Noble 8/5/2023 AIO 1.013. MIT-IA to max injection pressure every 2 years. 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 SDI 3-49A Inspection Date: Tubing OA Packer Depth 827 2800 2754 2744IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230810142609 BBL Pumped:4.5 BBL Returned:4.3 Friday, September 29, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 1.013. James B. Regg Digitally signed by James B. Regg Date: 2023.09.29 13:15:52 -08'00' MEMORANDUM TO: Jim ReggI ll P.I. Supervisor � FROM: Brian Bixby Petroleum Inspector gI317- Zq NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 3-49A DUCK IS UNIT SDI 3-49A Sre: Inspector Reviewed By: - P.I. Supry �1 Comm Well Name DUCK IS UNIT SDI 3-49A API Well Number 50-029-21735-02-00 Inspector Name: Brian Bixby Permit Number: 197-057-0 Inspection Date: 8/20/2021 Insp Num: mitBDB210820145812 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3 49A - Type Inj FWTTVD 9712 Tubing 2153 - 2091 - 2086 2oao - PTD 1970570 Type Test SP'r Test psi 2428 IA 1247 1 2712 2692 ' 2687' BBL Pumped: 3.3 BBL Returned: 3.4 OA 120 280 280 280 Interval REQVAR P/F P ✓ Notes' 2 Year MITIA as per AIO 1.013 Monday, August 23, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, August21, 2019 P.I. Supervisor J�'2 q ZiliG' I SUBJECT: Mechanical Integrity Tests (t Hilcop Alaska LLC 3-49A FROM: Bob Noble DUCK IS UNIT SDI 3-49A Petroleum Inspector Ste: Inspector Reviewed By: P.1. Supry P NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-49A Insp Num: mitRCN190820152113 Rel Insp Num: API Well Number 50-029-21735-02-00 Inspector Name: Bob Noble Permit Number: 197-057-0 Inspection Date: 8/20/2019 Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well 349A _ Type Inj W 'ITVD 9717 •Tubing 2203 zzzu zno 119, PTD 970570 .-- P Testl SPT `Test psi z3oo IA 2026 2402 2397 • z,o: OA alz 4so a4e aBBL Pumped: 4s Interval REQVAR IP/F P -J �— Notes: AID 1.013. MIT -IA every 2 years to the max injection pressure of 2300 psi. Dan told me that he had pre tested this well the day before and left pressure some on the IA so they kept the LA loaded. I watched it for 15 min to make use it was not moving. Wednesday, August 21, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 25,2017 TO: Jim Regg P.I.Supervisor "Ne p WI 7-7(t SUBJECT: Mechanical Integrity Tests ( l HILCORP ALASKA LLC 3-49A FROM: Jeff Jones DUCK IS UNIT SDI 3-49A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-49A API Well Number 50-029-21735-02-00 Inspector Name: Jeff Jones Permit Number: 197-057-0 Inspection Date: 10/22/2017 Insp Num: mitJJ171025085147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 3-49A Type Inj I W 'TVD 9712 - Tubing 2122 - 2079 - 2099 - 2104 - 2104 - 2133 PTD 1970570 '1Type Test SPT Test psi 3000 IA 1233 3306 - 3298 - 3290 - 3278 - 3268 - BBL Pumped: 4.8 - BBL Returned: i 4.5 - OA 420 640 - 640 - 630- 630- 620 _ Interval REQVAR P/F L P Notes: 2 year MI-IA to Max.anticipated injection pressure.AIO 1.013. 1 well inspected,no exceptions noted. SCANNED FEB 2 0 'u Wednesday,October 25,2017 Page 1 of 1 i S Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, October 4, 2017 9:23 AM To: Wallace, Chris D (DOA);Alaska NS - Endicott - Operations Leads Cc: Taylor Wellman; Regg,James B (DOA); Larry McBride; Kendal Vassen; Darci Homer- (C) Subject: Injector END 3-49A (PTD# 1970570) Ready For Injection All, Endicott injector END 3-49A(PTD# 1970570)operates under AIO 1.013 for water only injection. The well has been shut in for reservoir management and is out of its two year MIT interval.The well had a passing pre MIT-IA on 10/3/2017 and there are no known integrity issues. Well is ready to return to injection for stabilization and compliance testing. Once on injection,the well will return to monthly TIO reporting as per the AIO and be removed from the Quarterly LTSI Injector Report. Plan Forward -Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska, LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 SCANNED ' 4 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday,August 22, 2017 4:24 PM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA);Taylor Wellman; Kendal Vassen Subject: Shut-In Injector END 3-49A(PTD# 1970570) Due for AOGCC MIT-IA All, Long term shut-in Endicott water injector END 3-49A(PTD#1970570) is due for an AOGCC witnessed MIT-IA in August 2017. The well has been shut in for reservoir management since September 2014 and is expected to remain shut- in. The well will be added to the Quarterly North Slope LTSI Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC. 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG 3 t 2017, i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,August 26,2015 P.I.Supervisor �� 1 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-49A/M40 FROM: Chuck Scheve DUCK IS UNIT SDI 3-49A/M40 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-49A/M40 API Well Number 50-029-21735-02-00 Inspector Name: Chuck Scheve Permit Number: 197-057-0 Inspection Date: 8/21/2015 Insp Num: mitCS150822055710 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 3-49A/M40 Type Inj N 'TVD 9712 Tubing} 2280 - 2300 - 2250 - 2250 - PTD 1 1970570 ' rType Testi SPT Test psi 3000 - Ip 400 - 3015 - 3001 - 2996 Interval REQVAR PIFI---- P ✓ OA I 0 0 j 0 0 Notes: Tested per AIO 1.013 SCANNR) Wednesday,August 26,2015 Page 1 of 1 • 1 ti R EC t ry.. Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 201i 3800 Centerpoint Drive Suite 100 A A Anchorage,AK 99503 (l.•+�i(V' Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 7 Anchorage, AK 995014q A �� O 3' ao l k Re: Duck Island Unit Well Renaming Request 5CAW4E2 SE.p °I 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 "I" 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 I API_WeIINo I PermitNumberl WeliName WellNumber WeilNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/J40 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/028 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 07,2013 TO: Jim Regg Sf I 3 P.I.Supervisor $'7 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC 3-49A/M40 FROM: Jeff Turkington DUCK IS UNIT SDI 3-49A/M40 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J '- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-49A/M40 API Well Number 50-029-21735-02-00 Inspector Name: Jeff Turkington Permit Number: 197-057-0 Inspection Date: 5/2/2013 Insp Num: mitJAT130502155327 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min • Well 3-49A/M40 Typ e In j i. -,TVD IA � 3045 3034 3035 PTD 1970570 T ype Test SPT Test psi; 2500 I OA - 411 39' 1 392 ' Interval REQVAR P/F P / Tubin g 2291 2274 ' 2284 j i { I 2281 , Notes: AA AIO 1.013;slow T x IA,PWI only,6.2 BBL to fill SCATHED FEB 2 0 2014 Tuesday,May 07,2013 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg ICIT°57 i n Alaska Oil and Gas Conservat Commission o C /� 333 West 7 Avenue EN P 4� / ' � ~ T° Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 3 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 alternate, Gerald Murphy, at 659 -5102. Sincerely, 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 3 Date: 10/03/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END3 -01 / N -29 1861900 50029216780000 7.0 4.4 0.3 9/6/2010 1.70 10/3/2010 END3 -03 / J -33 1921210 50029223060000 8.0 6.1 0.3 9/6/2010 2.55 10/3/2010 END3 -05 / 0 -29 1861300 50029216240000 3.0 2.0 0.5 9/6/2010 3.40 10/3/2010 END3 -07A / L -29 1981470 50029219110100 2.0 0.5 0.3 9/6/2010 1.70 10/3/2010 END3 -09 / L -28A 1950190 50029217800100 0.1 NA _ 0.1 NA 1.00 10/3/2010 END3 -15 / K -33 1870940 50029217510000 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -17F / K -30 2032160 50029219460600 1.5 0.5 0.5 9/6/2010 2.55 10/3/2010 END3 -19 / R -28 1940490 50029224630000 10.0 17.0 0.3 9/6/2010 1.70 10/3/2010 END3 -21 / L -34 1870330 50029217140000 23.0 14.5 1.1 9/6/2010 13.60 10/3/2010 END3 -23 / N -32 1861550 50029216450000 1.5 1.0 __ 0.5 9/6/2010 3.40 10/3/2010 END3 -27 / M -33 1860830 50029215860000 1.0 0.1 0.6 9/6/2010 2.55 10/2/2010 END3 -29 / J -32 1901560 50029221060000 2.0 1.0 0.6 9/6/2010 3.40 10/2/2010 END3 -31 / K -32 1972270 50029228380000 2.0 3.0 0.5 9/6/2010 3.40 10/2/2010 END3 -33A / J -35 2032150 50029216680100 0.5 NA 0.5 NA 3.40 10/2/2010 END3 -35 / L -36 1870200 50029217010000 10.0 7.0 0.4 9/6/2010 3.40 10/2/2010 END3 -37 / L -35 1950510 50029225540000 8.0 7.3 0.3 9/6/2010 1.70 10/2/2010 END3 -39A /1-37 1970910 50029217640100 ' 1.0 0.8 0.7 9/6/2010 3.40 10/2/2010 r-1END3 -49A / M -40 1970570 50029217350200 0.4 NA 0.4 _ NA 1.70 10/2/2010 Pr6 kg7 6 5 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, February 03, 2012 10:11 AM r4, 431 lv To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Injector END 3- 49A/M40 (PTD #1970570) Place on Water Injection for AA Evaluation Based on passing MIT, proceed as planned with 2 month WI and monitoring in advance of requesting AA. Thank you for the update. Jim Regg EDFEB (j 3 ZWZ AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, February 02, 2012 8:19 PM To: Regg, James B (DOA) Subject: Injector END 3- 49A/M40 (PTD #1970570) Place on Water Injection for AA Evaluation Jim, A Tecwel Leak Detect Log has been performed on WAG Injector END 3- 49/M -40 (PTD #1970570) and no leak point was established. At this time, BP wants to pursue an Administrative Approval for water infection only. Prior to submitting an AA request, we would like to return the well to water injection for two months to establish a stable TIO on water service. The well passed an MIT -IA to 4000 psi on 08/23/2011. Please confirm that the plan forward is acceptable. The well will remain on the AOGCC Monthly Injection Report. The plan forward: 1. Slickline: Pull TTP 2. Operations: Place on water injection 3. WIC: Monitor TIO for 2 months 4. WIC: Apply for Administrative Approval for continued water injection — An updated TIO plot, Injection plot and MIT -IA form are attached for reference. «END 3 -49 TIO 02- 02- 12.doc» «MIT ACT END 3 -49 08- 22- 11.xls» Please call if you have any questions or would like to discuss. Thank you, Mehreett Vazir f,'lltc;rrrute: Gerald ;tlttrphv Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com 1 • • Endicott 3- 49/M40 PTD #1970570 2/2/2012 TIO Pressures Plot Wet 3-49 3000 • • --4,- Tb0 J - 2,000 - ODA . -•- 000A • • [w I T Algid I r t 02/05/11 03/19/11 04/08/11 09/09/11 06/09/11 07/10/11 08/10/11 09/10/11 10/11/11 11/1111 12/12/11 01/12/12 Injection Plot Wet 3-49 3,300 — - 18.000 Fl 4.. 2,700 2.600 ti - 14.000 2.500 2400 - 13.000 I 2300 2200 .. 12,00i) 2100I� - 11,000 2000 1,900 -10 - WHIP 1,800 - - - '` a 1700 RN 1.600 = 9 ,000 n - MI 1.500 • 9000 0 -..- Othel 1,400 J - On 1,300 I - 7,000 1200 ` 1.100 6,000 1.000 000 • 800 4.000 900 /41/1,,,‘‘ - 5, I 700 600 - 3000 500 400 . - 2000 300 - 200 -1,000 100 . . - • 02/05/11 03/08/11 04)08/11 05/09/11 06/09/11 07/10/11 08/10/11 09/10/11 10/11 /11 11;11/11 12/1 01/1 • Endicott 3- 49A/M40 PTD # 1970570 11/11/2011 TIO Pressures Plot Wet 3-49 i I 4,000 I 1 1 i • J,000 ■ I I —i— Tbp —1♦— IA I 1000 --&— OA aoA + OOOA I On 4 7 1( \ irez \fr...........1 i ■ ■ 1 1 i 1,000 i • 08/66111 08/13/11 08/20/11 08/27/11 00/03/11 09/10/11 09/17/11 09/24 /11 10/01/11 10/08/11 10/15/11 10/22/11 10/29111 11/05/11 1 _ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaoaalaska.aov; doa. aoacc.orudhoe.bav(cDalaska.aov; phoebe.brooks(cDalaska.aov; tom.maunderaalaskaa.00v OPERATOR: BP Exploration (Alaska), Inc. �� ( 44 v FIELD / UNIT / PAD: Prudhoe Bay / ACT / END 3 DATE: 08/22/11 OPERATOR REP: Mehreen Vazir AOGCC REP: Not Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3- 49A/M40 " Type Inj. W TVD - 9,712' Tubing 2140 2200 - 2200 2200 Interval 0 P.T.D. 1970570 / Type test P Test psi ' 2428 Casing 510 4007 3999 3995' P/F P - Notes: Evaluate TxIA communication - OA 50 380 380 380 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT ACT END 3 - 49 08 - 22 - 11 Monthly Injection Report for GPIiPMA, Northstar, Milne Point & Endiill for Novem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, December 20, 2011 2:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for November 2011 Attachments: AOGCC Inj Report 12- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the November 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 12- 11.zip)> Notes on wells: < • Added to Report: NS27 (PTD #2010270) Under evaluation for IA repressurization END3 -49A (PTD #1970570) Under evaluation for IA pressurization while on gas injection 16 -05 (PTD #2010100) Under evaluation to evaluate Injectivity to evaluate rig workover opportunities Taken off Report: None Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 12/20/2011 Well 3- 49AIM -40 Injection Plot Well: END 3- 49A/M -40 o Pressure vs. Rate o TIO Plot PTD: 1970570 0 0 0 0 v v Tbg IA Well currently classified as Not OA Operable until Leak Detect Log g ♦�,� o is performed for suspected TxIA • Nor CO • ri comminication m o , n o N > N 0 • O O 0 • Last 90 days • Last Month • O 0 5,000 10,000 15,000 20,000 5/12/11 8/2/11 10/23/11 1/13/12 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 12/01/11 0 675 12/01/11 0 825 0 11/30/11 0 663 11/30/11 0 825 0 11/29/11 0 662 11/29/11 0 800 0 11/28/11 0 674 11/28/11 0 825 0 11/27/11 0 657 11/27/11 0 825 0 11/26/11 0 648 11/26/11 0 825 0 11/25/11 0 636 11/25/11 0 800 0 11/24/11 0 683 11/24/11 0 700 0 11/23/11 0 709 11/23/11 0 700 0 11/22/11 0 734 11/22/11 0 700 0 11/21/11 0 684 11/21/11 0 700 0 11/20/11 0 774 11/20/11 0 700 0 11/19/11 0 788 11/19/11 0 650 0 11/18/11 0 807 11/18/11 0 650 0 11/17/11 0 826 11/17/11 0 500 0 • 11/16/11 0 835 11/16/11 0 650 0 11/15/11 0 767 11/15/11 0 400 0 11/14/11 0 854 11/14/11 0 400 0 11/13/11 0 906 11/13/11 0 550 0 11/12/11 0 972 11/12/11 0 550 0 11/11/11 0 1,079 11/11/11 0 500 0 11/10/11 0 1,239 11/10/11 0 500 0 11/09/11 0 1,724 11/09/11 0 1,450 0 11/08/11 0 2,563 11/08/11 0 1,450 0 11/07/11 8,577 2,844 11/07/11 2,818 1,400 0 11/06/11 10,096 2,828 11/06/11 2,818 1,400 0 11/05/11 9,811 2,819 11/05/11 2,881 1,400 0 11/04/11 10,337 2,949 11/04/11 2,881 1,300 0 11/03/11 9,536 2,897 11/03/11 2,903 1,300 0 11/02/11 9,812 2,930 11/02/11 2,941 1,000 0 11/01/11 9,906 2,934 11/01/11 2,941 1,000 0 RE: NOT OPERABLE: Injector 3- 49A/M40 (PTD #1970570) Slow iiressurizati... Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, November 13, 2011 1:08 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: NOT OPERABLE: Injector END 3- 49A/M40 (PTD #1970570) Slow IA Pressurization While On Gas Injection Tom, I did not mention in the note below that this well will remain on the Monthly Injection Report submitted to the AOGCC until you receive further notification from BP on a plan forward after the Leak Detect Log is evaluated. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, November 11, 2011 1:26 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wood, Alecia Cc: Walker, Greg (D &C); Olson, Andrew Subject: NOT OPERABLE: Injector END 3- 49A/M40 (PTD #1970570) Slow IA Pressurization While On Gas Injection All, WAG Injector END 3- 49A/M -40 (PTD #1970570) has continued to exhibit IA repressurization while on MI service as seen in the attached TIO plot. A Positive Pressure Packoff Test on the tubing hanger passed confirming that the communication is not through the wellhead seals. The well is currently shut in and reclassified as Not Operable until further diagnostics are completed. The plan forward is: 1. Slickline: Set tubing plug 2. Eline: Log Tecwel Leak Detect Log using MI gas 3. Production Engineer /Well Integrity Coordinator: Evaluate log results and determine plan forward to repair leak or apply for Administrative Approval for continued water injection only « File: END3 -49 TIO 11- 11- 11.doc» Please call if you have any questions or concerns. 12/29/2011 RE: NOT OPERABLE: Injector 3- 49A/M40 (PTD #1970570) Slow Oressurizati... Page 2 of 2 Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, October 24, 2011 9:22 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wood, Alecia Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael 3 Subject: UNDER EVALUATION: Injector END 3- 49A/M40 (PTD #1970570) Slow IA Pressurization While On Gas Injection Al I, Injector END3- 49A/M -40 (PTD #1970570) is exhibiting signs of slow IA pressurization while on miscible gas injection. The well passed an AOGCC witnessed MIT -IA on 05/06/2011 to 3000 psi, and also passed an MIT -IA to 4000 psi prior to the start of gas injection on 08/23/2011. The well is reclassified as Under Evaluation. Plan forward: 1. DHD: Bleed IAP to 500 psi 2. WIE: Monitor well for IA repressurization for 10 to 14 days 3. Wellhead: Positive pressure pack off test - tubing (PPPOT -T) A TIO plot, injection plot and wellbore schematic are included for reference. « File: END3 -49A (PTD #1970570) TIO and Injection Plot.doc » Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 12/29/2011 ! • WAG Injector END 3- 49A/M -40 (PTD # 1970570) TIO Plot 11/11/2011 Welt 3-49 3.000 l �__ —II-- IA 2,000 1 — � — R4 lit o I ....■On f 1 \ 7 T , 00/08 /11 09/13/„ 08/20/11 08/27/11 09/03/11 09/10/11 09/77/1 • X 09 /24 /11 10/01 /11 10/09 /11 10/15/11 10/22/11 10/29/11 11/05/11 MEMORANDUM • State o Alaska • Alaska Oil and Gas Conservation Commission !'J DATE: Monday, May 09, 2011 TO: Jim Regg S' 17(il P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3- 49A/M40 FROM: Lou Grimaldi DUCK IS UNIT SDI 3- 49A/M40 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Jl NON - CONFIDENTIAL Comm Well Name: DUCK IS UNIT SDI 3- 49A/M40 API Well Number: 50- 029 - 21735 -02 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110506160812 Permit Number: 197 -057 -0 Inspection Date: 5/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13- 49 A/M 4o rType Inj. W 1 TVD 9712 IA 720 3000 2960 2960 T P.T.D 1970570 TypeTest SPT Test psi 2428 , OA 70 280 280 280 Interval 'WRIST _ p/F P Tubing 1835 1835 1835 I 1835 Notes: 5.1 Bbl's Meoh pumped, well fluid packed. Good solid test. - Mg 1 8 '1U11 Monday, May 09, 2011 Page 1 of 1 04/14/09 a1~i11~~~~~~61- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.5188 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Woll ~..~, u ~.,_ ~` W-18 11968978 RST -~ uaie 12/22/08 GL 1 GOIOr GD 1 07-02B AXBD-00013 MCNL - 02/12/09 1 1 K-05C AWJB-00016 MCNL ~ ~~ 12/30/08 1 1 F-i8A AYLF-00020 CEMENT IMAGE LOG f ~- 03/19/09 1 1 J-09A AP30-00024 STP CROSS FLOW CHECK ~ (~ _ 03/25/09 1 1 X-05 AYTO-00014 PFCS CALIPER LOG) _ C 04/09/09 1 1 O-04A AYTU-00023 _ LDL & PLUG SET j~5 _ ~ 04/02/09 1 1 04-40 AYTU-00025 USIT ~ ~- C~ 04/10/09 1 1 06-148 AVYO-00021 SCMT _ '} 04/01/09 1 1 Z-01 B AVYO-00025 INJECTION PROFILE -- /p ~ 04/11/09 1 1 L3-15 AYTU-00023 _ _ . _ PRODUCTION PROFILE ~ 04/06/09 1 1 11-30 AXBD-00021 MEM PROD PROFILE ( c~ , °•~~ 04/14/09 1 1 3-03/J-33 AZ4D-00013 RST W/INJ PROFILE - ( ~' - ~ a 04/05/09 1 1 3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE - ( ~/ 04/03/09 1 1 3-49A/M-40 AXBD-00019 MEM INJECTION PROFILE • 04/07/09 1 1 V-114A ~ U °~- `"~ AVY500032 INJECTION PROFILE '- j ~~a 04/02/09 1 1 ---- -- i I.S I - ` ~. ~- THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 5185 E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) j _~- ~-~9 01/14/09 1 1 MPS-43 AXML-00020 OH LDWG EDIT 12/29/08 2 1 PLEASE ACKNOWLEDGE RE CEIpr rav clnnll nln nnln oeri iosnw. ~..~ .....,~, r-..... r,._ BP Exploration (Alaska) Inc. -• ~ - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 838 ATTN: Beth Received by: J Page 1 of 1 Mahnken, Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Friday, July 18, 2008 8:32 AM To: Mahnken, Christine R (DOA) Subject: FW: API Number revised in RBDMS Christine, Please print the following message and file it in the well file. Thanks, Steve D. • From: Johnson, Elaine M (DOA) Sent: Thursday, July 17, 2008 4:21 PM To: Davies, Stephen F (DOA) Cc: Fleckenstein, Robert J (DOA); Saltmarsh, Arthur C (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Mahnken, Christine R (DOA) Subject: API Number revised in RBDMS Steve, I revised the API Number from 50-029-21735-01-00 to 50-703-21735-02-00 for 19~ 7-057-0, DUCK IS UNIT SDI 3-49A/M40 as follows: tbIWellMaster, 1 Record tbIWellHistory, 6 Records tbIWellLeases, 1 Record ~~~~~ JUG ~ ~s 2~~~ tbIWellFieldPool, 1 Record tbIWellZones, 1 Record tblUicMaster, 1 Record tblUicIMIT, 4 Records tblProdWellPool, 21 Records tblGeoProdTest, 4 Records tblGeoLogs, 26 Records tbIFASSVS, 1 Record tblLocMaster, 1 Record cascading to tblLocSub, 1 Record tblLocSubCoord, 1 Record tblUicMonitor, 111 Records. {f you find other invalid records for this permit, please let me know. Elaine 7118/2008 MEMORANDUM To: Tim Regg ~~ a- ~; , .... P.1. Supervisor ,~,~ ~ 1 ~~ c ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commis DATE: Friday, September 28.2007 SUBJECT: Mechanical IntegriTy Tests BP EXPLORATION (ALASKA) INC 3-49A/M40 DUCK IS UNIT SDI 3-49ARv140 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: DUCK IS UNIT SDI 3-49AiM40 Insp Num: mitCS070911061719 Rel Insp Num: API Well Number: 50-029-21735-01-00 permit Number: 197-057-0 _ Inspector Name: Chuck Scheve Inspection Date: 9/8/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Iz-a9EvM4o ITYpe Inj. ~ ~' ~'i TVD ~~~ 9712 "~~ IA ~~ soo ~ 2zlo I 26so ~ z6ao P.T.D, 19'os7o I~TypeTest SPT' Test psi ~ za2a ~, OA so ~ loo loo ! loo Interval 4~TST P/F P °' Tubing ~ zsoo 2soo zsoo I 2soo ~ '~ _. Notes: Pretest pressures were observed and found stable. ~~,~~`' NCv ~ 2007 Friday, September 28, 2007 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair WellO Pull Tubing 0 Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 Convert to WAG Otherl!J 53.10 8. Property Designation: ADL-047503 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 3-49A1M-40 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit Exploratory 0 Service ŒJ Name: BP Exploration (Alaska), Inc. Development D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 13390 feet Plugs (measured) Junk (measured) None true vertical 10246.6 feet Effective Depth measured 13370 feet None true vertical 10231.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 118 38.0 - 118.0 1490 470 Liner 5097 7" 29# L-80 8288 - 13385 6807.5 - 10242.7 8160 7020 Production 8449 9-5/8" 47# NT80S 36 - 8485 36.0 - 6904.4 6870 4760 Surface 2478 13-3/8" 68# NT-80 37 - 2515 37.0 - 2513.9 5020 2270 Perforation deDth: Measured depth: 13230 -13240,13240 -13245,13245 -13246,13260 -13278, 13278 -13280,13321 -13338, 13338 -13341 True vertical depth: 10123.2 - 10130.89, 10130.89 - 10134.73, 10134.73 - 10135.5, 10146.27 - 10160.12, 10160.12;: 10161.66 10193.27 -10206.4, 10206.4 -10208.72 ~";1;~' It,:: l.,; t..... -~ Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 35 12791 .~"'" I, Packers & SSSV (type & measured depth): 4-1/2" Baker SB3 Packer 7" Baker ZXP Packer @ 12694 @ 8288 \liAR 1 0 200 AI(.1'.I(~A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 0 0 7002 1100 2047 0 9.7 0 3345 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily-Report of Well Operations- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature Title Production Technical Assistant Phone 564-4657 Date 3/8/04 ~~~;,A~~~E[JJ MA~{ 1. 2 2004 \Ø)MS BfL WAoll- Form 1 0-404 Revised 12/2003 3-49A1M-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/29/04 Convert to Water - Alternating - Gas Injection BBLS 0 FLUIDS PUMPED : TOTAL No Fluids Pumped Page 1 TREE: 4-1/16" /5000 psi /McEvoy - Baker/Axelson Actuators WELLHEAD: 13-5/8" 1 5000 psi 1 FMC (CCL) Sidetrack 13-3/8", 68#/ft, NT80 CYHE BUTT 12515 41/2" L-80 IBM TBG. 9-5/8", 47 #/ft NT80S XO to NT95HS I 8288 17" BAKER ZXP LINER 18485 BOTTOM 9 5/8" CASING ( TOP OF WINDOW) PERFORATING SUMMARY Reference log: SWS Jewelry Log 4/22/97 CO SIZE SPF SWS 2-7/8" 4 SWS 2-7/8" 4 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 SW 3-3/8" 6 INTERVAL 13230-13246 Open 13260-13280 Open 13079' -13089' SOZD 13132'-13156' SQZD 13230' -13240' SOZD 13258' -13278' SOZD 13156'-13166' SOZD 13178'-13210' SOZD 13230' -13245' SOZD 13260' -13280' SOZD PBTD 7" 29#/ft L-80 HYDRIL 113370 I 7" SHOE 113385 I Date 4/21/97 5/29/97 3/20/99 B Comments DV COMPLETION RAC SQZ/Post SOZ Perfs DB SQz/Post SOZ Perfs 0 RT ELEV= 56' BF ELEV= 17.2 MAX. DEV. = 61 DEG. @ 8480' MD SSSV LANDING NIPPLE 1502 HES "HXO" (3.813" ID) ALLGLV'S HAVE 8TM INTEGREL LATCHES CAMCO KGB-2-LS-MOD 9 CR 6 3475 5 5508 4 7369 3 8811 2 10255 1 11615 3418 5259 6332 7094 7972 8926 NOTE: ALL NIPPLES & GLMS ARE 9 CHROME 4-1/2" "X" NIPPLE (HES) (3.813" ID) - 7" BAKER SB-3 PACKER I Baker (3.952" I.D.) I I I ELMD I ~ 4-1/2" "X" NIPPLE (HES) (3.813" ID) 4-1/2" "XN" NIPPLE (HES) (3.725 10) 4-1/2" WLEG ENDICOTT WELL: ..~a/M-40 API NO: 50-029-27351-02 COMPLETION DIAGRAM 112683 12694 I 12759 I 12780 I 12791 I 12783 1 Top Baker Latch I 12999 I Collar 3.31' Length BP EXPLORATION (ALASKA), INC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Randy Ruedrich Commissioner P.I. Supervi DATE: September 19, 2003 Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Test BPX Endicott SDI 3-49/M40 DIU Endicott Field Packer Depth Pretest Initial 15 Min. 30 Min. I P.T.D.I 197-057 TypetestI P ITestpsil 2069 I Casingl 950 I 25001 2460 I 24401 P/F I P I~''''' Notes: pretest pressures observed for 30 minutes OK I WellI I Type Inj. P.T.D. I Type test Notes: WellI P.T.D.I Notes: WellI I Type Inj. P.T.D. I Type test Notes: Type Inj. Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER IN J, 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 Test's Details I traveled to BPXs DIU SDI location and witnessed the successful 4 year MIT on well 3-49. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 Total Time during tests: '1 hour Cc: MIT report form 5/12/00 L.G. 2003-0919_MIT_Endico~_SDl_3-'49_cs.xls 9/24/2003 STATE OF ALASKA ALAS.~_~-A^ OIL AND GAS CONSERVATION COMMISSION REPORT C.: SUNDRY WELL OPL.{ATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well ~ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.c/e, Alaska 99519-6612 4. Location of well at surface 2499' SNL, 610'WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development Exploratory __ Stratigraphic .__ Service .. 6. Datum elevation (DF or KB) 53.10' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49A/M-40 9. Permit number/approval number 97-57 / 399-191 10. APl number 5 O- 029-21735- 02 11. Field/Pool Endicott Field / Endicott 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: Length 122' 2476' 8449' 5098' measured true vertical 13390' feet 10247' feet 13370' feet 10231'feet Plugs (measured) Junk (measured) ORIGINAL Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 161' 161' 15-$/8" 3495 c.f. Perma frost 2515' 2514' 9-5/8" 860 c.f. Class 'G' 8485' 6904' 7" 410 c.f. Class 'G' 8289'- 13387' 6808'- 10244' 13078'-13090'; 13142'-13166', 13178'-13210' (All Squeezed) 13230'-13246'; 13260'-13280'; 13321 '- 13341 '(All Open) (Subsea)9950L9959~ 10000~10018~ 10027'-10052'(Afl Squeeze¢; 10070L10082~ 10093'-10109'; 10140'-10156'(Aflope¢ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing set to 12792' Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 13. Stimulation or cement squeeze summary MIT IA (10/03/99), Add Perforations, Cement Bond Log (10/24/9~')., Intervals treated (measured) 13321'-13341' MD ,,' ~_ E. ,,.-.J?U Treatment description including volumes used and final pressure see a~ached _ ~,,¢~ I~"~''' ........ Ui,'~"l 4.:~0 ~% f ',r' ~ ....... ~ ........ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ; - ', ,m¢! Tubing Pressure Prior to well operation 0 0 2135 0 0 Subsequent to operation 0 0 94 0 1589 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended Service WAG to be converted to MI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15!8.%... Title ~enior Technical A_~_~i.~tant IV Date 11-01-99 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department E-line operation DATE: 10~24~99 WELL N°: 3-49a / M-40 TYPE OF OPERATION: Cement Map tool ! Static / temp / add-perfs BP EXPLORATION REP: Tare Peruzzi SERVICE COMPANY: SWS / Boehme Summary: Cement looks good. At 13295 feet there may be some fast formation (VDL) causing good cement to look bad. Static data: SI date 9/22/99 (32 days). Datum 10,000' TVDSS. Pressure = 4491 psi. Temperature=216 degrees F. Temperature overlays yielded no reservoir information. However the data was useful. Metering on the well, and by extension all of the injection volume to date, is suspect. The meter was reading 3,000 BWPD. However the only audible indication of injection was when the well was first put on injection and WHP quickly pressured up from 650 to 2100 psi. After 2 hours of injection there was no change of temperature downhole and no disturbance to temperature gradient below 4,000 feet in the tubing. Well seems to be taking about 500 BWPD after perforating. Shot 10 feet. On 10/24 well is taking 6000 BWPD, but the flowmeter was reading zero in the morning until Will Burley got it working. Instrument tech will investigate the flowmeter 10/25 or soon. PERFORATION SUMMARY: GUN INTERVAL, MDBKB 1 13321-13341 ref 97 GR-CCL 2" powerjet 6 spf 60 degree phasing. FEET 20 su.zo. ,ECEIVED f';tV 0 2 3999 Alaska 0{I & Gas Cons. Commission Anchorage DATE/TIME OPERATIONS SUMMARY 10/24/99 0800 1000 1045 1400 1615 SITP 600, lAP 700 ©AP=0 Shot fluid level @ 1200 feet. With 920 feet of methanol estimate static pressure of 4600 pounds. 1200 x 0.08 + 960 x 0.39 + 7840 x .45 + 600. Calculation done prior to Schlumberger rigging up. On location Shul-in well and RIH. Log static and bond log SI. Start injection. Hear water entering well initially as tubing pressures up - then no noise. Spend some time opening and closing well to check if it is actually flowing. Make temp passes @ 1 and 2 hours. SI well and log out of tubing to find injection anomaly. 18:00 19:00 20:00 RIH with Gun. Shoot 13321-13341. RD. Go home. SSSV out RECEIVED ,-,,f 0 2 1999 ~k~ Oil & G~s ~n~. Oommi~ion Page BPX Endicott Production Engineering Department MIT Inner Annulus DATE: 10~03~99 WELL N°: 3-49AIM-40 BP EXPLORATION REP: Dan Robertson SERVICE COMPANY: APC Pump truck Note: well was shut in 9/27/99 for a static pressure survey. Tubing was displaced with gas for freeze protection. Fluid level shot indicated fluid level above SSSV. Pumped 15 bbls 60/40 methanol down tubing to freeze protect and prevent hydrates when well is returned to water injection. Pump 60 bbls 60/40 methanol into inner annlus to increase lAP from 1000 psi to 2500 psi. Monitor 30 minutes, lAP at 2500 psi after 30 minutes. Tubing pressure constant at 1150 psi throughout job, OAP constant at 50 psi. Witnessed by John Spalding with AOGCC. Bled inner annulus to 700 psi after test. Note: lAP WILL NEED TO BE CLOSELY WATCHED WHEN WELL IS PUT ON INJECTION DUE TO THERMAL EXPANSION. RECEIVED f,...?~',/02 1999 AIItS~ 0ii & Gas Cons. Commission Anchorage ALASKA OIL AND GAS OONSEFIVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Altar casing __ Repair well__ Change a~proved program __ 2. Name of Operator ~ BP Exc)loration (Alas.~,a_) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99579-6612 4. Location of well at surface 2499' SNL, 810' WEL, SEC. 8. T11N, R17E, UPM At top of productive interval 2957' SNL, 5286' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N. R17E, uPM At total depth 2915' SNL. 207' EWL, SEC. 10 T11N, R17E, UPM 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 Oj:~ratk3n Shutdown __ Re.enier suspende~i well __ Plugging Time ex-tension __ $11mulate __ Pull tubing__ Varfance__ Perforate ~; Other RECEIVED 1999 13390' feet Plu~~ed) 10~47' feet Datum elevation (DF or KB) 53.10' KB 7, Unit or Property name Duck Island Unit/Endicott -8, Well number 3-4,gA~M-40 9, Permit number 97-57/399. 017 10, APl number 50-029-21735.02 !11, Field/Pool Endicott Field / Endicott Pool 13370' feet Junk (measured) 10231' feet Size Come.ted Measured cl~p.[J,~ True vertical depth BKB 122' 30' Driven 161' 161' 2476' 1~-~/$" 3495 c.f, Permafrost 2515' 2514' 8449' 9-5/8" 880 c.f. Class 'G' 8485' 6904' 5098' 7~ 410 c.f. Class 'G' 8289'-13387' 6808'-10244' measured 13078'-13090'; 13142'-13f88', 13178'-13210' (Afl Squeezed) 13230'.13246'; 13260'-13£80' (All Open) true vertical ($ubsea) 9950'-99&9; 10000'- 10018'; 10027'. 10052' (All Squeezed); I0070'- 10082'; 10093'- 10109' (Ail open) Tubing (size, grade, and measured depth)4-I/2", 12.6#, L-80 tubing set to 12792' Packers end SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952¥ I.D) set at 12694' feet 13, Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 4. Estimated date for commencing operation October 2, ? 999 16. if proposal w~s verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service WAG t~ be converted to MI Suspended . 17. I hereby cert~ that th_,¢ foregoing is. true and corr~ect to the best of my knowledge. FOR COMMISSION USE ONLY Date 9-29-99 Conditions of approval: Notify Commission so representative may witness Plug Integrity_ BOP Test__ Location clearance ~ Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 J /~ ".-I I Approval NO.~.~ Subsequent form required 10- ~ ~ ORIGINAL SIGNED BY.-,,o"leGp. ~ ~ommissioner Date Robe~ N. Christens~gv~e~°~ e6 ~ SUBMIT IN TRIPLICATE / ~h~ I I~qT~kl~ ~ I,l~b ~¢R ~. Endicott Production Well 3-49a/M-40 Additional Perforating Program Synopsis Objective Complete the perforating of Flow Unit ii, to ensure conformance with offset production well 4-46 Justification Following its conversion to a WAG injector iax March 1999, water injection commenced only into two intervals in Flow Unit ii (Fii). There was concern that this unit might be at a low pressm'e and so would require re-pressm'izing before conunencing injection of MI. Consequently, the higher quality Fiii & Fir sands were not performed at that time, to speed up the re-pressurization of Fii and hopefully observe a response in offset production well 4-46. However, at the Reservoir Management Review in July 1999, it was identified that additional Fii sands, deeper in the wellbore; might also eon'elate with open perforations in 4-46. The work being proposed here is to perforate that additional Fii interval in 3-49a, in an effort to ensure complete conformance between the two wells. A static pressure will be obtained prior to perforating to determine the effect of Fii injection over the last few months. Assuming that the new perforations are observed to take water, Fii injection only will be sustained and another pressure will be acquired in the future (timing will be dependent on injection rate and well behavior). When it is confirmed that Fii is adequately pressurized, the Fiii & Fir sands will be reperforated, in preparation for conversion to MI. Summary Procedure note: a cement bond log & static pressure survey will be run immediately prior to perforating 1. chm~ge toolstfing for perforating and pick up a single 20' gun 2. RIH and perforate the following interval: Zone Top Bottom Length Gun Type Shot Density Fii 13325' 13345' 20' 2" Power Jet 6 s.p.f, reference log: Sperry Sun DGR-EWR of 14 April 1997 3. Return well to injection on a fully open choke. Phasing Orientation 60o random ORIGINAL cgs 9/29/1999 STATE OF ALASKA ALASK&~IL AND GAS CONSERVATION COMMISSIO~J. REPORT O. SUNDRY WELL OPE..ATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2499' SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development Exploratory __ Stratigraphic Service .. 6. Datum elevation (DF or KB) 53.10' KB feet 7. Unit or Properly name Duck Island Unit/Endicott 8. Well number 3-49A/M-40 9. Permit number/approval number 97-57 / 399-017 10. APl number 50- 029-21735-02 11. Field/Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Structural Conductor 122' Surface 2476' Intermediate 8449' Production 5098' Liner Perforation depth: 13390' feet 10247' feet 13370' feet 10231' feet Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 161' 161' 13-3/8" 3495 c.f. Permafrost 2515' 2514' 9-5/8" 860 c.f. Class 'G' 8485' 6904' 7" 410 c.f. Class 'G' 8289'-13387' 6808'-10244' measured 13078'-13090'; 13142'-13166', 13178'-13210' (Afl Squeezed) 13230'-13246'; 13260'-13280' (All Open) true vertical (Subsea) 9950;9959', 10000'-10018'; 10027'-10052' (Afl Squeezed); 10070'-10082'; 10093; 10109' (All open) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing set to 12792' Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 13. Stimulation or cement squeeze summary Cement squeeze and reperforation for conversion to Water Injector Intervals treated (measured) 13078'-13090'; 13142'-13166', 13178'-13210';13230'-13246'; 13260'-13280' (All Squeezed) 13230'- 13246? 13260'- 13280' (Reperforated) Treatment description including volumes used and final pressure see attached ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 0 0 0 0 0 Tubing Pressure 0 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations. × 16. Status of well classification as: Oil __ Gas Suspended Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed I'~.--,~ ~~,~Lg_~O ~ Titles;eniorT~_chnic~lAssistantlV Form 10-404 Rev 06/15/88 Date 4-13-99 SUBMIT IN DUPLICATE To: Anchorage Production Er,,~ .,eedng .cation: Endicott From: Nordlander/Johnston/Barba Date: 3/17/99 Operation: Endicott 3-49a Cement Squeeze Cost Code: N 10349 Summary Siwhp is 3400, decide reservoir pressure is greater than 3600 as well has been shutin over 7 months. Kill well with 266 bbls of seawater. Rih. Circulate out gas bubble down Well 3-43. Estimate reservoir pressure at 5100. At min rate, tag soft td @ 13,323 ctmd; did not correct. Pu and flagged pipe and kooled sump. Jet acid across peris and kool down cement interval. Lay in cement from bottom perf and begin squeeze at 1600 whp. Achieved bbl for bbl and walked up to final squeeze of 3000 whp. Held for over 1 hour while keeping poorboy and hardline warm. Jetted through cement with biozan contaminate, tagged top of cement at 12,920' and jetted to hard tag at 13,338'. Spotted tea across squeeze peris and chased cement out of hole; jetted jewelry on the way out of hole. Estimate 3 bbls cement behind pipe based on cement top, 5 bbls based on cement wash up. Freeze protect to 2000'. 3/17/99 Initial Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 3400 800 0 n/a 0 100 Time Operation 6:00 Miru DS #6, 14,570' of 1-3/4" (ctv 33.2 bbls). 8:30 Debriefed crew on pressure test. 9:06 Start pressure test. 9:14 Recover meoh. 9:50 Open well to kill. Time Depth Rate Ctp Whp Stage Out Rtn Remarks ft bpm psi psi bbls Nzl bbls 9:55 surf 3.0 3570 3510 5 Tank Strap 10:00 3555 3490 20 50 10:07 3220 3130 45 76 10:22 4.4 2660 2530 107 146 10:43 4.4 2480 2840 205 236/ Looks like whp gauge is off. Shows 2400 in squeeze manifold. 10:46 2400 2850 209 Shut down to monitor. 10:48 1240 1950 Try to rih. BOP shows 2000 whp, squeeze unit shows 900. 10:57 Cannot get in hole, try killing it more. 11:06 28030 2770 249 Shut down. 11:10 930 890 Cannot get in hole. Start pumping down coil. 11:14 Shut down and pop off. 11:27 Stab on, pressure test. 11:32 700 700 Warm pipe up 11:35 4.4 2200 2200 266/s Try rih. 11:49 580 1050 1050 Start water down coil only. 12:38 6500 1.0 1930 1260 40 Up weight 9.Ok, down 3.Ok. 13:21 11400 1930 1350 76 Inc rate. 13:26 2.0 3800 1750 82 Open choke. 13:32 12500 3230 700 95 Weight up 19.5k, 8.Ok down. Operation: Endicott 3-49 Cement Sq. rze W6. ame Here 13:37 730 106 Park. 14:08 152/12 Computer froze. 14:40 2.0 3800 1350 76 Chokes closed, shut down. 14:50 0 730 930 Continue circulation. 14:58 2.0 3300 700 94 Chokes closed, shut down. 15:00 620 620 Well is dead. Rih. Open chokes. 15:09 1.0 1530 550 104 Red rate to min. 15:14 13323 0.2 330 350 105 Tagtd, no correction. Pu. 15:17 13310 Flag pipe. 15:23 110/s Shut down coil. Line up cementers to pt. 15:26 3/f Pt good, start acid down coil. 15:38 2.0 3630 680 15/a Switch to seawater. 15:46 13280 1.0 1440 600 18 Jet across, inc rate, close chokes. 15:51 13070 1.5 2800 1100 25 Jet down. 15:56 13280 2900 1250 32 Jet up. Start mixing cement. 16:02 12880 2950 1310 41 Park. Postinj 1.5 (~ 1310 psi. 16:18 1.5 3160 1550 65 Cement to weight, 15.6 ppg 16:42 3400 1820 100 Open chokes, rih. Cement to test cell. 16:53 13310 2500 760 117 Park. 17:05 2370 630 135 Jet up. 17:13 12880 2350 620 148 Park. 17:23 2380 650 163 Jet down. 17:34 13310 2400 670 181 Park. 17:41 2360 640 190 30 min fl 69.5 cc, 0.87" thickness. 17:46 2370 640 198/s Switch to fw spacer. 17:49 5/f Switch to cement. 17:59 1950 610 15/c Switch to fw spacer. 18:03 13310 1860 620 20 Up 25.0k, switch to sw. 18:11 2250 610 32 Red rate. 18:12 33 0 Cement at nozzle, tighten chokes a little. 18:13 13300 1.0 790 860 34 1 18:14 880 900 35 2 Pooh. 18:15 13259 960 960 36 3 18:16 13231 860 840 37 4 18:17 13204 970 860 38 5 18:18 13178 1030 860 39 6 0 18:19 13152 1070 40 7 ~1 18:20 13125 1110 41 8 2 18:21 13099 1180 42 9 3 Perfscovered. 18:22 13074 1270 43 10 4 18:23 13046 1320 44 11 4.75 18:24 13020 1390 45 12 5.75 18:25 12994 1480 46 13 6.5 Pooh to wctoc. 18:26 12952 1540 47 14 18:27 12898 1620 48 15 8 18:28 12848 1644 49 9 Pu to safety. 18:29 12737 1675 50 9.75 18:30 12670 1700 51 10.5 Red rate, close chokes. 18:32 0.5 1560 52 11 Operation: Endicott 3-49 Cement Sq..,ze W6..ame Here 18:34 53 12 18:36 54 13 Open choke on 3-43. Walk pressure to 1600 18:38 1410 55 13.5 18:40 1950 1600 56 14 18:42 1950 57 14.75 18:44 1950 58 16 Walk pressure up to 2500. 18:46 2820 2500 59 16.25 18:48 2810 60 17 Shutdown. 18:51 2600 2600 Looks good, bleed down 3-43. Come on line. 18:53 2880 2700 61 17.25 18:55 3250 3000 62 17.75 18:58 63 18.75 19:00 12665 64 19.75/ 19:02 3100 3090 65/s Shutdown. 19:12 3100 3090 Bleed down 3-43, drop ball. 19:28 1600 1600 Close choke. Switch to biozan contaminate. 19:35 0.5 3300 3000 2 20:13 1.0 3600 2550 15 Cycle in hole. 20:22 12850 1.4 3000 1460 25 Park. 20:25 3200 1600 28 b 28/b Switch to water. 20:28 3160 1530 33 Jet down. 20:30 12920 Cementtop 20:34 13070 3000 1260 41 s 13/s Switch to tea. 20:40 13338 1.8 2880 1120 52 t 11/t Tag td, switch to slick seawater. 20:45 13090 2780 1370 58 Jet down. 20:51 13338 2.3 3350 1420 69 Jet up. 20:55 13290 1.5 2380 1000 75 Lay in tea. 21:00 13060 2180 84 Jet up at 80%. 21:07 12750 2.8 3500 1100 101 Jet jewelry up and down. 21:39 10240 3500 1180 185 21:47 9755 3500 1200 205 Dirty returns to surface. 23:04 3500 2.0 2500 1080 348 ss 296/ss Switch to meoh, 13 bbls of cement in hopper. 3/18/99 0:05 surf 1.5 3350 1100 80/m Sd trap pressure & monitor. 0:10 1150 1140 Jug tite. Bleed down and rig down. 2:00 Move coil to 4-10 Final Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 1100 800 0 n/a 0 Fluid Summary 804 Endicott plant water (Seawater & produced water). 296 Endicott plant water (Seawater & produced water) & fdction reducer. 13 Fresh water 15 Acid 15% HCI & 10% Xylene. 15 Cement. 28 Biozan w/contaminate. 11 TEA. Operation: Endicott 3-49 Cement Sq,..,ze W6..ame Here 1262 Total Squeeze Nozzle Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments DS ct connector. 2-1/8 1.00 0.94 BP squeeze nozzle 3.00 0.50 Total Length 1.44 DS Cement Summary 15.8 PPG Class G Cement containing: 0.10 gps D047 0.040 % BWOC C359 1.0 % BWOC D020 0.10 gps D135 0.30 % BWOC Ml17 1.0 gps D600 0.030 %BWOC D065 0.60 % BWOC DS00 Thickening Time = 6 hfs and 2 rains. Lab APl fluid Loss = 72 mi @ 170 o F. Requested 50-80 mi., 70 cc target Requested 5-7 hours Field APl fluid loss 70, 0.87" thickness. BPX Endicott Production Engineering Department DATE: 3~20~99 WELL N°: 3-49a/M-40 BP EXPLORATION REP: SERVICE COMPANY: Post-SQZ Perforations D. Barba SWS (P. AIIdredge) DATE/TIME OPERATIONS SUMMARY 1000 1045 1100 1155 1200 1210 1257 1310 1400 1430 MIRU SWS. SIWHP = 350 psig, lAP = 850 psig, OAP = 80 psig. Note well in was squeezed 3/17/99. 1510 1537 1545 1700 1800 Hold Safety Meeting Pressure test lubricator to wellhead pressure. RIH with Gun #1 (20') 2 7/8" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 7.1'. Out of the tubing tail. MAKE TIE-IN PASS. MAKE -47' CORRECTION.Tie into Jewelry Log Dated 4/22/97. Having trouble correlating gun seems to be yo-yoJng, while logging up hole. PARK CCL 13252.9' AND SHOOT (TS 13260' BS 13280'). Good cap break, and lost 10 psi at WH. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #2 (16') 2 7/8" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 11.1'. MAKE TIE-IN PASS. MAKE -18' CORRECTION.Tie into Jewelry Log Dated 4/22/97. PARK CCL 13219' AND SHOOT (TS 13230' BS 13246'). Good cap break, and lost 20 psi at WH. POOH OOH. Confirm all shots fired. RDMO SWS. PERFORATION SUMMARY: GUN INTERVAL DEPTH 1 13260-13280 2 13230-13246 FEET SUBZONE 20 FII 16 FII All intervals were shot using 2 7/8" guns with deep penetrating charges at 4 spf, 60 degree phasing and random orientation. PERMIT 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 97-057 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 04/07/99 DATA T DATA PLUS PERF TDTP/GR/CCL 7827 GAS LIFT-SPIN/ PERF PROD-SPIN/TEM/ PERF GAS LIFT DEFT PROD-PSP/DEFT. JWL/PERF ~1~600-13370 7681 ,/T/SCHLUM PDC/GR DGR-MD y8485=13385 DGR-TVD ~L'~6905-10247 7984 PERF ¢/13178-13280 PERF ~'~13198-13280 ~1 STAT ~RESS S~ ~8000-~33~0 PLUG SET 2TN~ SET RC~ ~ 85S0-8720 HW~ S2VY ~RRY 84~9.~5-~3390 PROD/FBS/CFM/GR/~EMP/DEFT 12980-13320 GAS ~FT-S~N/ ~RESS/TEMP/G~/CCL ~2600-~3084 ~000-13370 ~SCHL~ TDTP ~'TE~/P2ES/~EFT 0-~2500 ~0~0-~S0 ~RES/D 0-13300 RUN RECVD FINAL 05/16/97 i 05/16/97 FINAL 05/21/97 FINAL 05/21/97 ~EfSPERRY MPT/GR/EWR4/CNP/SLD/ROP 1-5 2000-12000 BOX 05/21/97 FINAL 07/18/97 FINAL 07/18/97 FINAL 07/18/97 FINAL 07/18/97 FINAL 07/18/97 08/06/97 FINAL 08/15/97 FINAL 08/15/97 FINAL 08/15/97 FINAL 10/02/97 1 10/02/97 FIN~ 11/13/97 FIN~ 11/21/97 FIN~ 12/18/97 FIN~ 12/30/97 FIN~ 04/30/98 F~N~ 0~/30/9S F~N~ 0~/30/~S PER_MIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 2 Date: 04/07/99 T / RUN RECVD D .............. BOX 10-407 ~R~OMPLETION DATE @ /-.//~,~ / TO ~//~/~?/ DAILY WELL 0PS R @S/il,q7 Are dry ditch samples required? yes ~____~And received? Was the well cored? yes~. _~alysis & description received? Are well tests required? ~,e~s ~Received? ~ ..... Well is in compliance /~ Initial C0~ENTS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 28, 1999 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Conversion of Well 3-49A/M-40 to Water Injector Dear Mr. Wondzell' Enclosed is a 10-403 Sundry application for conversion of well 3-49A/M-40 to a water injector. We plan to squeeze the perforation and convert to injection on or about February 1, 1999. If there are any questions, please contact me at 564-5872. Sincerely, Tave Peruzzi Production Engineer ,.f I A I I- fOI- ALASKA ALASKA-~°-tL AND GAS GONSEFlVATION GOMMISSIC'~' APPLICATI,..., I FOR SUNDRY APP,,OVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 2499' SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) 53.10' KB 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49A/M-40 9. Permit number 97-57 10. APl number 50-029-21735-02 11. Field/Pool Endicott Field/Endicott Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13390' feet Plugs (measured) 10247' feet 13370' feet Junk (measured) 10231' feet ORIG!klAL Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB C o n d u otc r 122' 30" Driven 161' 161' Surface 2476' 13-3/s" 3495 c.f. Permafrost 2515' 2514' Intermediate 8449' 9-5/8" 860 c.f. Class 'G' 8485' 6904' Production 5098' 7" 410 c.f. Class 'G' 8289'-13387' 6808'-10244' Liner Perforation depth: measured 13079'-13089'; 13132;13156, 13230;13240'; 13258`"13278'(Open) 13156;13166', 13178;13210', 13240'-13245, 13260'-13280' (Squeezed)¢~ f_C' ~, ~i~ ..... .r ( E true vertical (Subsea) 9953'-9962', 9995'-10013, 10070-10078; 10092-10107 (Open) .... ~' ~'-'' ~. 10013'- 10020', 10030'- 10055', 10078'- 10082', 10093`" 10109' (Squeezed;t /A i¥ ~.. 9 Tubing (size, grade, and measured depth)4-1/2", 12.6~, L-80 tubing set to 12792' ~'.Lfask, a Oil ,¢, Packers and SSSV (type and measured depth) 7" BaRor ZXP Liner Packer set at 8288', 7" Baker SB-3 PackCk(~O~61. D) 12694' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended__ Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~k//'~ ~~4],4' Title ~/-o o('q FOR COMMISSION USE ONLY Date 1/28/99 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test ¢"' Subsequent form required 10- ~ ~ ~ ~ ¢~;~,¢¢- ~)~IGINAL SIGNED-BY -60°~ Approved by order of the Commission Robert N. Chdsterlsofl ,~997q~,~o,e..~£, ~Commissioner Form 10-403 Rev 06/15/88 IAppr°va' N°i,.~~~)/ ? SUBMIT IN TRIPLICATE Application for Sundry Approval Request for 3-49A/M-40 Conversion to Water Injection 3-49a/M-40 well is a flow unit FIV, Fill and FII producer with a daily production rate of approximately 300 bopd at 78% water cut and solution GOR. Well 3- 49/M-40 has historically been a consistent Iow rate, Iow GOR producer with a water cut that has ranged between 60% and 85%. A production log run on March 1998 indicated zero contribution from the FII interval, suggesting pressure depletion. This is the same interval that has been identified in well 4-46 as having no contribution to production. It is anticipated to make 3-49A and 4-46 an injector/producer pair. The initial post squeeze re-peRoration strategy will target the FII sands only. Operationally we will l) perform the cement squeeze 2) get a cement bond log 3) re-perforate the well 4) begin water injection in the well 5) probably inject MI in the well at a later date (it is currently #8 in priority for MI injection) STATE Of ALASKA ALA~C'~.OIL AND GAS CONSERVATION COMMIS~'""~N REPORT SUNDRY WELL OF_RATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612,~ Anchoracle, Alaska 99519-6612 4. Location of well at surface 2499' SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 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 13390' feet 10247' feet 5. Type of Well: Development .. Exploratory __ Stratigraphic Service ~ Plugs (measured) 6. Datum elevation (DF or KB) 53.10' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49AIM-40 9. Permit number/approval number 97-57 10. APl number 50- 029-21735-02 11. Field/Pool . . -., ~lic¢~ ~ief~ndicott Pool 13370' feet Junk (measured) 10231' feet Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2476' 13-3/8" 3495 c.f. Permafrost 2515' 2514' 8449' 9-5/8" 860 c.f. Class 'G' 8485' 6904' 5098' 7" 410 c.f. Class 'G' 8289'-13387' 6808'-10244' measured 13079'-13089'; 13132'-13156, 13230'-13240'; 13258'-13278' (Open) 13156'-13166', 13178'-13210', 13240'-13245, 13260'-13280'(Squeezed) true vertical (Subsea) 9953'-9962', 9995'- 10013', 10070'- 10078'; 10092'- 10107' (Open) 10013'-10020', 10030'-10055', 10078'-10082', 10093'-10109'(Squeezed) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing set to 12792' Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 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 Tubing Pressure 36O 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. Form 10-404 Rev 06¢~15/88 Date 7/30/98 SUBMIT IN DUPLICAT~ BPX Endicott Production Engineering Department DATE: 7/14198 WELL N°: 3-49a/M-40 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT Lovelace HB&R TIME OPERATIONS SUMMARY 0933 RIG UP HB&R AND P-TEST LINES TO 3500 PSIG SIP=2600 IA=400 OA=0 0935 PUMPED 50 BBLS OF DEISEL 0942 PUMPED 405 BBLS OF SEA WATER 1139 HOLD 2500 PSI ON IA FOR 30 MINUTES: GOOD TEST 1210 BLEED DOWN IA TO FLOW LINE PRESSURE IA=2600 SIP=280 OA=0. 1215 RIG DOWN HB&R. PUMP SUMMARY: PUMPED 25 BBLS OF DIESEL AND 405 BBLS OF SEA WATER THE WATER HAD CORROSION INHIBITOR AND H20 SCAVENGER IN IT PRESSURE TESTED TO 2500 PSI FOR 30 MINUTES. TEST GOOD 4/30/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 111034 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 1-41/O-23 L~L ~ INJECTION PROFILE 9803'26 I 1 1-51 IV-20 ~l (.., INJECTION PROFILE 980330 I 1 2-04/M-19 ~t f,.. PRODUCTION PROFILE 980404 I 1 2-04/M- 19 4~ DEFT LOG 980404 I 1 2-34/P-14 I~ ~ INJECTION PROFILE 98041 I I 1 3-31/K-32 PRODUCTION PROFILE W/DEFT 980322 1 1 3- 39 A/I - 37 PRODUCTION PROFILE W/DEFT 980406 1 1 3-49A/M -40 PRODUCTION PROFILE W/DEF'.T 98031 2 I 1 3-49A/M-40 DEFT LOG 980312 I 1 3-49A/M-40 GAS LIFT SURVEY 980312 I 1 4- 08/P- 27 Ck ( C.~ INJECTION PROFILE 980323 I 1 4-10 / M - 28 PRODUCTION PROFILE 980407 I 1 4-14/R - 34 I,&t f~ INJECTION PROFILE 980401 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Al(.a~a 99618-1199~ Received~:~~ ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11675 Company: Field: Alaska OII & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 12/29/97 Well Job # Log Description Date BL RF Sepia LIS Tape 1-47A/M-20 SET EZSV RECORD 971 1 18 I 1 1-47AIM-20 BACKOFF REPORT 9 71 2 0 9 I 1 3-09A/L-28 PRODUCTION PROFILE 971218 1 1 3- 2 7/M- 33 LEAK DETECTION LOG 9 71 2 08 I 1 3-39A/I-37 PERFORATING RECORD/GR 971 106 I 1 3-3 9AII-3 7 PERFORATION RECORD 971217 I 1 3-49AIM-40 PERFORATING RECORD 971 106 1 , , 4- 421P- 38 PRODUCTION PROFILE 971 10 7 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: REGEIV U Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 12/8/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11619 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 1 - 01/J- 19 TUBG.PATCH SET RECORD 971 01 6 I 1 1 - 1 9/I- 18 PERFORATION RECORD 970901 I 1 1-1 9/I-18 PRODUCTION PROFILE 971010 I 1 1 - 31 ! M - 21 PERFORATING RECORD 9 710 04 I 1 1 - 33 / M - 23 ~ PERFORATING RECORD 971004 1 1 1-43/P-26 ~, ~_ INJECTION PROFILE 970910 I 1 1 - 67/T- 2 0 PERFORATING RECORD 971 013 I 1 2-44/R-12 [~.{ C.~ JET CU'I-rER RECORD 971 003 I 1 2- 44 A/Q- 11 USlT/CEMENT CORROSION LOG 971 006 I 1 3-17 B/M-31 PLUG SET RECORD 97091 8 I 1 3-17B/M-31 PRODUCTION LOG 971014 I 1 3-17B/M-31 GAS LIFT SURVEY 971014 I 1 3-45/M-39 ~,-I ~-- INJECTION PROFILE 971029 I 1 '3- 49 A ! M- 40 PRODUCTION PROFILE 97071 4 I 1 '4-1 0/M-28 ~'~ - O~ C) PERFORATING RECORD 971 012 I 1 4-38!K-34 PERFORATION RECORD 970914 I I <~;~' o~-I ,c,57 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 · 'X:_,. ,. . , ti' Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASK~---..OIL AND GAS CONSERVATION COMMISSIOn's- REPORT O. SUNDRY WELL OPEI-.,-tTIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing m Repair well__ Perforate_x_ Other..__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoracle, Alaska 99519-6612 4. Location of well at surface 2499' SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 53.10' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49AIM-40 9. Permit number/approval number 97-57 10. APl number 50- 029-21735-02 11. Field/Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical 13390' feet 10247' feet Plugs (measured) Effective depth: measured 13370' feet true vertical 10231' feet Junk(measured) Casing Length Size Cemented Measured depth Structural BKB Conductor 122' 30" Driven 161' Surface 2476' 13-3/8" 3495 c.f. Permafrost 2515' Intermediate 8449' 9-5/8" 860 c.f. Class 'G' 8485' Production 5098' 7" 410 c.f. Class 'G' 8289L 13387' Liner Perforation depth: measured 13079'-13089'; 13132'-13156, 13230'-13240'; 13258'-13278'(Open) 13156'-13166', 13178'-13210', 13240'-13245, 13260'-13280'(Squeezed) true vertical (Subsea)9953'-9962~ 9995L10013~ 10070L10078~ 10092c10107'(Open) 10013'-10020~ 10030L10055~ 10078L10082~ 10093L10109'(Squeezed) True vertical depth BKB 161' 2514' 6904' 6808'- 10244' RECEIV NOV 19 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing set to 12792' Alaska 0il & Gas Cons. C( Anchorage Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 358 19 695 0 321 Subsequent to operation 307 5 875 0 321 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoina is true and correct to the best of my knowledge. Signed Title Senior Technical A.~.qi~t~nt IV Form 10-~-0~-Rev 06/15/88 - ' Date 11/14/97 SUBMIT IN DUPLICATE ED BPX Endicott Production Engineering Department ADD-PERFORATION DATE: 11/06/97 WELL N°: 3-49a / M-40 BP EXPLORATION REP: SERVICE COMPANY: R. Clump SWS (S. Deckert) DATE/TIME OPERATIONS SUMMARY 1400 Miru SWS. FWHP= 350 psig, FWHT= 104 deg F, Choke= 104 beans, lAP= 1700 psi~l, & OAP= 0 psi~l. Cable head is leaking. Tie new head. 1500 Safety Meeting. Continue radio silence at SDI. 1520 Shut in well. Rih w/Gun #1 (3-3/8"× 20' DP gun, 6spf) Distance from CCL to TS = 6'. 1645 Out tail. Have large pickup vvt >2500 #. Pop well and Rih. Log Tie in strip from 13280-13050' md bkb. Tied into Jewelry Log dated 22 April 1997. Log confirmation strip. Log into firing position @ 13252' md bkb CCL depth. 1720 Shoot Gun #1 from 13258'-13278' md bkb. No big signs. Log off. Shut-in well & Pooh. 1900 OOH. Confirm all shots fired. 1945 RDMO. POP w/GL. PERFORATION SUMMARY: GUN # DEPTH 1 13258' - 13278' LENGTH SUBZONE 20' Fii All perforations shot w/3-3/8" HSD, 34BHJ II, 20.5 gm, 0.4 EH, & 21.9" penetration, 60 degree phasing, w/random orientation. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11556 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 1 1/1 4/97 Well Job # Log Description Date BL RF Sepia LIS Tape 1-17A/I-17 PRODUCTION PROFILE LOG 970828 I 1 1 - 21 / K- 25 PERFORATING RECORD 97081 7 I 1 2-12/Q-16 D~I ¢._ INJECTION PROFILE LOW RATE W/PSP 970822 I 1 2-12/Q-1 6 ~ INJECTION PROFILE HIGH RATE W/PSP 970822 I 1 2-14/O - 1 6 PERFORATING RECORD 97081 5 I 1 3-17 B ! M- 31 PRODUCTION LOG 970811 I 1 3-17B/M-31 GAS LIFT SURVEY 970811 I 1 3-39A/I-37 PERFORATE RECORD 970804 I 1 3- 49 A / M- 40 PERFORATING RECORD 970806 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11534 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 11/7/97 cji/. o~"i ~i~. oS'O Well Job # Log Description Date BL RF Sepia LIS Tape 2-1410-16 CHEMICAL CUTTER 970731 I 1 2-46A/R-10 CHEMICAL CUTTER RECORD 97071 6 I 1 3 - 17 A/J - 30 CHEMICAL CUTTER RECORD 970608 I 1 3 - 17 B / M- 31 PLUG SET RECORD 970612 I 1 3-17B/M-31 PERFORATION RECORD 970728 I 1 3-39A/I-37 PLUG SET RECORD 970527 I 1 3-39A/I-37 COLLAR LOG GPJCCL 97061 8 I 1 3 - 39 A / I - 37 PERFORATE RECORD 970620 I 1 3-49A/M-40 GAS LIFT SURVEY 97071 4 I 1 ., 4- 04/T- 2 6 INJECTION PROFILE LOG 970721 I 1 4-10/M-28 FULL SUITE PRODUCTION LOG 970708 I 1 ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~~ ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11407 Company: Field: Alaska OII & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3-49A/M-40 ~ '7~'7 97390 TDTP&GR/CCL 970424 I I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1 0/2/97 BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA .- REPORT O[ SUNDRY WELL OPER,- TIONS 1. Operations performed: Operation shutdowns__ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well Perforate X Other X 2. Name of Operator BP Exl)loration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora~Te, Alaska 99519-6612 4. Location of well at surface 2499'SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957' SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084' WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) 53.10' KB feet Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49A/M-40 9. Permit number/approval number 97-57 10. APl number 50- 029-21735-02 11. Field/Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical ~Effective depth: measured true vertical 13390' feet 10247' feet 13370' feet 10231' feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Length Size Cemented Measured depth BKB True vertical depth BKB Conductor 122' 30" Ddven 161' 161' Surface Intermediate Production Liner Perforation depth: 2476' 13-3/8" 3495 c.f. Permafrost 2515' 8449' 9-5/8" 860 c.f. Class 'G' 8485' 5098' 7" 410 c.f. Class 'G' 8289'-13387' measured 13079'-13089'; 13132'-13156, 13230'-13240' (Open) 13156'-13166', 13178'-13210', 13240'-13245, 13260'-13280' (Squeezed) true vertical (Subsea)9953'-9962~ 9995'-10013~ 10070'-10078'(Open) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing set to 12792' 2514' 6904' 6808'-10244' R'EGEI! 10013'-10020', 10030'-10055', 10078'-10082', 10093'-10109'(Squeezed) /~l~$~t.0jJ.& Gas Cons, Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 13. Stimulation or cement squeeze summary Add Perforation (8/6/97), Scale Inhibitor Treatment (8/16/97) Intervals treated (measured) 13079'-13089'; 13132'-13156, 13230'-13240', 13156'-13166', 13178'-13210', 13240'-13245, 13260'- 13280' Treatment description including volumes used and final pressure ~¢b~,f.,~i.o/w/~,c,s¢¢~,..~..~,¢vo.~. ¢¢b~f..w w,~.c~s/.~°/~ ~. ovo./.., o¢.w w/o=. NE-18 r~n-ionic surfactant, 226 bbls sw tubing displacement, f~whp=550 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 295 43 688 0 877 1455 2045 0 Tubing Pressure 308 306 15. Attachments Copies of Logs and Surveys run .. Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby_., certify t~hat4he foregoing~s., . .~' true and correct to the best of my knowledge, Form 10-4~4 Rev 06/15/88 ' Date 8/19/97 SUBMIT IN DUPLICATE '97 .Cqrrl~[SSiu BPX Endicott Production Engineering Department DATE: 8/6/97 WELL N°: 3-49a/M-40 BP EXPLORATION REP: VARBLE SERVICE COMPANY: SWS (S. Deckert) ADD PERF TIME OPERATIONS SUMMARY 1500 MIRU SWS FWHP = 325 lAP = 700 CAP = 0 1550 Hold safety meeting. Call for radio silence. 1600 Arm gun 1625 Shut in well & RIH with GR-CCL/3-3/8" gun ( 10' ) 1730 Out TT. Open choke & bleed well down. 1740 Log tie in pass. Add 6'. Tie into Perf Icg dated 5/22/97 1745 Log confirmation pass. Line tension erratic. Take out 2'. Log again. Within 1 '. Add 1'and re-log. 1808 Log into place. On depth. Hang CCL @ 13225.5' md. (4.5' from CCL to top shot) 1810 Shoot gun from 13230'-13240' md. Good cap break & lost 200 Cf weight. 1813 Log off. POOH. 1901 CCH. 1916 Confirm all shots fired. Lift radio silence. 2030 RDMO. Return well to production & request well test ASAP. Perforation Summary: Perforation Interval Length Zone 13230'-13240' 10' FI I All perforations were shot w/3-3/8"HSD @ 6 spf, 60 deg phasing w/random orientation. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11246 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2-28/P-19 PROD. PROFILE W/DEFT 970501 I 1 3 - 09 A ! L- 28 PERFORATION RECORD 9 70508 I 1 3- 39 ! J - 39 CHEMICAL CUTTER RECORD 970521 I 1 3-49AIM-40 PROD. PROFILE W/DEFT 970506 I 1 3-49A/M-40 GAS LIFT SURVEY 970506 1 1 3-49AIM-40 PERFORATION RECORD 9 70528 I 1 4-50!K-41 GAS LIFT SURVEY 970502 I 1 4-501K-41 PROD. PROFILE W/DEFT 970502 I I 8/1 4/97 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA O.-z'!? AND GAS CONSERVATION COMMISSION REPORT et SUNDRY WELL OPER,- TIONS 1. Operations performed: Operation shutdown__ Stimulate X Plugging__ Pull tubing__ Alter casing __ Repair well Perforate X Other__ 2. Name of Operator BP ExlNoration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora_~Te, Alaska 99519-6612 4. Location of well at surface 2499'SNL, 610' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2957'SNL, 5266' WEL, SEC 10, T11N, R17E, UPM At effective depth 2920' SNL, 5084'WEL, SEC 10, T11N, R17E, UPM At total depth 2915' SNL, 207' EWL, SEC. 10 T11N, R17E, UPM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ ORIGINAL Datum elevation (DF or KB) 53.10' KB feet Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49A/M-40 9. Permit number/approval number 97-57 10. APl number 50- 029-21735-02 11. Field/Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13390' feet 10247' feet Plugs (measured) 13370' feet Junk (measured) 10231' feet Casing Structural Length Size Cemented Measured depth True vertical depth BKB BKB Conductor Surface Intermediate Production Liner Perforation depth: 122' 30" Driven 161' 161' 2476' 13-3/8" 3495 c.f. Permafrost 2515' 2514' 8449' 9-5/8" 860 c.f. Class 'G' 8485' 6904' 5098' 7" 410 c.f. Class 'G' 8289'-13387' 6808'-10244' measured 13079'-13089';,3,32'-,3156(Open) ECE'I 13156'-13166', 13178'-13210', 13230'-13245, 13260'-13280'(Squeezed) true vertical (Subsea) 9953'-9962', 9995'-10013' (Open) Tubing (size, grade, and measured depth) 4-1/2", 12.6tt, L-80 tubing set to 12792' 10013'-10020', 10030;10055', 10070'-10082', 10093'-10109'(Squeezed) Alaska0iJ&Gas¢0ns. C Anchorage Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer set at 8288', 7" Baker SB-3 Packer (3.952" I.D) set at 12694' 13. Stimulation or cement squeeze summary WSO/Cement Squeeze (5/23/97); Post squeeze perfs (5/28/97) Intervals treated (measured) 13079'-13089'; 13132'..13156', 13156'.-13166', 13178'-13210', 13230'-13245, 13260'-13280' Treatment description including volumes used and final pressure see attached 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 987 754 4O23 0 416 951 996 120 0 323 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 foregojn'g is true and correct to the best of my knowledge. Signed Title 5;~nior T~chnic~l A~i_~hant IV Form 10-4041FJev 06/15/88 ~' V Date 8/6/97 SUBMIT IN DUPLICATE .. :~rnmission~ WSA PRODUCTION TEAM To: Endicott Reservoir, Anchorage Date: 5-23-97 3-49 NRW~, Water Shutoff From: Re: 5 -23 -97 Time Operational Summary 07:00 MIRU Dowell CTU #6, ctu vol. 33.3 bbls, FWHP-300, IAP-700, OAP-0, FWHT-118. S/I well. 07:20 Pick up injector, make up fn, 3.5" jetting nozzle 08:00 POP, Safety mtg. 08:30 Pressure test 4000 ct, hope's, standing line to squeeze unit. Recover meth, lose pump to high temp sensor, s/d. Wait on Dowell pump. 09:53 RIH, Press test Dowell lines 4000. 16:00 Couldn't get cement to meet specs, had one API FLUID LOSS OF 90, tried second test with a 83 fluid loss. Dumped cement will try again in morning. 5-24-97 06:00 Rig up Dowell 06:45 Press test 4000. 06:55 Recover meth 07:15 RIH, SIWHP-500, IAP-680, OAP-0 5-23-97 TIME CTD WHP CTP RATE VOL RTNS COMMENTS 10:28 4100 290 210 .5 15 Start FSW down ct. 11:46 12500 300 100 .5 50 Pull test 21.8k., 11.9k down. 12:01 13368 310 100 .4 53 Slow to minimum. Tag TD @ 13368, place flag 13355. 12:16 13355 310 2550 2.3 60/0 Safety meeting about acid, come on line with acid. 12:20 13355 310 2700 2.4 10/0 Switch to SW 13355 310 5/0 Switch to coil pumps 12:30 13355 310 18 Acid at nozzle, reciprocate pipe 12:40 310 28 Water at nozzle, reciprocate, chase acid to tailpipe. 12:56 12720 305 1350 2.0 71 RIH, go to minimum. 14:01 13020 300 60 .2 80/0 S/I well, start BH kill. 14:08 13020 280 350 5.5 10 14:19 500 30 5.4 83 Caught f/1. 14:35 3040 3.8 160 14:52 3250 3140 2.7 206 206 SW on perfs. 15:33 2650 2600 1.0 310 S/D 15:43 500 510 0 310/0 Prepare for acid. 15:48 13020 690 2600 1.9 0 Crack choke to circulate acid to nozzle. 15:57 690 2800 2.0 15/0 Switch to sw. 16:02 690 2900 2.0 5/0 Switch to ct pump. 16:10 13080 2630 3300 1.0 13 Acid @ nozzle, close chokes, recip across perfs. 16:18 13300 570 1640 1.0 23 PUH 16:23 13075 260 1410 1.0 28 , h Injectivity 1 bpm @260, start mixing cement. 16:44 30 30 0 28/0 Cement up to wt. Press test t in b/s line. Come on line to cool sump 17:10 13320 100 3780 2.4 40 AP1 FLUID LOSS=90 cc~ SECOND ~ TEST 83~ FC THICKNESS= 1"~ dump and regroup. 19:18 13320 400 1120 1.0 306/0 Decrease rate to 1.0 bpm, do injectivity test 19:25 13320 100 250 .2 0 POOH, pumping minimum, switch to meth. 21:00 0 0 0 0 38 OOH, LDFN. 5-24-97 07:47 2000 300 1500 1.5 0 Start circulating out gas. 09:03 10200 170 2850 2.0 118 09:24 12500 110 2740 2.0 161 Pull test 20.0 k 09:37 13320 100 2600 2.0 180 Check flag, pumpl5 bbl check injectivity. 1 bpm@ 380 psi, release pressure, cool down sump, start batching up cement. 10:17 13330 110 3050 2.0 256 Still gas in rtns. Cement u[ to weight. 11:02 13320 100 1200 1.25 353 Cement in f/1 cell. 45 cc API f/l at 10 minutes. 11:42 13080 100 1225 1.25 404 F/1=46 cc, f.c..68 prepare to pump. 12:06 13140 220 3440 2.3 428/0 Start with ew, cement in live cell. 12:13 13220 50 800 1.0 10/0 Switch to cement. 12:20 13320 60 3211 1.7 10 12:26 3300 60 2080 1.4 20/0 Switch to EW 12:32 13330 60 2290 1.6 10/0 23.3 Switch to gel water 12:32 1 24.25 12:33 13533 55 2169 1.7 2 25.3 3 12:34 13330 56 4 26.5 Cement @ nozzle 12:35 13318 5 27.25 12:35 13316 61 6 28 12:36 13320 59 1453 1.5 7 29 12:37 8 8.5 restart returns 12:38 13234 62 1358 1.5 9 9.7 perf covered 12:40 13190 62 12 10.5 12:40 13157 64 1309 13 11.5 perf covered 12:41 13139 65 1293 1.5 14 12.5 12:41 13120 64 1305 1.5 15 13.25 12:42 13090 1316 1.5 16 14.25 12:43 13057 221 1455 1.5 17 15.25 Start applying pressure. 12:43 13042 217 1500 1.5 18 15.75 12:44 13028 211 1530 1.5 19 16.75 12:45 13020 210 1577 1.5 20 17.75 12:45 13000 381 1691 21 18.75 PLF ~ tI~ F l~ ! \,t ~ 1'~ 12:46 12907 442 1723 1.5 22 18 ~ I,, N., L. I ~t t.. 12:46 12822 421 1015 1.5/1.0 23 20 12:48 12740 410 1053 1.0 24 20.75 ~1_~ ~ ~ 1~,~ 12:49 12646 423 1090 1.0 25 21.5 p3aska 0il & Gas Cons. Anch0rage 12:49 12604 -398 1079 1.0 26 22.25 Park coil 12:51 12604 398' 1073 1.0 27 23.25 Ramp to 1000 psi 12:51 12604 947 1518 1.0- 28 24 12:52 12604 1000 1589 1.0 At 1000 psi. 12:53 12604 1000 1590 1.0 29 24.75 12:54 12604 1/.5 30 25.75 12:54 12604 1023 1229 .5 31 12:55 12604 1176 1372 .5 Ramping to 1500 psi 12:56 12604 1456 1500 .5 31 26.5 41 API cc on live cell, 8.5 mils 12:58 12604 1516 1725 .5 32 27.25 13 mils 13:00 12604 1525 1731 .5 33 28.25 Ramping to 2500 psi 13:01 12604 2441 2540 .5/0 34/0 28.5 Shut down. Switch to Coil pump 13:04 12604 2398 2600 .5 0 Ramping to 3000 psi. 13:05 12604 3000 3178 .5 1 1 13:07 12604 3000 3179 .5 24 mils on live cell, should equate to 71 mm of filter cake. 13:08 12604 3022 3218 .5 2 2.25 13:09 12604 3090 3286 .5 Ramp 3500 psi. 13:10 12604 3524 3708 .5 3 3 13:12 12604 3502 3670 4 3.75 13:14 12604 3527 3705 .5 5 4.75 PUH 13:15 12600 3500 3680 .5 13:16 12600 3508 3697 .5 6/0 5.75 13:17 12600 3500 3470 .5 Come offline - trap pressure. 32 mils in live cell. 12600 3477 3489 0 JFT, release pressure to 2000 13:49 12600 1700 0 0 Start rih reversing. 14:18 12870 1980 0 1.5 57 Dirty 14:26 12900 1960 0 1.4 68 15:00 13070 2030 40 1.4 113 16:04 13330 1870 45 1.3 197 16:36 13320 1780 45 1.6 241/0 S/D, press test, leaks 500 psi in 3 minutes., Switch lines to jet perfs. 16:40 13200 1500 3620 1.8 2 Jet perfs 16:58 12600 1500 3660 1.8 39 Start down 17:37 1330 1775 60 1.8 61/0 POOH reversing, total of 11 bbl of cement returns. 18:22 10500 2160 2210 0 83/0 Pressure test, flowline pressure holding at 320, 600 spi in 20 minutes, 30 psi/minute.. 5 bbl.s to bump back up to 2160. POOH, pumping meth. 19:55 100 1450 1470 1.0 38 OOH, RD. FLUID SMUMMARY 5-23 145 bbls. 25 bbls. 310 bbls. 15 bbls. 306 bbls. 5-24 FSW RIH and sump cleanout. 15%HCL W/10% XYLENE FSW to bullhead kill. Acid FSW, cool down 428 10 20 10 43 241 61 83 bbls. bbls. bbls bbls bbls bbls. bbls bbls. FSW for cool down FSW Cement EW SW SW reverse SW jetting SW second reverse pass CEMENT (DUMPED) D047 antifoam .20gal/sk Do65 dispersant .50 % BWOC D110 retarder 1.0% BWOC D156 fluid loss 1.0% BWOC API fluid loss was 90 cc with .92-.97" filter cake thickness (Field) CEMENT D020 1.0 BWOC D047 antifoam .20gal/sk Do65 dispersant .50 % BWOC D110 retarder 1.0% BWOC D156 fluid loss 1.0% BWOC API fluid loss was 51 cc with .71" filter cake thickness (lab) ACID xylene 10% U74 dispersing agent 1.5% A261 Inhibitor .6% A179 Inhibitor 1 4#/1000 gal L-58 Iron Stabilizer 20~/1000 gal A153 Inhibitor 8#/1000 gal SUMMARY 5-23 RIH and tag TD @ 13368. Cleaned sump with 15 bbls. Of 15% HCL, chased acid to tailpipe and reciprocated nozzle back to sump. Flowed well for 1.5 hours. Bullhead kill well with 310 bbls of FSW. Injectivity was down to lbpm @2600 psi. when 310 bbls. were pumped. Pumped 15 bls. of acid into perfs and overdisplaced. Injectivity was 1 bpm @ 260. Cement f/1 was 90. This was out of spec. Ran another test and had 82 cc, filter cake thickness was .97". Decided to abort for night. POOH and LDFN. 5 -24 -97 RIH and circulate killed well with 428 bbls. ofFSW. Injectivity was 1 bpm @ 380 psi. Cement fluid loss was 46 cc, filter cake was .71". Decided to pump. Laid 20 bbls of cement in from 13330, 9 bbls to cover perfs. Ramped presure to 3000 psi in 23 minutes, to 3500 in 30 minutes. No dramatic breaks in ramp up. Flatlined JFT 3500 for 30 minutes and released to reverse circulate. Reversed out 11 bbls of cement. Presure tested well 2100, bled 500 psi in 4 minutes. Jetted well and performed a second reverse out, very little cement in second reverse out. A total of 11 bbls. of cement recovered. Pressure tested 2150 second time, lost 600 psi in20 minutes. Injectivity less than. 1 bpm @ 2000 psi. Discussed options with PE Supervisor, POOH leaving well full of SW with 100' of methanol. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil I--] Gas [] Suspended [~ Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-57 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612¢-%;~ ~,~.- ...... -.. ~ 50-029-21735-02 4. Location ofwell at surface .~ ,,u~.,,,-: ~:¢;~Ji'! '~~ 9. Unit or Lease Name -" ~'~ ,~ '~' ¢. ' ' ~41~.1~%A I1~11~.~1~~ 2499' SNL, 610' WEL, SEC. 8, T11 N, R17E, UPM ...... "' ::' ~~1~-,,~'~1 Duck Island Unit/Endicott At top of productive interval i~2-.-~ .~ ]~, 110' Well Number1. 2939' SNL, 95' EWL, SEC. 10, T11N, R17E, UPM .i 3-49A/M-40 At total depth ,~ -' ..¥7¥- t Field and Pool 2915' SNL, 207' EWL, SEC. 10, T11 N, R17E, UPM ' Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.10'I ADL 047503 12. Date Spudded 113. DateT. D. Reached I 14. Date Comp., Susp., or Aband.ll 5. Water depth, if offshore 16. No. of Completions 4/5/97I 4/13/97! 4/22/97I N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121 · Thickness of Permafrost 13390 10247 FTI 13370 10231 FTI []Yes I~No (nipple) 1502' MD 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD DIL/CDT/CNL/GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 161' Driven 13-3/8" 68# L-80 Surface 2515' 17-1/2" 3495 c.f. Permafrost 9-5/8" 47# NT80S/NT95HS Surface 8485' 12-1/4" 860 c.f. Class 'G' 7" 29# L-80 8289' 13387' 8-1/2" 410 c.f. Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12792' 12694' MD TVD MD TVD 13230'-13245' 10124'-10135' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 35 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 23, 1997I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-EEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kekiktuk 13040' 9977' LS2 13080' 10008' Fill 13134' 10050' FII 13210' 10108' '~1. List of Attachments Summary of Daily Drilling Reports, Surveys, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed SteveShultz¢~/~./_.~ 1~ ~ ¢~- ~.¢~.~.,~. Title Senior Drilling Engineer Date ~f/¢//-C~F 3-49A/M-40 97-57 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 31 Mar 97 01 Apr 97 02 Apr 97 03 Apr 97 04 Apr 97 End SDI 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-03:00 03:00-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-13:00 13:00-14:30 14:30-15:30 15:30-16:00 16:00-19:30 19:30-23:30 23:30-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:30 11:30-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-01:30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-11:00 11:00-11:30 Duration 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3hr 1/2 hr 1/2 hr 1/2hr lhr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3hr 3-1/2 hr 1-1/2 hr lhr 1/2 hr 3-1/2 hr 4hr 1-1/2 hr 1/2 hr 1/2 hr 1/2hr 3-1/2 hr 1/2hr 1/2 hr 3-1/2 hr lhr 3-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 4hr 1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2 hr lhr 3hr 3hr lhr lhr 2-1/2 hr 1/2 hr lhr 2-1/2 hr lhr 1/2 hr Progress Report Well 3-49A/M-40 Rig Doyon 15 Page Date Activity Rig moved 60.00 % Held safety meeting Rig moved 100.00 % Skid rig Fill pits with Seawater Rigged up Lubricator Retrieved Hanger plug Rigged down Lubricator Circulated at 12950.0 ft Installed Hanger plug Removed Xmas tree Retrieved Adapter spool Rigged up All functions Held safety meeting Rigged up All functions Tested All functions Removed Hanger plug Removed Tubing hanger Circulated at 12950.0 ft Held safety meeting Rigged up High pressure lines Circulated closed in well at 12950.0 ft Rigged down High pressure lines Flow check Rigged up Tubing handling equipment Laid down 3500.0 ft of Tubing Held safety meeting Serviced Top drive Laid down 9450.0 ft of Tubing Installed Wear bushing Set downhole equipment (wireline) Tested Casing Ran Drill collar to 688.0 ft (6-3/4in OD) Held safety meeting Ran Drillpipe in stands to 3924.0 ft Serviced Block line Ran Drillpipe in stands to 8635.0 ft Circulated at 8635.0 ft Pulled out of hole to 8480.0 ft Worked toolstring at 8487.0 ft Held safety meeting Worked toolstring at 8525.0 ft Held safety meeting Worked toolstring at 8530.0 ft Circulated at 8530.0 ft Pulled out of hole to 687.0 ft Pulled out of hole to 0.0 ft Serviced BOP stack Ran Drillpipe in stands to 4000.0 ft Held safety meeting Ran Drillpipe in stands to 8635.0 ft Circulated at 8635.0 ft 'Mixed and pumped slurry - 55.000 bbl Pulled out of hole to 7488.0 ft 1 19 May 97 Facility Date/Time 05 Apr 97 06 Apr 97 07 Apr 97 08 Apr 97 09 Apr 97 10 Apr 97 End SDI Progress Report Well 3-49A/M-40 Rig Doyon 15 Page 2 Date 19 May 97 11:30-12:30 12:30-13:00 13:00-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:30 21:30-22:00 22:00-23:00 23:00-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-22:30 22:30-01:30 01:30-03:00 03:00-05:30 05:30-06:00 06:00-06:30 06:30-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:30 09:30-12:00 12:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-01:00 01:00-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 Duration lhr 1/2 hr 3hr 2hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr lhr 1-1/2 hr lhr 4-1/2 hr 1/2 hr lhr 10-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr 2-1/2 hr lhr 1/2 hr 3hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 7hr lhr 3-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 6hr 1/2hr lhr lhr 9-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 6-1/2 hr lhr 3-1/2 hr 1/2hr 1/2 hr 1-1/2 hr Activity Reverse circulated at 7488.0 ft Bullhead well Pulled out of hole to 0.0 ft Made up BHA no. 1 Held safety meeting Singled in drill pipe to 1934.0 ft Set Retrievable packer at 55.0 ft with 0.0 psi Installed Seal assembly Installed Wear bushing Serviced Block line R.I.H. to 7567.0 ft Washed to 8068.0 ft Drilled cement to 8432.0 ft Held safety meeting Drilled cement to 8485.0 ft Drilled to 8650.0 ft Held safety meeting Drilled to 8965.0 ft Held safety meeting Drilled to 9195.0 ft Circulated at 9195.0 ft Held safety meeting Pulled out of hole to 1557.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Made up BHA no. 2 R.I.H. to 8658.0 ft Washed to 9195.0 ft Held safety meeting Drilled to 9489.0 ft Serviced Mud pumps Drilled to 9750.0 ft Held safety meeting Drilled to 10710.0 ft Held safety meeting Drilled to 10721.0 ft Circulated at 10721.0 ft Pulled out of hole to 8433.0 ft R.I.H. to 10721.0 ft Drilled to 11060.0 ft Held safety meeting Drilled to 11110.0 ft Serviced Liner Drilled to 11571.0 ft Held safety meeting Drilled to 12130.0 ft Held safety meeting Drilled to 12268.0 ft Circulated at 12268.0 ft Pulled out of hole to 1557.0 ft Pulled BHA Held safety meeting Pulled BHA Facility Date/Time 11 Apr 97 12 Apr 97 13 Apr 97 14 Apr 97 15 Apr 97 End SDI Progress Report Well 3-49A/M-40 Rig Doyon 15 Page Date Duration Activity 08:00-09:00 09:00-12:00 12:00-13:00 13:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-06:00 06:00-06:30 06:30-08:00 08:00-11:30 11:30-12:00 12:00-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-20:00 20:00-21:00 21:00-01:30 01:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-23:00 23:00-00:00 00:00-00:30 00:30-02:00 02:00-05:00 05:00-06:00 lhr 3hr lhr 3hr 1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/2hr 1-1/2 hr 3-1/2 hr 1/2hr 3-1/2 hr lhr lhr 1/2 hr 2hr lhr 4-1/2 hr 4-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 3hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 3hr lhr Made up BHA no. 3 R.I.H. to 2800.0 ft Serviced Block line R.I.H. to 10254.0 ft Washed to 12268.0 ft Drilled to 12318.0 ft Held safety meeting Drilled to 12615.0 ft Held safety meeting Drilled to 12889.0 ft Circulated at 12889.0 ft Held safety meeting Pulled out of hole to 12254.0 ft R.I.H. to 12889.0 ft Drilled to 13111.0 ft Held safety meeting Circulated at 13123.0 ft Pulled out of hole to 8485.0 ft Circulated at 8485.0 ft Pulled out of hole to 1556.0 ft Pulled BHA Retrieved Wear bushing Held safety meeting Tested BOP stack Made up BHA no. 4 R.I.H. to 13127.0 ft Drilled to 13190.0 ft Held safety meeting Drilled to 13360.0 ft Held safety meeting Drilled to 13390.0 ft Circulated at 13390.0 ft Pulled out of hole to 11950.0 ft R.I.H. to 13390.0 ft Circulated at 13390.0 ft Pulled out of hole to 8485.0 ft R.I.H. to 13390.0 ft 06:00-06:30 06:30-07:00 07:00-07:30 07:30-09:00 09:00-09:30 09:30-15:30 15:30-16:30 16:30-17:30 17:30-21:30 21:30-22:00 22:00-23:30 23:30-01:30 01:30-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2hr 6hr lhr lhr 4hr 1/2 hr 1-1/2 hr 2hr lhr 2hr lhr 1/2 hr 1/2 hr Held safety meeting R.I.H. to 13300.0 ft Washed to 13390.0 ft Circulated at 13390.0 ft Flow check Pulled out of hole to 1556.0 fl Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 5 Tested LWD - Via string Made up BHA no. 5 R.I.H. to 8480.0 ft Serviced Block line R.I.H. to 10000.0 ft Held safety meeting 3 19 May 97 Facility Date/Time 16 Apr 97 17 Apr 97 End SDI Progress Report Well 3-49A/M-40 Page 4 Rig Doyonl5 Date 19May97 06:30-07:30 07:30-10:30 10:30-11:15 11:15-13:30 13:30-14:00 14:00-15:30 15:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:30 08:30-11:30 11:30-13:00 13:00-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-21:30 21:30-22:00 22:00-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-15:30 15:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:30 23:30-01:30 Duration lhr 3hr 3/4 hr 2-1/4 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr lhr lhr 4-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 3hr 1-1/2 hr 2-1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 4hr 2hr 2hr 1/2 hr 4-1/2 hr 1/2 hr lhr lhr 2hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 2hr Activity R.I.H. to 12901.0 ft Logged hole with LWD: Formation evaluation (FE) from 13050.0 ft to 13251.0 ft Worked stuck pipe at 13251.0 ft Reamed to 13291.0 ft Logged hole with LWD: Formation evaluation (FE) from 13251.0 ft to 13291.0 ft Reamed to 13386.0 ft Logged hole with LWD: Formation evaluation (FE) from 13291.0 ft to 13386.0 ft Pulled out of hole to 12430.0 ft Circulated at 12430.0 ft Held safety meeting Pulled out of hole to 1448.0 ft · Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Ran Liner to 3600.0 ft (7in OD) Held safety meeting Ran Liner to 5023.0 ft (7in OD) Installed Liner hanger Circulated at 5023.0 ft -- Ran Liner on landing string to 8432.0 ft Circulated at 8432.0 ft Ran Liner on landing string to 13380.0 ft Washed to 13384.0 ft Circulated at 13884.0 ft Held safety meeting Set Liner hanger at 8313.0 ft with 2200.0 psi Pumped Water spacers - volume 70.000 bbl Tested High pressure lines Mixed and pumped slurry - 71.500 bbl Displaced slurry - 328.000 bbl Set Tie back packer at 8288.0 ft with 0.0 psi Pulled Drillpipe in stands to 7338.0 ft Rigged down Additional services Laid down 5548.0 ft of 5in OD drill pipe Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 6 Held safety meeting Singled in drill pipe to 4774.0 ft Rigged up Drillstring handling equipment R.I.H. to 7470.0 ft Serviced Block hne R.I.H. to 13221.0 ft Drilled cement to 13299.0 ft Circulated at 13299.0 ft Tested Casing- Via annulus and string ~'~ Drilled installed equipment - Landing collar Held safety meeting Drilled cement to 13370.0 ft ....... Tested Casing - Via annulus and string Circulated at 13370.0 ft Cleared Flowhne ' '" Facility Date/Time 18 Apr 97 Apr 97 20 Apr 97 End SDI Progress Report Well 3-49A/M-40 Page 5 Rig Doyon 15 Date 19 May 97 Duration Activity 01:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-06:00 06:00-06:30 06:30-13:00 13:00-13:30 13:30-14:00 14:00-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 3-1/2 hr lhr 1/2 hr 1/2hr lhr 8-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr lhr 10hr 1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 2hr lhr lhr Filter Brine Laid down 1000.0 ft of 5in OD drill pipe Held safety meeting Serviced Draw works Repaired Drillstring handling equipment Laid down 12000.0 ft of 5in OD drill pipe Pulled BHA Held safety meeting Removed Wear bushing Rigged up Tubing handling equipment Ran Tubing to 7300.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 12792.0 ft (4-1/2in OD) Installed Tubing hanger Tested Dual control line Reverse circulated at 12792.0 ft Installed Tubing hanger Set Production packer at 12694.0 ft with 4000.0 psi Held safety meeting Tested Permanent packer Installed Hanger plug Removed BOP stack Installed Adapter spool Installed Xmas tree Tested Xmas tree Rigged up Lubricator Retrieved Hanger plug Freeze protect well - 35.000 bbl of Diesel Cleared Trip tank Rigged down ESD system BPX ' Endicott Production Engineering Department Initial Perforations DATE: 4/22/97 WELL N°: 3-49a/M-40 BP EXPLORATION REP: Varble/Eckstein/Clump SERVICE COMPANY: SWS (J. Majcher) DATE TIME OPERATIONS SUMMARY 4/22/97 1335 Miru SWS. Whp= 1500 psi, lap= 1400, & Oap= 0 psi. 1425 Safety Meeting. Call for radio silence. 1445 RIH with GR/CCL/3-3/8" x 20' HSC gun w/15' @ 6 spf 34 B Hyperjets (20.5 gms), w/60 deg phasing. 1515 See fluid level @ 5500'. 1630 Log tie-in pass.. 1700 Lose tool signal. Trouble shoot. Pooh. 1830 OOH. Gun-GR is all gassed up. 1945 Rih w/new GR/CCL/3-3/8' gun for 2"d attempt. 2230 Tied into MWD-GR dated 4/16/97. See marker jt @ 13300'md bkb. Rib to tag PBTD @ 13347' md bkb. Log into shooting position @ 13222.4' md bkb. 2258 Shoot Gun #1 from 13230-13245 md bkb. Good indications however no pressure change. Shot balanced? Log off & log jewelry. 2313 Pooh. See fluid level @ 5500' md bkb. 4/23/97 0001 OOH. All shots fired. Whp= 1650 psi. 0025 Bring well on w/1 mmscf gas lift. 1300 SWS RDMO. Perforation Intervals: Zone Interval Depth Length Fii 13230'- 13245' md bkb 15' Interval was perforated with 3-3/8", 6spf, 34 B Hyperjet II, 20.5 gm, EH= 0.4", TP= 21.9", @ 60 deg phasing, and random orientation. SPT Y-SUN DRILLING SERVICES ANCHORAGE ALASKA oS7 PAGE BP EXPLORATION INC. ENDICOTT SDI / 3-49A/M-40 500292173502 NORTH SLOPE BOUROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 041497 MWD SURVEY JOB NUMBER: AK-MM-70091 KELLY BUSHING ELEV. = 53.10 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8479.15 6901.98 6848.88 61 15 8480.00 6902.39 6849.29 61 15 8485.00 6904.79 6851.69 61 15 8506.84 6915.96 6862.86 57 12 8540.74 6934.89 6881.79 54 54 N 68.80 E .00 1114.26N 3097.12E N 68.80 E .00 1114.53N 3097.81E N 68.82 E .40 ll16.11N 3101.90E N 69.91 E 18.99 1122.73N 3119.46E N 71.72 E 8.10 1131.98N 3146.02E 2288.20 2288.71 2291.68 2304.52 2324.27 8578.84 6957.03 6903.93 54 1 8611.42 6975.93 6922.83 55 7 8642.49 6993.68 6940.58 55 10 8674.48 7012.11 6959.01 54 30 8706.17 7030.75 6977.65 53 27 N 73.90 E 5.21 1141.14N 3175.63E N 78.04 E 10.89 1147.57N 3201.37E N 80.84 E 7.40 1152.24N 3226.43E N 84.73 E 10.15 1155.53N 3252.37E N 87.68 E 8.23 1157.23N 3277.94E 2346.81 2367.08 2387.51 2409.34 2431.54 8738.70 7050.31 6997.21 8769.71 7069.08 7015.98 8803.15 7089.16 7036.06 8835.28 7108.30 7055.20 8866.93 7126.91 7073.81 52 38 S 88.55 E 9.60 1157.43N 3303.93E 52 52 S 84.22 E 11.14 1155.87N 3328.55E 53 18 S 81.00 E 7.81 1152.43N 3355.07E 53 35 S 76.99 E 10.06 1147.50N 3380.39E 54 25 S 71.55 E 14.16 1140.56N 3405.03E 2454.77 2477.56 2502.87 2527.78 2552.95 8899.62 7145.74 7092.64 55 13 8931.68 7164.21 7111.11 54 25 8963.39 7182.90 7129.80 53 20 8994.11 7201.13 7148.03 53 53 9026.38 7220.17 7167.07 53 45 S 67.70 E 9.92 1131.25N 3430.06E S 64.94 E 7.46 1120.74N 3454.06E S 61.25 E 10.00 1109.15N 3476.90E S 59.33 E 5.33 1096.89N 3498.38E S 57.17 E 5.42 1083.19N 3520.52E 2579.52 2605.70 2631.30 2655.99 2681.91 9057.47 7238.42 7185.32 54 21 9089.73 7256.98 7203.88 55 25 9120.81 7274.57 7221.47 55 40 9151.03 7291.61 7238.51 55 38 9241.42 7342.49 7289.39 55 50 S 53.55 E 9.62 1068.88N 3541.22E S 51.19 E 6.83 1052.77N 3562.12E S 46.66 E 12.05 1035.94N 3581.43E S 46.60 E .21 1018.80N 3599.57E S 46.85 E .33 967.59N 3653.96E 2706.80 2732.65 2757.41 2781.25 2852.65 9339.35 7397.58 7344.48 9436.51 7452.28 7399.18 9530.61 7504.65 7451.55 9626.60 7559.69 7506.59 9722.18 7616.93 7563.83 55 41 55 46 56 34 53 27 52 58 S 48.15 E 1.11 912.89N 3713.65E S 50.65 E 2.13 860.65N 3774.61E S 50.42 E .87 810.96N 3834.96E S 47.22 E 4.25 759.23N 3894.16E S 47.98 E .80 707.61N 3950.68E 2930.35 3008.09 3084.17 3160.12 3233.61 9818.68 7676.62 7623.52 50 35 9915.18 7738.06 7684.96 50 18 10011.83 7802.29 7749.19 46 22 10107.60 7868.73 7815.63 45 45 10203.41 7935.92 7882.82 45 12 S 45.76 E 3.06 655.80N 4006.03E S 46.88 E .94 604.41N 4059.84E S 45.25 E 4.26 554.34N 4111.85E S 45.94 E .84 506.08N 4161.12E S 46.86 E .89 458.98N 4210.58E 3306.14 3377.10 3445.86 3511.36 3576.53 ORIGINAL SPI Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION INC. ENDICOTT SDI / 3-49A/M-40 500292173502 NORTH SLOPE BOUROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 041497 MWD SURVEY JOB NUMBER: AK-MM-70091 KELLY BUSHING ELEV. = 53.10 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 10299.02 8003.59 7950.49 10395.01 8071.92 8018.82 10492.04 8141.37 8088.27 10588.78 8211.28 8158.18 10678.73 8277.05 8223.95 44 40 S 47.09 E .57 412.90N 4259.95E 44 33 S 48.95 E 1.37 367.80N 4310.06E 44 1 S 48.94 E .56 323.30N 4361.16E 43 26 S 51.16 E 1.70 280.37N 4412.41E 42 34 S 51.39 E .97 241.98N 4460.27E 3641.16 3706.02 3771.50 3836.44 3896.33 10782.82 8352.18 829 10879.08 8420.68 836 10973.89 8489.45 843 11065.55 8556.21 850 11162.91 8624.76 857 9.08 7.58 6 35 3.11 1 66 45 1 S 55.01 E 3.36 198.88N 4517.97E 44 15 S 55.43 E .86 160.31N 4573.52E 42 45 S 56.24 E 1.69 123.65N 4627.51E 43 45 S 57.13 E 1.28 89.17N 4679.99E 46 43 S 55.69 E 3.23 50.91N 4737.55E 3967.11 4033.98 4098.60 4160.91 4229.45 11257.90 8688.95 863 11351.97 8750.97 869 11447.55 8813.63 876 11542.83 8876.78 882 11638.82 8941.46 888 5 85 7.87 0 53 3.68 8 36 48 15 S 54.97 E 1.70 11.08N 4795.12E 49 15 S 52.84 E 2.01 30.585 4852.26E 48 49 S 53.61 E .76 73.795 4910.06E 48 9 S 55.41 E 1.58 115.215 4968.15E 47 6 S 56.41 E 1.34 154.975 5026.87E 4298.69 4368.34 4439.28 4509.67 4579.91 11733.63 9006.81 895 11828.28 9072.95 901 11927.19 9142.35 908 12022.97 9210.34 915 12119.11 9280.11 922 3 71 9.85 9.25 7.25 7.01 45 43 S 58.66 E 2.25 191.845 5084.80E 45 37 S 58.57 E .14 227.105 5142.60E 45 15 S 59.70 E .89 263.265 5203.09E 44 16 S 61.23 E 1.52 296.515 5261.77E 42 39 S 62.85 E 2.05 327.535 5320.17E 4648.16 4715.59 4785.83 4853.15 4919.25 12215.25 9352.48 12306.80 9422.34 12402.80 9494.00 12498.06 9564.38 12593.21 9635.74 9299.38 39 39 S 63.73 E 3.18 355.985 5376.68E 9369.24 40 51 S 61.61 E 1.99 383.155 5429.23E 9440.90 42 37 S 55.02 E 4.93 416.735 5483.52E 9511.28 42 9 S 60.87 E 4.17 450.805 5537.90E 9582.64 40 47 S 70.38 E 6.77 476.815 5595.13E 4982.52 5041.65 5105.19 5169.02 5231.86 12689.39 9709.21 12783.85 9781.38 12879.65 9853.85 12974.89 9926.47 13071.90 10001.67 9656.11 39 51 S 84.56 E 9.58 490.325 5655.54E 9728.28 40 42 N 83.18 E 8.43 489.535 5716.36E 9800.75 41 1 N 78.77 E 3.03 479.695 5778.23E 9873.37 39 35 N 79.45 E 1.57 468.055 5838.72E 9948.57 38 46 N 80.46 E 1.07 457.355 5899.07E 5292.04 5346.27 5397.46 5446.62 5496.06 13167.62 1007 13263.61 1014 13350.82 1021 13390.00 1024 5.67 10022.57 39 57 N 78.35 E 1.87 446.185 5958.73E 9.39 10096.29 39 42 N 77.38 E .70 433.265 6018.83E 6.64 10163.54 39 22 N 78.07 E .63 421.455 6073.08E 6.93 10193.83 39 22 N 78.07 E .05 416.325 6097.39E 5544.67 5592.92 5636.40 5655.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6111.59 FEET AT SOUTH 86 DEG. 5 MIN. EAST AT MD = 13390 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 116.17 DEG. TIE-IN SURVEY AT 8,479.15' MD idINDOW POINT AT 8,485.00' MD. PK~JECTED SURVEY AT 13,390.00' SP] Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION INC. ENDICOTT SDI / 3-49A/M-40 500292173502 NORTH SLOPE BOUROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 041497 JOB NUMBER: AK-MM-70091 KELLY BUSHING ELEV. = 53.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8479.15 6901.98 6848.88 9479.15 7476.26 7423.16 10479.15 8132.10 8079.00 11479.15 8834.44 8781.34 12479.15 9550.37 9497.27 1114.26 N 3097.12 E 838.29 N 3801.87 E 329.19 N 4354.40 E 87.90 S 4929.21 E 444.51 S 5526.87 E 1577.17 2002.89 425.72 2347.05 344.16 2644.71 297.66 2928.78 284.07 13390.00 10246.93 10193.83 416.32 S 6097.39 E 3143 . 07 214.29 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION INC. ENDICOTT SDI / 3-49A/M-40 500292173502 NORTH SLOPE BOUROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 041497 JOB NUMBER: AK-MM-70091 KELLY BUSHING ELEV. = 53.10 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8479.15 6901.98 6848.88 1114.26 N 3097.12 E 1577.17 8572.14 6953.10 6900.00 1139.63 N 3170.42 E 1619.04 41.87 8743.31 7053.10 7000.00 1157.25 N 3307.59 E 1690.21 71.17 8912.47 7153.10 7100.00 1127.17 N 3439.78 E 1759.37 69.16 9082.90 7253.10 7200.00 1056.28 N 3557.72 E 1829.80 70.43 9260.32 7353.10 7300.00 956.89 N 3665.37 E 1907.22 77.42 9437.96 7453.10 7400.00 859.89 N 3775.54 E 1984.87 77.65 9615.46 7553.10 7500.00 765.29 N 3887.54 E 2062.36 77.49 9781.25 7653.10 7600.00 675.95 N 3985.01 E 2128.15 65.79 9938.49 7753.10 7700.00 592.19 N 4072.80 E 2185.40 57.25 10085.19 7853.10 7800.00 517.24 N 4149.58 E 2232.09 46.70 10227.79 7953.10 7900.00 447.14 N 4223.21 E 2274.69 42.60 10368.60 8053.10 8000.00 379.97 N 4296.09 E 2315.50 40.80 10508.35 8153.10 8100.00 315.86 N 4369.70 E 2355.25 39.75 10646.20 8253.10 8200.00 255.72 N 4443.08 E 2393.10 37.86 10784.12 8353.10 8300.00 198.36 N 4518.72 E 2431.02 37.92 10924.26 8453.10 8400.00 142.48 N 4599.44 E 2471.16 40.14 11061.25 8553.10 8500.00 90.78 N 4677.49 E 2508.15 37.00 11204.31 8653.10 8600.00 33.88 N 4762.46 E 2551.21 43.06 11355.23 8753.10 8700.00 32.08 S 4854.22 E 2602.13 50.92 11507.33 8853.10 8800.00 100.20 S 4946.37 E 2654.23 52.10 11655.92 8953.10 8900.00 161.90 S 5037.31 E 2702.82 48.59 11799.90 9053.10 9000.00 216.52 S 5125.29 E 2746.80 43.98 11942.46 9153.10 9100.00 268.73 S 5212.46 E 2789.36 42.56 12082.38 9253.10 9200.00 316.17 S 5298.03 E 2829.28 39.92 12216.04 9353.10 9300.00 356.20 S 5377.13 E 2862.94 33.66 12347.70 9453.10 9400.00 396.59 S 5452.58 E 2894.60 31.66 12482.83 9553.10 9500.00 445.73 S 5529.02 E 2929.73 35.14 12616.07 9653.10 9600.00 481.36 S 5609.29 E 2962.97 33.24 12746.69 9753.10 9700.00 491.33 S 5692.34 E 2993.59 30.62 12878.66 9853.10 9800.00 479.82 S 5777.59 E 3025.56 31.97 13009.44 9953.10 9900.00 464.02 S 5860.37 E 3056.34 30.78 13138.17 10053.10 10000.00 450.00 S 5940.20 E 3085.07 28.73 13268.44 10153.10 10100.00 432.58 S 6021.84 E 3115.34 30.27 13390.00 10246.93 10193.83 416.32 S 6097.39 E 3143.07 27.73 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 7/18/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11163 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3-49A/M-40 RETAINER SET RECORD 970402 1 1 3~49A/M-40 STATIC PRESSURE SURVEY 970424 I 1 3-49A/M-40 PERFORATION RECORD 970425 I 1 3-49A/M-40 PERFORATION RECORD 970426 I 1 4-44/M-44 [_)v t ~ TUBING PUNCHER RECORD 970313 I 1 2-24/M-12 ~),. i ~ INJECTION PROFILE 970326 I 1 2-46A/R-10 PRODUCTION LOG 97041 6 I 1 2-26/N-1 4 PRODUCTION PROFILE 970402 I 1 2-08/K-1 6 GAS LIFT SURVEY 970308 I 1 2-08/K- 16 PRODUCTION PROFILE 970308 1 1 1-25A/K-22 CHEMICAL CUT RECORD 970419 I 1 1-2SA/K-22 PLUG SET RECORD 970423 I 1 3-29/J-32 PRODUCTION PROFILE W/DEFT 970329 I 1 1-09A/L-21 GAMMA RAY/CCL 970301 I 1 1-1 7A/1-17 COMPLETION RECORD 970306 I 1 4- 50/K- 41 CHEMICAL CUTTER 970321 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~B-~~. D i~t I i_1_ I IM CS WELL LOG TRANSMITTAL To: State of Alaska May 21, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3-49A/M-40, AK-MM-70091 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ J'an Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5, MD Gamma Ray Logs: 50-029-21735-02 2" x 5" TVD Gamma Ray Logs: 50-029-21735-02 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:11 I--L-I ~1G SEI:I~IC~ S WELL LOG TRANSMITTAL To: State of Alaska May 15, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Drive. C)~~~.~~ LJx Anchorage, Alaska 99501 C~[ ~ 1 MWD Formation Evaluation Logs - 3-49A/M-40, AK-MM-70091 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21735-02 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport FIoad Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11023 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 5/14/97 Well Job # Log Description Date BL RF Sepia LIS Tape 3-49A/M-40 ~'~- '"7 ~p'~I 97206 PDC GR (JEWELRY LOG & GR) 970422 I 1 1 ,. , , I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 28, 1997 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island 3-49A/1~I-40 BP Exploration (Alaska) Inc. Permit No. 97-57 Sur. Loc. 2499'SNL, 610'WEL, Sec. 8, T11N, R17E, UM Btmnhole Loc. 2763'SNL. 4968'WEL, Sec. 10, T11N. R17E. UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced ~vell. The permit to redrill does not exempt you from obtaining additional permits required by' laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice ma,,,' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman BY ORDER OF dlf/Enclosures 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 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil' [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 56' Endicott Field / Endicott Pool 3. Address '6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047503 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Z4~' SNL, ~so' WEL, SEC. 8, T11N, R17E Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 2775' SNL, 4981' WEL, SEC. 10, T11N, R17E ~,~ $-49NM-40 At total depth ~l'l ~ 9. Approximate spud date Amount $200,000.00 2763' SNL, 4968' WEL, SEC. 10, T11N, R-1-4-E- 04/01/97 12.Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL047505, 2517'! No Close Approach 2560 13261' MD/10456' TVD ~16.To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) KickOff Depth 85'00' Maximum Hole Angle 4~" Maximum surface 3900 psig, At total depth (TVD) 10000' / 4900pslg 18. Casing Program Setting Depth Size Specifications Top Bottom · Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 Butt 5'I. 1'~-' &,~50" 6800' 137~J' 10400' 400 sx 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 MD TVD Structural Conductor Surface Intermediate RECEIVED Production Liner N~ 0ti & Gas cons. commisst~ Perforation depth: measured /~lohomg~ true vertical '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the fm"egoipg is true ..aj:ld ~cJrre9( to the best of my knowledge Signed s'te~Shuaz :~ /..~ Title Senior Drilling Engineer Date C~/~ .u- - ' ~'-'~mmission Use Only Permit Number I APINumber I Appr°v-alDate I Seec°verletter ~7 --tD5'"'2 50- (b,,%eJ -~/7~.~--' t~. '-'~"-'~'"'~7 for other requirements Conditions of Approval: Samples Required [] Yes llg[ No' Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures j~SLYes [] No Directional Survey Flequired .[~xYes [] No Required Working Pressure forBOPE []2M: []3M; ~ SM; [] 10M; [] 1SM Other: by order of Approved By Commissioner the commission Date I Well Name: 13-49A/M-40 Redrill Plan Summary IType of Redrill (producer or injector): PRODUCER Surface 2499' SNL, 610' WEL Sec. 8, T11N/R17E Location: Target Location: 2775' SNL, 4981' WEL Sec. 10, T11N/R17E Bottom Hole 2763' SNL, 4968' WEL Sec 10, T11N/R17E Location: AFE 727OO7 Number: Estimated Start Date: 4/1/97 IMD: 113,764' ITVD: IRig: I DOYON RIG #15 Operating days to complete: 28 110,400 I I KBE: 14o.o I Well Design (conventional, slimhole, etc.): Conventional Sidetrack I Objective: I Kekiktuk ABNORMAL PRESSURE Special design considerations NONE. NO ABNORMAL PRESSURE ANTICIPATED. Mud Program: An 10.2 ppg mud will be used. Special design NC~E considerations 3-49/M-40 Redrill Plan Summary RECEIVED ,Naai~ 0Il.& Gas.¢0ns. ~ Depth Densi PV YP INT 10MIN FL OIL SOLID (TVD) ty (CP) #/FT GEL GEL cc/30 (%) S (PPG) min (%) KOP' 10.2 10 18 5 10 5 0 5 to to to to to to to to to 13261' 10.4 15 25 15 30 7 0 10 Directional: I Ko " 18ooo' Maximum Hole Angle: Close Approach Well: 49° The above listed wells will be secured during the close approach. Casinclrrubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/'FVD 8 1/2" 7" 26 L-80 Butt 5414' 8350/6800 13764/10400 N/A 4 1/2" 12.6 L-80 nsct 12500' 0/0 12500/9838 3-49/M-40 Redrill Plan Summary RECEIVED Gas Cons. Page 2 Cement Calculations: Liner 7", 26#, L-80,Butt Size: Basis: 50% open hole excess, 80' shoe joint, top of cement to be _+1000' above the top of the Kekiktuk Total Cement 350 ft3 400 sx Class "G" cement Volume: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards and Contingencies 1. The expected Sadlerochit bottom hole pressure is psi @ 10000' SS, and calculates to a 9.5 ppg EMW.. 2. There are no close approach issues for this sidetrack. 3. There is some potential for lost circulation. 3-49/M-40 Redrill Plan Summary RECEIVED SUMMARY PROCEDURE , . 3. 4. 5. . , 12. 13 15. 16. 17. 18. 19. 20. 21. MIRU drilling rig, ND tree and NU BOPE, test same to 250 psi/5000 psi, pull TWC and circulate and conditon PU 4 1/2" tubing landing joint and pull the 4 1/2" tubing hanger to the floor, LD same POOH with 4 1/2",12.6#,L-80,TDS tubing and LD same. PU 9 5/8" section mill and RIH Displace well to milling fluid. Set Baker sidetrack whipstock assembly in the 9 5/8, 47#, NT-80S casing and mill window at 8500'. POOH Run in with a 6 3/4" steerable drilling assembly and a 8 1/2" bit with gamma ray/directional MWD. Dress the cement to 5' below the section top. Kickoff and if necessary displace well to a clean mud system. Continue to directionally drill to the 7" casing point at +13,764' with sail angle of 49.0° and final angle of 43° at TD(see attached directional plan). RU and run 7",26#,L-80 liner to 13,764' Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the 80' shoe volume, with the top of cement 1000' feet over the Kekiktuk. Set the liner top packer and release from hanger, pressure up and test casing. Re-test BOP's as needed. Clean out cement to landing collar. Run the 4-1/2",12.6#, L-80 completion string assembly. Space out and circulate with corrosion inhibitor. Land 4 1/2" tubing, set 4 1/2"X 7" packer, install TWC valve and test. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and TWC valve. Shear RP valve in the upper GLM and freeze protect the well. Set a TWC valve and test. Release rig. Complete appropriate documentation and hand-over to Production. PE's to perforate the well through tubing at a later date. RECEIVED ~ 011 & 6as Cons, 3-49/M-40 Redrill Plan Summary Page 4 [Shared SerVices Drilling[ [Structure: End SDI Well: ;5-49a/M-40 I Field: Endic°ff Loc~tion :Alask~ Scale 1 '250.00 13 ~9o/M-40 Wp11 East -> A II 2500 2750 5000 5250 5500 5750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 1500 i ~ i I ~ ~ i ~ i ~ ~ ~ ~ I I I.. I I _ I ~ ~ ! ! I I I t I I I I t500 I TARGET DATA ~ - 14) I~a ~ ~ N43db EoM. # -- ~o~itio~ -- ,~"~250 - 1250 13737 4.3,194,!.~1$0~31 -ZT~ 11~ U-40 Target 2 276610,59705.~O lal~/ 4k3.19~&27 I0~0~ --&,~.~ ~ M-443Tar~t I 276310,5970260 ~-' 250 I 0 o Z ~~ ~ -250 M-40 Torgct 2 C~ r"r~ M-40 Target 1 ~.~ m -1000! I I I I I' ' I I I I I , I I -I I I I I I I I I , I I I I I I I I 1000 -- - 750 - A - 500 II - 250 Z - O · _ ~ - -250 - -500 u~ - W .,.,.a - -750 -- -- 0 0 , -1000 o 2500 2750 5000 3250 .3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 Scale 1 ' 250.00 East -> 90?563?252 SPERRY-SUN Shared Services-Drillingt S{ructure ;'~ SDI Well: 3-49a/Id-40 Field · Endicoft Location: Alaska 6000 - - 6500 - o 7000 - 750o - _ 8000 - - 8500 - _ 9000 - 9500 - 1 oooo - 10500 - 11000 - 500 [ 3-490/M-40 Wp1 1 WELL PROFILE DATA .... Point .... kid Inc Olr ~ North Eoet DLS(de~l/lOOft) KOP EM of Drop lrr~l of Hold forget forget End of Hold 8500 61,23 6&85 6912 1121 3114 0,00 9137 48,98 130,50 7300 1062 3589 8,00 12422 48,98 130.50 9458 -546 5474 0,00 13147 43.19 46.27 10006 -555 5897 8.00 13737 43,19 46,27 10438 -276 8189 0,00 13764 4.3,19 46,27 10455 -263 6203 0,00 KOP'8500MD 48.78 4a.,sa End of Drop :nd of Hold MD I I I I I -- I 'l I I [- I I I' I I '1 I I I I- '1 I I I - I I I 1000 1500 2000 2500 ,.3000 3500 4.000 4500 5000 5500 6000 6500 7000 7500 8C Sc<~le 1 ' 500.00 Naal~ Oil & Gas C0ns, ~,~L~a~ 3-49a/M-40 Wp1 Vertical Section 114,14' RI(B 56.00' MD Inc. AzL TVDss TVDrkb Rect. Coordinates Grid Coordinates DIS Vertical Northlng Fasting t=n~dng Northbg degtlOOftSection 8500.00 61.23 68.85 6856.01 6912.01 1120.86n 3114,16e 273578,92 5972019.50 8600.00 57.33 76,98 6907.15 6963.15 1146.20n 3196.18e 273661.67 5972042,34 8700.00 53.99 85.79 6963,63 7019.63 1158,67n 3277.66e 273743,48 5972052.33 8800.00 51.35 95.29 7024.36 7080,36 1158.03n 3357,00e 273822.77 5972049.29 8900.00 49.53 105.41 7088.15 7144.15 1144.30n 3432,68e 273897,99 5972033,27 9000.00 48.63 115.93 7153,75 7209.75 1117.75n 3503.20e 273967,67 5972004,58 9100.00 48,70 126.59 7219.91 7275.91 1078.88n 3567.21e 274030.47 5971963,80 9136.95 48.98 130,50 7244.23 7300.23 1061.55n 3588,98e 274051.68 5971945.81 0200.00 48.98 130.50 7285.61 7341.61 1030.65n 3625,13e 274086,90 5971913,83 9300.00 48,98 130.50 7351.24 7407.24 981.65n 3682,50e 274142.75 5971863.12 9400,00 48.98 130.50 7416.87 7472.87 932,65n 3739,87e 274198,60 5971812.40 9500.00 48.98130.50 7482.51 7538.51 883,64n 3797.24e 274254,46 5971761,68 9600.00 48,98 130.50 7548.14 7604.14 834.64n 3854.61e 274310.31 5971710.96 9700.00 48.98 130.50 7613.77 7669.77 785.64n 3911.98e 274366.17 5971660.24 9800.00 48.98 130.50 7679,40 7735.40 736.64n 3989.35e 274422.02 5971609.52 9900,00 48,98 130.50 7745,03 7801,03 687.63n 4026.72e 274477.87 5971558.80 10000.00 48.98 130.50 7810.66 7866,66 638.63n 4084.08e 274533.73 5971508.09 1016O.00 48.98 130.50 7876.30 7932.30 589,63n 4141.45e 274589.58 5971457,37 10200.00 48198 130.50 7941.93 7997,93 540.62n 4198.82e 274645.~ 5971406.65 10300.00 48,98 130.50 8007.56 8063.56 491.62n 4256,19e 274701.29 5971355.93 10400.00 48.98 130,50 8073.19 8129,19 442.62n 4313,56e 274757,14 5971305.21 10500.00 48.98 130.50 8138.82 8194.82 393.62n 4370.93e 274812.99 5971254.49 10600.00 48.98 130.50 8204,45 8260.45 344.61n 4428.30e 274868.85 5971203.78 10700,00 48.98 13050 8270.09 8326.09 295.61n 4485.67e 274924.70 5971153.06 10800,00 48.98 130.50 8335.72 8391.72 246.61n 4543,04e 274980.56 5971102,34 10900.00 48.98 130,50 8401.35 8457.35 197.61n 4600.41e 275036,41 5971051,62 11000.00 48.98 130.50 8466.98 8522.98 148.60n 4657.78e 27509226 5971000,90 11100.00 48.98 130.50 8532.61 8588.61 99,60n 4715.15e 275148.12 5970950,18 11200.00 48.98 130.50 8598.24 8654.24 50,60n 4772.52e 275203,97 5970899.46 11300.00 48.98 130.50 8663.88 8719.88 1,60n 4829,89e 275259.82 5970848.75 11400.00 48.98 130.50 8729.51 8785,51 47.41s 4887.25e 275315.68 5970798.03 11500.00 48.98 130.50 8795.14 8851,14 96.41s 4944.62e 275371.53 5970747.31 11600.00 48.98 130,50 8860.77 8916.77 145,41s 5001.99e 275427,39 5970696,59 11700.00 48.98 130.50 8926.40 8982.40 194.41s 5059,36e 275483.24 5970645.87 11800.00 48.98 130.50 8992.03 9048.03 243.42s 5116.73e 275539.09 5970595.15 11900.00 48.98 130.50 9057.67 9113.67 292,42s 5174.10e 275594.95 5970544.43 12000.00 48.98 130.50 9123.30 9179.30 341.42s 5231.47e 275650.80 5970493.72 12100.00 48.98 130,50 9188.93 9244.93 390.42S 5288.84e 275706.65 5970443.00 12200,00 48.98 130.50 9254.56 9310.56 439.43s 5346.21e 275762,51 5970392.28 0,00 2383.43 KOP: 8500 ltD 8.00 2447.91 8.00 2517,16 8,00 2589.83 8.00 2664.50 8,00 2739.72 8.00 2814.03 8.00 2840.96 0.00 2886.60 O.00 2959.00 0.00 3031,39 0.00 3103.78 0.00 3176.18 0.00 3248,57 0,00 3320.96 0.00 3393.35 0.00 3465,75 0.00 3538.14 0,00 3610.53 0.00 3682.93 0.00 3755,32 0.00 3827,71 0.00 3900,10 O.00 3972,50 0.00 4O44,89 O.00 4117,28 0.00 4189.67 0,00 4262.07 0.00 4334.46 0.00 4406.8,5 0.00 4479.25 0.00 4551.64 0.00 4624.03 0.00 4896.42 0.00 4768.82 0.00 4841.21 0.00 4913.60 0.00 4986.0O 0.00 5058.39 Comment ' 3/27/97 7:10 PM Page 1 of 2 3-4ga/M-40 Wp1 tertlcal Section 114.14° . qKB 66.00' MO inc. Ad. TVDs~ TYOrkb Rect. Coordinates Northlng Easting 12300,00 48.98 130,50 9320.19 9376.19 488.43S 5403.58e 275818.36 5970341.56 12400.00 48.98 130,50 9385.82 9441.82 537,43s 5460,95e 275874,21 5970290.84 12422.21 48.98 130.50 9400.40 9456,40 548.32s 5473.6911 275886.62 5970279.58 12500.00 45.48 123,49 9453,25 9509.25 582.71s 5519,18e' 275931,04 5970243.82 12600,00 41,70 113.24 9525.76 9581.76 615.56s 5579.57e 275990.41 5970209.15 12700.00 38.97 101.61 9602.09 9658.09 635.05s 5641.03e 276051,25 5970187,81 12800.00 37.50 88.89 9680.76 9736.76 640.80s 5702.37e 276112.37 5970180.20 12900.00 37.47 75.72 9760,24 9816.24 632.69s 5762.38e 276172,60 5970186.49 13000.00 38.87 62.96 9838,98 9894.98 610,89s 5819.90e 276230.76 5970206.53 13100.00 41.56 51.27 9915.44 9971.44 575.81s 5873,81e 276285,71 5970239,95 13146,77 43.19 46.27 9950.00 10006.00 555.04s 5897.49e 276310,00 5970260.00 13228.66 43.19 46.27 10009.70 10065.70 516.30s 5937.99e 276351.66 5970297.49 13328.66 43.19 46.27 10082.61 10138.61 468.99s 5987.45e 276402.53 597034327 13428.66 43.19 46.27 10155.53 10211.53 421,68s 6036,91e 276453.40 5970389.06 13528.66 43.19 46.27 10228.44 10284.44 374,38s 6086,36e 276504,26 5970434.84 13628.66 43.19 46.27 10301.35 10357.35 327.07s 6135,82e 276555.13 5970480.62 13728.66 43,19 46.27 10374.26 10430,26 279.77s 6185.28e 276606.00 5970526,40 13736.53 43.19 46.27 10380.00 10436,00 276.05s 6189.17e 276610.00 5970530.00 13763.95 43.19 46.27 10400.00 10456,00 263,07s 6202.73e 276623.95 5970542,56 Grid Coordinates DIS Vertical Easting Nofthing degfl0Oft Section Comment 0.00 5130.78 0.08 6203,17 0.08 5219.25 8.00 5274.83 8,00 5343.37 8.00 5407,43 8,00 5465.75 8.00 5517.20 8.00 5560.77 8.00 5595.63 8.00 5508.74 M-40 Target 1:13147 MD 0.08 5629.85 0.00 5655.64 0.00 5681.43 0.00 5707,21 0.00 5733.00 0.00 5758.78 0.00 5760.81 M-40 Target 2:13737 MI) 0.00 5767.89 TOE" Liner Pt: 13764 MI:) 3/27/97 7:10 PM Page 2 of 2 TREE: 4 1/16" CIW WELLHEAD: MCEVO¥ ACTUATOR: OTIS 3-49A/M-40 Sidetrack out of 9 5/8" Casing KB. ELEV=56 (DOYON 14) BF= 11.2O' 13 3/8" 68 #/ft L-80, BU3-1' OTIS SSSV Landing Nipple 4-1524' w/min. I.D. 2" Production Tubing 4 1/2", 12.6#, L-80, NSCT 7"X 9 5/8" Hanger/Packer Window from 8500' to 8030' 7",26#,L-80,BTS Liner Baker SAB @ 14,415' 9 5/8", 47~,NT-95, NSCC 14,720' 7", 29fl BAKER SAB-3 PACKER ±12,500' 1/2" OTIS "X" Nipple 3,813" I.D. 7",29~f,L-80 NSCC 4 1/2" OTIS "XN" Nipple 3.750" I.D. 7", 29#/ft SM-110, B'CI'S-TKC Squeezed Perfs 16,076'-16,233' - ' C~)MMENTS ENDICOTT r,,.,v,., ........... , APl NO 50'029.-_. ( SDI WELL 3-49/J-40 ) RT. BEV - BF, BEV - 16.4' - MAX. DEV. - 61:54 ' 8800' MD 13-3/8", 68#/ft, L.-80, BTRS. CSG. 9-5/8', 47#/it, ~ NT80S XO TO ~. NTgSHS ' UNER 9.5/8', 47#//t,NTgSHS, I 14'720, J NSCC PERFORATION SUMMARY Ref. Log DLL-GR (8/03/87) CO. SIZE SF[: INTERVAL BAKER 5' 4 14,840' to 14.886' 14.900' to 14.910' ....... 14,966' to 15.040' 15,050' to 15,070' TREE: 4-1/16" / $000 psi / C. JW WELLHEAD:. 13-5/8" / SO00 psi / McEVOY SSSV LANDING NIPPLE [ 1,524' (3.813" MIN. ID) W/SSSV I,{~N I.D. Z' 4-1/Z", 1 Z.6~/~ L-80, TDS TUBING GAS LiFT MANDRELS (HUGHES) NO. TVD-~;~; MD-BRT #~1 6.Z6rl ?,zorn I I~l #a I a.6nr I ~z,~°r I I#Zl s.6~r I v~.o~8' I SLIDING SLEEVE OTIS 'XA' I 14.342' (3.813' MtN. ID) TUBING SEAL ASSY. [ 14,400,' 9-5f8' PACKER I 14.415' (BAKER 'SAB') 3-1/2', 9.2ff//t. L-80 TAILPIPE 3-1/2' ')C NIPPLE I 14,462' (OTIS) (~_7S0' ID) 3-1/2' 'XN' I 14'4~ I NIPPLE (OTIS) (ze3s' D) 3-1/2- WLEG W/2-7/8' ~(' NIPPLES (2.313' MIN. ID) 2-7/8' WLEG I 14,945, I 'l'bg Vol = Z19 Bbls. Tailpipe Vol - 1 Bbl. Liner to Perf Vol = 1Z Bbls. SM-110, BTRS, 10/2.1/87 I MDM I COMP.&PERF ENDICOTT WELL 3-49/J-40 AP! NO: 50-029-21735 COMPLETION DIAGRAM BP EXPLORATION, INC. WELL NAME 3-49/J-40 LOG/DATE DILPSFL 8/3/87 Pass #3 TOP M.D. BOT M.D. 3A2 14840 14886 3A2 14900 14910 2B5 14966 15040 2B3 15050 15070 H TOPT'VD BOTTVD 46 10044 10067 1 0 10075 10080 74 10109 10148 20 10153 10164 2/1/88 5/1/89 0.00 0.00 0.00 0.00 0.79 0.79 PLUGGEDOFF 0.21 0.21 PLUGGED OFF ~VELL PERMIT CHECKLISTco~Y ~ X WELL NAME ~%1J~ 3-q q~/~-~O PROGRAM= exprq dev ~ redrl~servU wellbore segU ann disp para reqD FIELD & POOL ~,~.~ ~-~ ( ~ 0 INIT CLASS ~.%~ /-- O~ GEOL AREA ~ ~ ~ UNIT, / O c~/ ~"0 ON/OFF SHORE .... ~ ~/1 ADMINISTRATION 9. 10. 11. DATE 12. 1. Permit fee attached .................. .~Y~N 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. ~ N 4. Well located in a defined pool ............. ~ N 5 Well located proper distance from drlg unit boundary...~ N 6 Well. located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... ~N If deviated, is wellbore plat included ........ ~ N Operator only affected party .............. ~ N Operator has appropriate bond in force ......... ~ N Permit can be issued without conservation order ..... ~ N Permit can be issued without administrative approval...~Q N Can permit be approved before 15-day wait ........ ~ N REMARKS ENGINEERING 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost ..... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If dtverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to _~~ psig. 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpr~ Y N 32. Seismic analysis of shines. ......... Y N 33. Seabed condi~io~~ (if off-shore) ........ Y N 34. Contac phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOWldlf. A:\FORMS~cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ............................ . ....... SCHLUMBERGER ....... COMPANY NAlViE : BP EXPLORATION WELL NAi~E : 3-49A/M-40 FIELD NAFIE : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 50-029-21735-02 REFERENCE NO : 97390 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/09/30 ORIGIN : FLIC REEL NAi~E : 97390 CONTINUATION # : PREVIOUSREEL : CO~ENT : BP EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 97/09/30 ORIGIN : FLIC TAPE NA~E : 97390 CONTINUATION # : 1 PREVIOUS TAPE COMFIFJFf : BP EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 TAPE ~ER Endicott CASED HOLE WIRELINE LOGS WELL NAME: 3-49A/M-40 API NUFI~ER: 500292173502 OPERATOR: BP Expl ora ti on LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 30-SEP-97 JOB NUFiBER: 97390 LOGGING ENGINEER: Carl o Yon OPERATOR WITNESS: Bob Clump SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 53.10 DERRICK FLOOR: 53.10 GROUND LEVEL: 14 ~ 10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: f~WD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 13347.5 13345.5 13343.5 13338.0 13336.5 13332.0 13327.5 13327.0 13322.0 13320.5 13319.0 13307.5 13282.5 13278.5 13268.0 13265.5 13253.5 13252.5 13250.5 13244.5 13241.5 13240.5 13227.5 13227.0 13220.5 13214.5 13213.0 13208.0 13202.5 13200.5 13196.0 13191.0 13190.0 13180.0 13179.0 13174.5 13171.5 13171.0 13166.0 13163.5 13163.0 13156.5 13154.0 13138.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88886.5 88886.5 13346.0 13344.5 13341.5 13336.5 13336.0 13330.5 13331.5 13326.5 13326.5 13322.0 13319.5 13317.5 13306.5 13282.5 13279.0 13267.0 13265.5 13253.5 13252.0 13251.5 13245.5 13242.0 13241.5 13228.5 13229.0 13222.5 13215.0 13215.0 13209.0 13202.5 13202.5 13197.0 13192.5 13192.5 13182.0 13180.5 13176.0 13172.5 13172.5 13167.5 13164.5 13164.5 13158.0 13155.0 13139.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 13347.5 13345.5 13343.5 13338.0 13336.5 13332.0 13327.5 13327.0 13322.0 13320.5 13319.0 13307.5 13282.5 13278.5 13268.0 13265.5 13253.5 13252.5 13250.5 13244.5 13241.5 13240.5 13227.5 13227.0 13220.5 13214.5 13213.0 13208.0 13202.5 13200.5 13196.0 13191.0 13190.0 13180.0 13179 0 13174 5 13171 5 13171 0 13166 0 13163 5 13163 0 13156 5 13154 0 13138 0 30-SEP-1997 16:01 SPERRY SUN .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88886.5 13346.0 13344.5 13341.5 13336.0 13330.5 13326.5 13319.5 13317.5 13306.5 13282.5 13267.0 13252.0 13241.5 13228~5 13215.0 13202.5 13197.0 13192°5 13180.5 13172°5 13167.5 13164~5 13158.0 13155~0 13139.5 88886.5 13336.5 13331.5 13326.5 13322.0 13279.0 13265.5 13253.5 13251.5 13245.5 13242.0 13229.0 13222.5 13215.0 13209.0 13202.5 13192.5 13182.0 13176.0 13172.5 13164.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 13137.0 13132.5 13127.0 13126.0 13106.5 13092.0 13091.0 13089.5 13086.0 13084.0 13082.0 13078.0 13076.5 13074 5 13072 0 13059 0 13032 0 13026 0 13020 0 13010.0 13000.5 12992.5 12978.5 12964.0 12960.5 12958.5 12958.0 12956.0 12934.5 12931.5 12929.5 12928.5 12925.0 12923.0 12922.5 12920.0 12906.5 12905.0 12902.0 12896.0 12890.0 12885.0 12884.5 12876.5 12870.5 12861.5 12855.5 100.0 $ 13127.0 13108m0 13092.5 13090.5 13088.0 13083.0 13078.0 13076.0 13061.0 13033.0 13027.0 13021.5 13011.0 13001.5 12994.0 12980.5 12965.0 12962.5 12960.0 12957.5 12936.5 12934.0 12930.5 1292 6.5 12925.0 12921~0 12909.0 12907.5 12903.5 12898.0 12891.5 12886.5 13139.5 13134.5 13131.0 13092.0 13086.0 13080.5 13075.5 13004.0 12960.0 12933.5 12925.0 12891.5 12886.0 12876.5 12871.5 12863.5 12863.5 12856.0 100.5 102.0 CONTAINED HERE IS THE CASED HOLE TDTPAND GAF~A RAY DATA ACQUIRED ON BP'S 3-49A/M-40 ~VDICOTT WELL. THERE WERE THREE TDTP PASSES AND ONE PASS OF GAM~IA RAY AND CASING COLLAR LOGS MADE. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:O1 PAGE: **** FILE HEADER **** FILE NA~IE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13370.0 12854.0 TDTP 13390.0 12854.0 $ CURVE SHIFT DATA - PASS TO PASS (MEAS[HAED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUPiBER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS THE CLIPPED DATA FOR TDTP PASS #1. NO PASS TO PASS SHIFTS WERE MADE ON THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SBHFTDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SBHIVTDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SIBHTDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TRATTDTP 560192 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 560192 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TCANTDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 TSCFTDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 560192 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 560192 O0 000 O0 0 1 1 1 4 68 0000000000 T~NS TDTP LB 560192 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 560192 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13388.500 SIGM. TDTP 28.993 TPHI.TDTP 36.651 SBHF. TDTP SBHN. TDTP 87~675 SIGC. TDTP 0.284 SIBH. TDTP 145.083 TRAT. TDTP SDSI. TDTP 0.475 BACK. TDTP 87.239 FBAC. TDTP 23.949 TCAN. TDTP TCAF. TDTP 8813.111 TCND. TDTP 14645.584 TCFD. TDTP 4381.025 TSCN. TDTP TSCF. TDTP 715.652 INND. TDTP 2305.911 INFD. TDTP 354.176 GRCH. TDTP TENS. TDTP 1604.000 CCL.TDTP -0.016 79.016 1.438 21495.016 1697.728 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: DEPT. 12854.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCArD. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 195.485 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVUFI~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 2 DEPTH INC~: 0~5000 FILE SUFE~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13370.0 12930.0 TDTP 13390.0 12930.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88888.0 13356.5 13356.5 13349.5 13349.5 13344.0 13344.0 13341.5 13341.0 13339.5 13339.0 13339.0 13339.0 13337.0 13338.0 13336.5 13336.5 13332.0 13331.5 13331.0 13331.5 13326.0 13326.5 13323.0 13323.5 13321.0 13322.0 13319.0 13319.0 13308.0 13309.0 13304.0 13305.0 13296.0 13297.0 13293.0 13292.0 13291.5 13292.5 13283.0 13282.5 13278.5 13279.5 13277.5 13279.0 13275.0 13276.0 13265.5 13265.5 13264.5 13264.5 13252.0 13252.0 13250.5 13252.0 13247.5 13248.5 13245.0 13245.5 13242.0 13243.0 13241.5 13242.5 13227.5 13228.5 13226.0 13228.0 13222.5 13224.0 13220.5 13222.5 13214.0 13215.0 13201.5 13202.5 13200.5 13202.5 13193.5 13196.0 13191.0 13192.5 13190.5 13192.5 13186.0 13186.0 13180.5 13182.0 13180.0 13182.0 13175.5 13176.5 13171.5 13172.5 13165.5 13167.0 13158.5 13160.0 13157.0 13158.0 13153.0 13154.0 13147.5 13150.0 13140.0 13143.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 13137.5 13139.5 13137.0 13139.5 13133.0 13135.5 13132.5 13133.5 13126.5 13130.5 13118.0 13118.5 13113.5 13118.5 13092.5 13093.5 13091.5 13092.5 13084.0 13086.0 13083.5 13084.5 13080.0 13080.5 13076.5 13079.0 13074.5 13076.0 13072.0 13075.5 13061.0 13063.0 13044.5 13047.0 13044.0 13046.5 13037.0 13037.0 13032.0 13032.5 13028.5 13030.5 13026.5 13027.0 13018.5 13021.5 13017.5 13018.0 13015.0 13014.5 13008.0 13011.5 13002.5 13004.5 13000.5 13001.5 12994.5 12996.0 12985.0 12986.0 12975.5 12977.5 12965.5 12967.5 12964.5 12965.0 12958.5 12960.0 12960.0 12951.5 12953.0 12951.0 12953.0 12945.0 12946.5 12943.0 12943.5 12938.5 12941.0 12935.0 12936.5 12932.0 12934.0 100.0 102.0 102.5 $ REMARKS: THIS FILE CONTAINS CLIPPED AND DEPTH CORRECTED TDTP PASS #2. DEPTH CORRELATIONS WERE MADE COMPARING GRCH PASS #2 TO GRCH PASS #1 AND SIGM PASS #2 TO SIGM PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SBPiNTDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 560192 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 560192 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 560192 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 560192 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 560192 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 560192 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 10 ** DATA ** DEPT. 13390.000 SIGM. TDTP 27.601 TPHI.TDTP 34.784 SBHF. TDTP 81.433 SBHN. TDTP 86.777 SIGC. TDTP 0.690 SIBH. TDTP 143.045 TRAT. TDTP 1.439 SDSI. TDTP 0.531 BACK. TDTP 156.964 FBAC. TDTP 32.955 TCAN. TDTP 20794.801 TCAF. TDTP 8541.771 TCND. TDTP 14092.535 TCFD. TDTP 4221.063 TSCN. TDTP 1625.991 TSCF. TDTP 693.378 INND. TDTP 2109.899 INFD. TDTP 348.113 GRCH. TDTP -999.250 TElVS. TDTP 1718.000 CCL. TDTP 0.000 DEPT. 12932.000 SIGM. TDTP -999.250 TPHI.TDTP SBP~N. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL~TDTP -999.250 -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 TCAN. TDTP -999.250 TSCN. TDTP -999.250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 156.981 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT c002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **~* FILE NAM~ : EDIT °003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE ~ER FILE NOlviBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH GRCH 13370.0 TDTP 13390.0 STOP DEPTH 12753.0 12753.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 11 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888 0 13362 0 13349 0 13345 5 13344 5 13343 0 13336.0 13335.0 13331.5 13330.5 13325.5 13321.0 13318 5 13303 5 13297 5 13295 5 13291 0 13283 0 13277.5 13277.0 13274.5 13263.0 13256.0 13251.0 13250.5 13244.5 13241.5 13238.5 13226.5 13224.5 13221.5 13220.0 13214.0 13210 0 13200 0 13192 5 13190 5 13182 0 13180 0 13176.0 13174.5 13170.0 13166.0 13165.5 13163.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88888.5 88888.5 13346.0 13344.0 13336.5 13331.5 13326.5 13319.5 13297.0 13284.0 13279.5 13263.5 13255.5 13252.0 13245.5 13240.0 13228.5 13227.0 13223.5 13212.0 13192.5 13184.0 13177.0 13172.5 13167.5 13165.0 13362.5 13349.5 13345.0 13336.5 13331.5 13326.5 13322.5 13305.0 13297.5 13292.5 13279.0 13276.0 13252.0 13243.0 13222.5 13215.0 13202.5 13195.5 13182.0 13176.5 13167.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30~SEP-1997 16:01 PAGE: 12 13158.5 13156.5 13152.0 13147.5 13137.0 13133.0 13129.5 13126.5 13126.0 13092.5 13092.0 13089.5 13084.0 13080.0 13075.5 13075.0 13060.0 13047.5 13043.0 13034 0 13032 0 13019 5 13017 0 13010 0 13008 5 13002 0 13000 5 12994.5 12965.5 12964.5 12959.0 12958.5 12953.5 12951.0 12948.0 12935.0 12930.0 12929.0 12925.5 12923.0 12919.5 12907.0 12903.0 12897.5 12890.0 12888.0 12885.0 12882.5 12877.5 12875.5 12869.5 12864.0 12857.0 100.0 $ 13158.0 13153.5 13131.0 13127.0 13092.5 13090.5 13080.5 13076.5 13043.5 13033.0 13018.0 13010.5 13003.0 12995.5 12965.5 12960.0 12955.5 12936.5 12931.0 12927.0 12921.0 12909.0 12899.0 12889.0 12886.5 12879.5 12871.5 12859.0 102.0 13160.0 13150.0 13139.5 13135.5 13130.5 13093.5 13085.5 13078.0 13062.5 13050.5 13037.0 13022.0 13011.5 13004.0 12967.0 12960.0 12953.5 12951.5 12933.0 12925.5 12905.5 12892.0 12884.0 12876.5 12864.0 100.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 13 REMARKS: THIS FILE CONTAINS CLIPPED AND DEPTH CORRECTED TDTP PASS #3. DEPTH CORRELATIONS WERE MADE COMPARING GRCH PASS #3 TO GRCH PASS #1 AND SIGM PASS #3 TO SIGM PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NARIE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SBP1NTDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 560192 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 560192 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 14 NAM~ SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPIB SAMP ELEM CODE (HEX) TCND TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TSCFTDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 560192 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 560192 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 560192 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 560192 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13390.500 SIGM. TDTP 27.916 TPHI. TDTP 33.867 SBHF. TDTP SBHN. TDTP 88.410 SIGC. TDTP 0.894 SIBH. TDTP 145.150 TRAT. TDTP SDSI. TDTP 0.580 BACK. TDTP 178.402 FBAC. TDTP 36.679 TCAN. TDTP TCAF. TDTP 10056.377 TCND. TDTP 13930.602 TCFD. TDTP 4160.438 TSCN. TDTP TSCF. TDTP 693.307 INND. TDTP 2113.215 INFD. TDTP 323.189 GRCH. TDTP TENS. TDTP 1707.000 CCLoTDTP 0.000 DEPT. 12753.000 SIGMoTDTP 41.703 TPHI. TDTP 51.069 SBHF. TDTP SBHN. TDTP 60.908 SIGC~TDTP 1.891 SIBH. TDTP 84.361 TRAT. TDTP SDSI.TDTP 0.970 BACK. TDTP 158.179 FBAC. TDTP 23.345 TCAN. TDTP TCAF. TDTP 9977.426 TCND.TDTP 12667.355 TCFD. TDTP 3138.239 TSCN. TDTP TSCF. TDTP 324.377 INND.TDTP 1915.442 INFD. TDTP 292.168 GRCH. TDTP TENS. TDTP 2023.000 CCLwTDTP 0.000 76.962 1.411 24731.438 1578.083 -999.250 59.130 1.455 35636.750 943.786 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 15 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUFI~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13370.0 8026.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH 88888.0 88888.5 13341.0 13341.5 13336.5 13336.5 13325.5 13326.5 13316.0 13317.5 13305.5 13305.0 13281.0 13281.0 13268.0 13267.5 13251.5 13252.0 13245.5 13245.5 13225.0 13226.5 13211.5 13212.5 13208.5 13209.0 13201.5 13202.5 13191.5 13193.0 13171.0 13172.5 13154.0 13155.0 13138.0 13139.5 13132.5 13133.5 13117.5 13117.5 13090.0 13090.5 13074.5 13076.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 16 13068.0 13070.5 13060.0 13061.0 13039.0 13040.0 13037.0 13037.5 13017.5 13018.0 13000.0 13001.0 12996.0 12996.0 12985.5 12987.0 12979.5 12980.5 12965.5 12965.5 12959.5 12960.0 12955.0 12955.5 12936.0 12936.5 12933.5 12934.0 12923.5 12925.0 12909.0 12910.5 12902.5 12903.0 12890.5 12891.0 12880.0 12881.0 12862.5 12863.0 100.0 100.5 $ REMARKS: THIS FILE CONTAINS THE CASED HOLE GAMFLA RAY AND COLLAR LOCATOR DATA LOGGED WITHOUT ACQUIRING TDTP DATA. THIS DATA HAS BEEN DEPTH CORRECTED TO PASS $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 17 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 560192 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 560192 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 560192 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 560192 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13370.500 GRCH. TDTP 85.554 TENS. TDTP 2261.000 CCL. TDTP DEPT. 8026.500 GRCH. TDTP 24.182 TENS. TDTP 1229. 000 CCL. TDTP 0.000 O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .004 SERVICE : FLIC VERSION : O01COi DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 18 of edited static baseline passes for all other curves. DEPTH INCREFIENT 0.5000 PASSES INCLUDED IN AVF2~AGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP THIS FILE CONTAINS THE ARITHT4ETIC AVERAGE OF TDTP PASS i, 2 AND 3. THE ARITHIMETIC AVERAGE WAS COMPUTED AFTER CLIPPING ANDDEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NABiE SERV UNIT SERVICE API API API API FILE NUf4~ NUAiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 560192 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PNAV PU-S 560192 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PNAV 560192 O0 000 O0 0 5 I 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 19 NA~E SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) SDSI PNAV CU 560192 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TSCNPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 INNDPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 INFDPNAV CPS 560192 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 560192 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13388.500 SIGM. PNAV 28.356 TPHI.PNAV 35.510 SBHF. PNAV 78.550 SBHN. PNAV 87.423 SIGC.PNAV 0.549 SIBH. PNAV 144.290 TRAT. PNAV 1.432 SDSI.PNAV 0.532 BACK. TDTP 87.239 FBAC. TDTP 23.949 TCAN. PNAV 22584.848 TCAF. PNAV 9228.961 TCND.PNAV 14211.211 TCFD. PNAV 4263.108 TSCN. PNAV 1645.302 TSCF. PNAV 704.408 INND.PNAV 2180.906 INFD.PNAV 333.499 GRCH. TDTP -999.250 DEPT. 12854.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHIV. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 195.485 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30~SEP-i997 16:01 PAGE: 2O **** FILE HEADBR **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFi~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 1 DEPTH INCREmENT: 0.5000 FILE SUFk~%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 13390.0 12854.0 TDTP LOG HEADER DATA DATE LOGGED: 24 -APR- 97 SOFTWARE VERSION: 8C0-609 TI~E LOGGER ON BOTTOM: 1030 24-APR-97 TD DRILLER (FT): 13370.0 TD LOGGER (FT) : 13370.0 TOP LOG INTERVAL (FT) : 8026.0 BOTTOM LOG INTERVAL (FT): 13370.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEFIPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLH3FJ~ (BPM) : TOOL NUM~ER TNC-P 390 8.500 13385.0 Produced Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 21 WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : ArEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: This log was depth referenced to a Sperry-Sun MWD log, logged on 14-April-1997 Sandstone Matrix used for computations The well was shut in while logging This file contains raw TDTP Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.$ 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 22 ** SET TYPE - CHAN ** NA24E SERV UNIT SERVICE API API API API FILE NUMiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~f CODE (HEX) DEPT FT 560192 O0 000 00 0 6 1 1 4 68 SIGM PS1 CU 560192 00 000 O0 0 6 1 1 4 68 TPHI PS1 PU 560192 O0 000 O0 0 6 1 1 4 68 SBHF PS1 CU 560192 O0 000 O0 0 6 1 1 4 68 SBHIVPS1 CU 560192 O0 000 O0 0 6 1 1 4 68 SIGC PS1 CU 560192 O0 000 O0 0 6 1 1 4 68 SIBH PS1 CU 560192 O0 000 O0 0 6 1 1 4 68 TRAT PS1 560192 O0 000 O0 0 6 1 1 4 68 SDSI PS1 CU 560192 O0 000 O0 0 6 1 1 4 68 BACK PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 FBAC PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TCANPS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TCAF PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TCND PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TCFD PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TSCNPS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TSCF PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 INND PS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 INFDPS1 CPS 560192 O0 000 O0 0 6 1 1 4 68 TENS PSI LB 560192 O0 000 O0 0 6 1 1 4 68 GR PS1 GAPI 560192 O0 000 O0 0 6 1 1 4 68 CCL PS1 V 560192 O0 000 O0 0 6 1 1 4 68 0000000o00 000000000o 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000o000oo 0000000000 0000000000 0000000000 0000000000 0000000000 00000o0000 000000000o 0000000000 00o0o0000o 0000ooo00o 00000o000o ** DATA ** DEPT. 13401.000 SIGM. PS1 -999.250 TPHI.PS1 -999.250 SBHF. PS1 SBHIV. PS1 -999.250 SIGC.PS1 -999.250 SIBH. PS1 -999.250 TRAT. PS1 SDSI.PS1 -999.250 BACK. PSi -999.250 FBAC. PS1 -999.250 TCAN. PS1 TCAF. PS1 -999.250 TCND.PSl -999.250 TCFD.PS1 -999.250 TSCN. PS1 TSCF. PS1 -999.250 INND.PS1 -999.250 INFD.PS1 -999.250 TENS.PSi GR.PS1 0.000 CCL.PS1 -0.016 DEPT. 12742.000 SIGM. PS1 45.906 TPHI.PS1 69.112 SBHF. PS1 SBPiNoPS1 62.970 SIGC. PS1 0.824 SIBH. PS1 89.038 TRAT. PS1 SDSI.PS1 1.019 BACK. PSi 121.826 FBAC. PS1 24.578 TCAN. PS1 TCAF. PS1 8787.334 TCND.PS1 12784.016 TCFD.PS1 2940.006 TSCN. PS1 TSCF. PS1 238.303 INND.PS1 1940.901 INFD.PS1 291.875 TENS.PSi GR.PS1 111.636 CCL.PS1 -999.250 -999.250 -999.250 -999.250 -999.250 1242.000 55.069 1.710 35089.727 872.715 1923.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 23 **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIVE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE I~J~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 2 DEPTH INC~: 0.5000 FILE SU~fARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13390.0 12854.0 TDTP LOG HEADER DATA DATE LOGGED: 24-APR-97 SOFTWARE VERSION: 8C0-609 TIME LOGGER ON BOTTOM: 1030 24-APR-97 TD DRILLER (FT) : 13370.0 TD LOGGER (FT) : 13370.0 TOP LOG INTERVAL (FT) : 8026.0 BOTTOM LOG INTERVAL (FT): 13370.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): TOOL NUMBER TNC-P 390 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PA GE: 24 LOGGERS CASING DEPTH (FT): 13385.0 BORE~OLE 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) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARJfS: This log was depth referenced to a Sperry-Sun MWD log, logged on 14-April-1997 Sandstone Matrix used for computations The well was shut in while logging This file contains raw TDTP Pass #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 25 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA2qE SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUA~ SAMP ELE~ CODE (HEX) DEPT FT 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS2 CU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SBH~VPS2 Cig 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS2 CU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS2 CU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 560192 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS2 CU 560192 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS2 CPS 560192 O0 000 O0 0 7 1 i 4 68 0000000000 TSCN PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS2 CPS 560192 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 560192 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 560192 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS2 V 560192 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 13408.500 SIGM. PS2 -999.250 TPHI.PS2 -999.250 SBHF. PS2 SBPiN. PS2 -999.250 SIGC.PS2 -999.250 SIBH. PS2 -999.250 TRAT. PS2 SDSI.PS2 -999.250 BACK. PS2 -999.250 FBAC.PS2 -999.250 TCAN. PS2 TCAF. PS2 -999.250 TCND.PS2 -999.250 TCFD.PS2 -999.250 TSCN. PS2 TSCF. PS2 -999.250 INND.PS2 -999.250 INFD.PS2 -999.250 TENS.PS2 GR.PS2 109.790 CCL.PS2 0.000 -999.250 -999.250 -999.250 -999.250 922.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 26 DEPT. 12886.500 SIGM. PS2 42.841 TPHI.PS2 SBHN. PS2 45.034 SIGC. PS2 0.000 SIBH.PS2 SDSI.PS2 0.768 BACK. PS2 147.057 FBAC.PS2 TCAF.PS2 9735.859 TCND.PS2 15068.043 TCFD.PS2 TSCF.PS2 341.408 INND.PS2 1573.628 INFD.PS2 GR.PS2 155.848 CCL.PS2 -999.250 65.749 SBHF. PS2 48.351 TRAT. PS2 40.253 TCAN. PS2 3406.756 TSCN. PS2 276.099 TENS. PS2 47.986 2.034 40523.609 1510.835 2064.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .008 SERVICE : FLIC VERSION : 001C01 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE~ER FILE NUFiBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREM~2gT : 0.5000 FILE SU~4ARY VENDOR TOOL CODE START DEPTH TDTP 13390.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIMiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 12854.0 24 -APR~97 8C0- 609 1030 24-APR-97 13370.0 13370.0 8026.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 27 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ 13370.0 900.0 NO TOOL NUMBER TNC-P 390 BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 13385.0 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) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: This log was depth referenced to a Sperry-SunMWD log, logged on 14-April-1997 Sandstone Matrix used for computations The well was shut in while logging This file contains raw TDTP Pass #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE 28 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~I CODE (HEX) DEPT FT 560192 O0 000 O0 0 8 1 1 4 68 0000000000 SIGMPS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 SBHlVPS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 560192 00 000 O0 0 8 1 1 4 68 0000000000 SDSI PS3 CU 560192 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TCAFPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TCFDPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TSCNPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 INNDPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 INFDPS3 CPS 560192 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 560192 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 560192 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS3 V 560192 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 29 ** DATA ** DEPT. 13411.500 SIGM. PS3 SBHN. PS3 -999.250 SIGC. PS3 SDSI.PS3 -999.250 BACK. PS3 TCAF. PS3 -999.250 TCND. PS3 TSCF. PS3 -999.250 INND. PS3 GR.PS3 106.901 CCL.PS3 -999.250 TPHI.PS3 -999.250 SIBH.PS3 -999.250 FBAC. PS3 -999.250 TCFD.PS3 -999.250 INFD.PS3 0.000 DEPT. 12689°000 SIGM. PS3 53.452 TPHI.PS3 SBHN. PS3 112.545 SIGC. PS3 0.585 SIBH. PS3 SDSI.PS3 6.413 BACK. PS3 431.411 FBAC. PS3 TCAF. PS3 0.000 TCND. PS3 -4834.099 TCFD.PS3 TSCF. PS3 0.000 INND. PS3 -14.665 INFD.PS3 GR.PS3 49.980 CCL.PS3 -999.250 -999.250 SBHF. PS3 -999.250 TRAT. PS3 -999.250 TCAN. PS3 -999.250 TSCN. PS3 -999.250 TENS.PS3 0.000 SBHF. PS3 139.542 TRAT. PS3 80.713 TCAN. PS3 -917.787 TSCN. PS3 -2.744 TENS. PS3 -999.250 -999.250 -999.250 -999.250 761.000 98.533 0.000 0.000 0.000 1974.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFZE : EDIT .009 SERVICE · FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 4 DEPTH INCREMeNT: 0.5000 FILE SUF~fARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13370°0 8026.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 3O 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): 24 -APR-97 8C0- 609 1030 24-APR-97 13370.0 13370.0 8026.0 13370.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY $ TOOL NUFI~ER TNC-P 390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 13385.0 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) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATENORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 This log was depth referenced to a Sperry-Sun MWD log, logged on 14-April-1997 Sandstone Matrix used for computations LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 31 The well was shut in while logging This file contains raw Cased Hole Gamma Ray and Casing Collar Locator data without acquiring TDTP data. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUA~ NUAiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 560192 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 560192 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 560192 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS4 V 560192 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 13395.500 TENS.PS4 887.000 GR.PS4 208.319 CCL.PS4 0.000 DEPT. 8025.500 TENS.PS4 1216.000 GR.PS4 30.384 CCL.PS4 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-SEP-1997 16:01 PAGE: 32 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT ~009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/09/30 ORIGIN : FLIC TAPE NA~E : 97390 CONTINUATION # : 1 PREVIOUS TAPE : COM~iEArT : BP EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/09/30 ORIGIN : FLIC REEL NAM~ : 97390 CONTINUATION # : PREVIOUS REEL : COM~iENT : BP EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 Sperry-Sun Drilling Services LIS Scan Utility Wed May 14 18:23:18 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/05/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER DUCK ISLAND UNiT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 3-49A / M-40 500292173502 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 14-MAY-97 MWD RUN 1 AK-MM-70091 M. WORDEN E. VAUGHN MWD RUN 2 AK-MM-70091 M. WORDEN E. VAUGHN MWD RUN 3 AK-MM-70091 M. WORDEN E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 4 AK-MM-70091 M. WORDEN E. VAUGHN MWD RUN 5 AK-MM-70091 M. WORDEN E. VAUGHN 8 liN 17E 2499 53.10 53.10 · GROUND LE\rEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 14.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8485.0 8.500 13390.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 3. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). THIS RUN WAS MEASURED AFTER DRILLING (MAD). 4. THE API# FOR WELL 03-49A / M-40 IS 50-029-21735-02. THE ORIGIONAL API# OF 50-029-21735-01 WAS CANCELLED AND REISSUED AS 50-029-21735-02. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13390'MD, 10247'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING (MAD). ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 700 PPM. 10.4 PPG. 16000 PPM. 1.0 G/CC 2.65 G/CC SANDSTONE .Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FiLE HEADER FILE NUMBER: 1 EDITED MERGED I~D Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8446.5 13361.0 ROP 8477.5 13385.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8446.5 12613.0 12616.0 12619.5 12622.0 12623.5 12636.0 12640.5 12643.5 12647.5 12653.0 12656.5 12660.0 12662.5 12665.0 12667.5 12669.0 12672.0 12677.5 12685.0 12687 0 12690 0 12691 5 12696 5 12700 5 12703 5 12708 0 12710 0 12714 5 12717 0 12719 5 12723 0 12726 0 12728 0 12729 5 12732 0 12736 0 12739 5 12743 5 12748 5 12750.0 12754.5 12756.5 GR 8454.0 12620 5 12626 5 12629 5 12632 5 12634 5 12645 0 12650 0 12651 5 12656 5 12662 0 12665 5 12669 5 12673 0 12675 5 12678 5 12680 0 12682 5 12687 0 12695 0 12697 0 12699.5 12700.5 12705.5 12709.5 12712.5 12716.0 12718 5 12723 0 12725 0 12727 5 12730 0 12732 5 12735.5 12737 0 12740 0 12744 5 12746 5 12751 5 12756 0 12757 5 12762 0 12764 5 EQUIVALENT UNSHIFTED DEPTH ~2758 5 12762 5 12766 0 12768 0 12771 0 12775 0 12778 0 12781 0 12785 0 12789 5 12794 5 12798 0 12800 0 12803 0 12804 0 12808 0 12810 5 12813 0 12814.5 12817.5 12821.0 12823.0 12832.0 12840.0 12842.5 12844.0 12845.5 12847.0 12851.0 12854.0 12855.5 12863.5 12867.5 12868.5 12871.0 12875.0 12878.0 12879.5 12882 0 12883 5 12886 0 12887 0 12889 0 12890 0 12892 0 12917 0 12921 0 12923 5 12926 5 12930 5 12934 5 12936 5 12940 0 12943.5 12946.0 12947.5 12953.0 12954.5 12957.5 12960.0 12962.5 12965.0 12980.5 12983.5 12766.5 12769.0 12772.0 12774.0 12776.5 12780 0 12783 5 12787 0 12789 5 12794 5 12799 0 12802 5 12805 5 12809 0 12810 5 12813 5 12816 5 12818 5 12820 5 12823 0 12826.0 12827.0 12836.5 12844.0 12845 5 12847 5 12849 5 12851 5 12854 5 12858 0 12859 5 12867 5 12871 0 12872 5 12874 5 12879 0 12883 0 12884 5 12886 0 12888 0 12890 5 12892 5 12894 0 12895 0 12896 0 12922 5 12925 0 12928 0 12930 5 12935 0 12938 0 12940 5 12943 5 12946 5 12948 5 12951 5 '12957 5 12959 0 12962 0 12964 5 12967 0 12970 5 12984 5 12988 0 .12991 12993 12996 13000 13004 13012 13013 13014 13018 13020 13023 13031 13032 13073 13074 13076 13078 13079 13083 13086 13089 13092 13118 13127 13131 13133 13139 13153. 13155 13158 13159 13162 13164 13168 13172 13174 13175 13177 13179 13180 13184 13188 13192 13196 13197 13203 13210 13215 13218 13221 13224 13226 13228 13230 13231 13240 13242 13249 13251 13252 13255 13265 13279 13281 0 5 5 0 5 0 0 5 0 5 5 0 5 0 5 0 0 5 0 5 5 0 5 5 0 0 5 5 0 0 5 0 5 5 5 5 5 0 0 5 0 5 5 0 5 0 5 5 0 0 0 0 5 0 5 5 5 5 5 5 5 0 5 5 12994 5 12997 5 13000 5 13003 5 13007 0 13014 0 13015 5 13020 5 13022 0 13025 5 13028 0 13036 0 13037 5 13078.5 13079.5 13081.0 13083.5 13086.0 13091.0 13094.0 13096.5 13099.5 13124.0 13133.0 13136.0 13140.0 13145.0 13159.0 13160.5 13163.0 13165.0 13167.0 13169.5 13172.5 13178.0 13180.0 13180.5 13182.0 13184.0 13185.0 13188.5 13193.5 13197.0 13200.0 13202.0 13207.5 13215.0 13219.5 13222.0 13224.5 13226.5 13229 5 13232 5 13234 0 13235 5 13244 5 13247 0 13252 5 13255 0 13256 0 13259.0 13270.0 13283.0 13285.5 ,13282 13319 13322 13326 13331 13336 13340 13341 13385 $ .5 .5 .5 5 5 5 0 0 0 13287 0 13323 5 13326 0 13330 0 13336 0 13340 5 13344 0 13345 5 13389 5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 8485.0 9196.0 9196.0 12282.0 12282.0 13127.0 13127.0 13390.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8446.5 13385 10915.8 9878 8446.5 ROP 3.334 908.789 69.2674 9816 8477.5 GR 14.7533 363.14 100.379 9830 8446.5 Last Reading 13385 13385 13361 First Reading For Entire File .......... 8446.5 Last Reading For Entire File ........... 13385 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FI LE SUMMARY PBU TOOL CODE PEF DRHO RHOB FCNT NCNT NPHI FET RPD RPM RPS RPX GR RAT MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: .5000 START 12994 12994 12994 12994 12994 12994 12994 12994 12994 12994 12994 12994 12994 DEPTH .5 .5 .5 .5 .5 5 5 5 5 5 5 5 .5 STOP DEPTH 13361.0 13361.0 13361.0 13352.0 13352.0 13352.0 13344.0 13344.0 13344.0 13344.0 13344.0 13372.0 13380.5 MAD RUN NO. MAD PASS NO. 5 MERGED MAD PASS. Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 12998.0 MERGE BASE 13385.0 Name Service Order DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD AAPI 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHM~ 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 NPH, I MAD P.U. 4 1 68 NCNT Ie~D CNTS 4 ! 68 FCNT Iq_AD CNTS 4 t 68 RHOB M~D G/CC 4 t 68 DRHO MAD G/CC 4 1 68 P EF MAD BARN 4 1 68 32 36 40 44 48 52 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 12994.5 13380.5 13187.5 773 RAT 36.95 2279.05 203.462 773 GR 15.902 225.336 80.5253 756 RPX 1.669 1860 32.5607 700 RPS 1.969 2489.1 33.3606 700 RPM 2.433 3252.61 34.3114 700 RPD 2.88 2489.3 33.4953 700 FET 47.6639 81.5765 62.0395 700 NPHI 7.568 61.648 29.17 716 NCNT 2129 4568 3100.54 716 FCNT 471.986 1611 754.303 716 RHOB 1.436 5684.1 42.289 734 DRHO -0.229 7428.62 52.2365 734 PEF 1.653 5685.08 42.476 734 First Reading 12994 5 12994 5 12994 5 12994 5 12994 5 12994 5 12994.5 12994 5 12994 5 12994 5 12994 5 12994 5 12994 5 12994 5 Last Reading 13380.5 13380.5 13372 13344 13344 13344 13344 13344 13352 13352 13352 13361 13361 13361 First Reading For Entire File .......... 12994.5 Last Reading For Entire File ........... 13380.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8454.0 9164.0 ROP $ LOG HF~ADER DATA 8485.0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWA_RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMIIM ANGLE: MAXIMUM ANGLE: 9195.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 06-APR-97 IrC 4.96 5.46 MEMORY 9196.0 8485.0 9196.0 52.6 61.3 TOOL NUMBER P0709CG6 8.500 8.5 LSND 9.50 61.0 11.6 1150 4.8 .000 .000 .000 .000 50.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 ~API 4 1 68 ROP ~D ! FT/H 4 1 68 Name Min Max Mean Nsam DEFT 8454 9195.5 8824.75 1484 GR 22.9813 106.329 60.3872 1421 ROP 3.9865 302.93 45.3001 1422 First Reading 8454 8454 8485 Last Reading 9195.5 9164 9195.5 First Reading For Entire File .......... 8454 Last Reading For Entire File ........... 9195.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUi~VLARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9166.5 12251.5 ROP 9197.5 12281.5 $ LOG HEADER DATA DATE LOGGED: 10-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.96 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12282.0 TOP LOG INTERVAL (FT) : 9196.0 BOTTOM LOG INTERVAL (FT) : 12282.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 39.7 MAXIMUM P~qGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G.~/~¢u~_ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHM}4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): I~UD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 56.6 TOOL NUMBER P0709CG6 8.500 8.5 LSND 10.00 62.0 9.5 80O 3.0 .000 .000 .000 .000 67.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9166.5 12281.5 10724 6231 9166.5 GR 36.808 246.415 93.8163 6171 9166.5 ROP 3.334 461.426 88.2611 6169 9197.5 Last Reading 12281.5 12251.5 12281.5 First Reading For Entire File .......... 9166.5 Last Reading For Entire File ........... 12281.5 File Trailer Service name ............. STSLIB.004 Sezvice Sub Level Name... Vezsion Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12247.5 ROP 12273.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS ~4UD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : STOP DEPTH 13101.5 13126.5 12-APR-97 ISC 4.96 5.46 MEMORY 13127.0 12282.0 13127.0 38.8 42.6 TOOL NUMBER P0709CG6 8.500 8.5 LSND 10.20 53.0 MUD PH: F~UD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMIC) AT TEMPEP~TURE (DEGF) FUJD AT MEJ~SURED TEMPERATURE (MT): I~'D AT M~ CIRCULATING TERMPERA, TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.8 800 3.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 65.6 First Name Min Max Mean Nsam Reading DEPT 12247.5 13126.5 12687 1759 12247.5 GR 21.2541 363.14 168.359 1709 12247.5 ROP 6.898 908.789 35.1679 1708 12273 Last Reading 13126.5 13101.5 13126.5 First Reading For Entire File .......... 12247.5 Last Reading For Entire File ........... 13126.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header · Sezvice name ............. STSLIB.006 Service Sub Level Name... Version Numbez ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record 65535 File Type ................ LO Previous File Name ....... STSLiB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13103.0 ROP 13128.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13365.5 13389.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPE~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : 13-APR-97 ISC 4.96 5.46 MEMORY 13390.0 13127.0 13390.0 40.0 39.4 TOOL NUMBER P0709CG6 8.500 8.5 LSND 10.40 60.0 9.2 700 3.0 .000 .000 .000 .000 71.7 ~EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13103 13389.5 13246.2 574 13103 GR 14.7533 144.728 63.5594 526 13103 ROP 3.7554 225 26.0128 523 13128.5 Last Reading 13389.5 13365.5 13389.5 First Reading For Entire File .......... 13103 Last Reading For Entire File ........... 13389.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Con~nent Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD. PASS NUMBER: FI LE SUMI~XRY VENDOR TOOL CODE START DEPTH PEF DRHO RHOB FCNT NCNT NPHI FET RPD RPM RPS RPX GR RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12998.5 12998.5 12998.5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998.5 12998.5 12998.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: STOP DEPTH 13365 5 13365 5 13365 5 13356 5 13356 5 13356 5 13348 5 13348 5 13348 5 13348 5 13348 5 13376 5 13385 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : 15-APR-97 ISC 4.96 5.46 MEMORY 13385.0 12998.0 13385.0 40.0 39.4 TOOL NUMBER P0700CRNDG6 P0700CRNDG6 P0700CRNDG6 P0700CRNDG6 8.500 8.5 LSND 10.40 60.0 9.2 700 3.0 1.400 .000 1.100 1.800 71.7 .EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 5 AAPI 4 1 68 RAT MAD 5 FT/H 4 1 68 RPX MAD 5 OHMM 4 1 68 RPS MAD 5 OHM~ 4 1 68 RPM ~AD 5 OHMM 4 1 68 RPD MAD 5 OHMM 4 1 68 FET MAD 5 HOUR 4 1 68 NPHI MAD 5 P.U. 4 1 68 NCNT MAD 5 CNTS 4 1 68 FCNT MAD 5 CNTS 4 1 68 RHOB MAD 5 G/CC 4 1 68 DRHO MAD 5 G/CC 4 1 68 PEF MAD 5 G/CC 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 12998.5 13385 13191.8 774 GR 15.902 225.336 79.9819 757 RAT 36.95 2279.05 211.209 774 RPX 1.669 1860 32.7877 701 RPS 1.969 2489.1 33.5036 701 RPM 2.433 3252.61 34.3159 701 RPD 2.88 2489.3 33.3992 701 FET 47.6639 81.5765 62.1482 701 NPHI 7.568 61.648 29.0661 717 NCNT 2129 4568 3106.51 717 FCNT 471.986 1611 757.591 717 RHOB 1.436 5684.1 41.51 735 DRHO -0.229 7428.62 51.2166 735 PEF 1.653 5685.08 41.693 735 First Reading 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 12998 5 Last Reading 13385 13376.5 13385 13348.5 13348 5 13348 5 13348 5 13348 5 13356 5 13356 5 13356 5 13365 5 13365 5 13365 5 First Reading For Entire File .......... 12998.5 Last Reading For-Entire File ........... 13385 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/14 Maximum Physical Record..65535 File Type ................ LO ~Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/05/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/05/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File * ~S~ COMP~ING CENTER ~ ............................ ............................ ............................ COMPANY NAME : BP EXPLORATION (ALASKA) , INC. WELL NAME : 3-49A / M-40 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21735-02 REFERENCE NO : 97206 LIS Tape VerificaL~on Listing Schlumberger Alaska Computing Center 12-MAY-1997 11: 04 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/05/12 ORIGIN · FLIC REEL NAME : 97206 CONTINUATION # : PREVIOUS REEL : CO~4~NT · B.P. EXPLORATIONi 3-49A/M-40, ENDICOTT, 50-029-21735-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 97/05/12 ORIGIN · FLIC TAPE NAME : 97206 CONTINUATION # : 1 PREVIOUS TAPE : COf4~IENT · B.P. EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 TAPE HEADER Endicott CASED HOLE WIRELINE LOGS WELL NAME: 3-49A / M-40 API NUMBER .. 500292173502 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-MAY-97 JOB ~ER: 97206 LOGGING ENGINEER: John Majcher OPERATOR WITNESS: ECKSTEIN/CLU SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 iN RANGE: 17E FNL : FSL: FEL : FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 53.10 DERRICK FLOOR: 53.10 GROUND LEVEL: 14.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 13385.0 29.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUNZ~ER : DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ THIS IS THE PDC DATA FROM THE GR/CCL LOG RUN 22-APR-97. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/05/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS 1VUM~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUNk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13350.0 12602.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH REMARKS: THIS IS THE PDC DATA FROM THE GR/CCL LOG RUN 22-APR-97. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. THIS IS THE CLIPPED DATA FILE. LIS Tape Verificat.on Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557841 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 557841 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 557841 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 557841 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13370.000 GRCH.GR -999.250 TENS.GR 1566.000 CCL.GR DEPT. 13200.000 GRCH.GR 8.569 TENS.GR 2241.000 CCL.GR DEPT. 13000.000 GRCH.GR 75.807 TENS.GR 2183.000 CCL.GR -999.250 O. 025 O. 046 DEPT. 12800.000 GRCH.GR 84.757 TENS.GR 2100.000 CCL.GR -0.005 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 PAGE: DEPT. 12602.000 GRCH. GR 29.394 TENS.GR 2203.000 CCL.GR 0.089 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE ~ 97/05/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : GR LOG HEADER DATA 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 1VUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 13370.0 12602.0 DATE LOGGED: 22-APR-97 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 1600 22-APR-97 TD DRILLER (FT) : 13370.0 TD LOGGER (FT) : 13370.0 TOP LOG INTERVAL (FT) : 12602.0 BOTTOM LOG INTERVAL (FT) : 13370.0 LOGGING SPEED (FPHR): 3600.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 PAGE: GR GAMMA RAY $ PGGD BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 13385.0 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) : SEAWATER/GAS 10.40 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 LIS Tape Verificau~n Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 PAGE: 6 TYPE REPR CODE VALUE 7 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 1 66 73 65 0.5 FT 64 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557841 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH GR GAPI 557841 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 557841 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 557841 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13397.500 GRCH. GR 0.000 TENS.GR 937.000 CCL.GR DEPT. 13200. 000 GRCH. GR DEPT. 13000.000 GRCH. GR 8.569 TENS. GR 75.807 TENS.GR 2241.000 CCL.GR 2183.000 CCL.GR DEPT. 12800.000 GRCH. GR 84.757 TENS.GR 2100.000 CCL.GR DEPT. 12602.000 CRCH. GR 29.394 TENS.GR 2203.000 CCL.GR 0.009 O. 025 O. 046 -0. 005 O. 089 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAY-1997 11:04 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/12 ORIGIN : FLIC TAPE NAME : 97206 CONTINUATION # : 1 PREVIOUS TAPE : CO~!MENT : B.P. EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE . 97/05/12 ORIGIN . FLIC REEL NAME : 97206 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, 3-49A/M-40, ENDICOTT, 50-029-21735-02