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195-166
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7g'Nj�'z-0 DATE: 8/15/2020 P. I. Supervisor FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector MPU F-38 Hilcorp PTD 1951660 August 15, 2020: 1 traveled to Hilcorp's Milne Point Unit (MPU) well F-38 to witness a No -Flow test. The well had previously been bled down to zero tubing and IA pressure, both connected to a 2 -inch hard line terminating in a large flow back tank. Flow from the well was blocked in and the well pressure was allowed to build for 3 hours. When opened, the well pressure indicated 4 PSI and dropped to 0 PSI in 3.5 minutes. Less than 1 quart of fluid was produced in the 5 minute bleed off period. MPU F-38 passed the No -Flow test today. Attachments: None 2020-0815_No-Flow_MPU_F-38 ij.docx Page 1 of 1 THE STATE °fALASKA May 27, 2020 GOVERNOR M1hL DUNLEAVY Mr. Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH 2O-029 Notice of Violation - Closeout Duck Island MPI 2-48 (PTD 1951660) Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 WW W.00gcc.olaska.gov The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska LLC (Hilcorp)'s May 14, 2020 explanation regarding the failure to obtain approval of well test and safety valve system changes prior to commencing production through a second flow line attached to Duck Island Unit MPI 2-48. The recommendations developed from Hilcorp's internal investigation — when implemented — should prevent recurrence of this violation. Sincerely,` Jeremy M. Price Chair, Commissioner cc: P. Brooks AOGCC Inspectors III May 14, 2020 Hilcorp Alaska, LLC Jeremy M. Price, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Docket No, OTH-20-029 Notice of Violation Duck Island MPI 2-48 (PTD 1951660) Dear Commissioner Price, Chad Helgeson Area Operations Manager 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8405 cheigeson@hilcorp.com Hilcorp Alaska, LLC, (Hilcorp) responds to the AOGCC letter dated April 21S1, 2020, regarding the failure to obtain approval of well test and safety valve system changes prior to commencing production on MPI 2-48 second production flow line leg B and violation of 20AAC 25.230 and 25.265. On February 8, 2020 Hilcorp initiated a Management of Change (MOC) request to Twin Well 2- 48 (MOC # HAK2020-02-08_13677) at Endicott. The technical basis of the project was to add a second flowline to allow increased flow from the well without exceeding the velocity limitations of the existing piping. The MOC was approved on March 1 a to allow startup. (The MOCfile can be provided on this project if requested.) The following sections summarize Hilcorp internal investigation on this incident. Well Testing - 20 AAC 25.230 Flow started through the new twinned flowline on March 1 at. There were two well tests (March 2nd and 5`h) conducted using the twinned piping before the wing valve on the twinned line was closed on March 10`h. The well was tested in the facility test separator with all production from the well flowing through it during the test. The production rate flowing from the well did not exceed the test separator capacity where an alternate test method may have been necessary. The normal DIU MPI test methodology was used when the well was twinned and it is not clear how these test violated 20AAC 25.230. SVS System — 20 AAC 25.265 Hilcorp submitted an AGOCC Test Witness Notification Request on March 2"d (Email receipt attached), where the reason for the SVS test was listed in the other information section on the form "twinned well 2-48 added additional flow -line choke and PSL". The witness of this SVS test was waived by Jeff Jones. A complete SVS performance test was performed which included testing the existing equipment and new low pressure detection device on the new secondary flowline. The SVS passed the 20 AAC 25.265 requirements and the test report (Attached) was submitted to Docket No. OTH-20-029 May 14, 2020 Page 2 of 2 AOGCC on March 3`d and in the forms remarks section it stated "Well 2-48 was test with an additional Wing Choke and PSL [Leg B] All components Passed." Hilcorp was contacted by AOGCC with questions about the new additional detection device listed on the testing report. On March 10' AOGCC requested more information in regards to MPI 2-48 safety valve test and Hilcorp shut-in the second production flowline leg B and submitted a formal request for approval of the additional flowline/choke/PSL on March IIth. Hilcorp received approval to use an alternate well testing methodology and install, main, operate and test the twin flowline safety valve system on April 21 s . Findings Hilcorp investigated this event and developed the following recommendations to ensure that similar projects in the future meet AOGCC expectations: - When an Management of Change request is written for twinning a well, the well Operations Engineer will be listed as a reviewer to ensure 20 AAC 25.230 and 25.265 are followed. - If a field expects that twinning wells will be a standard procedure for wells in the Unit, an amendment to the Conservation Order for the Unit will be submitted. If you have any additional questions, please contact David Gorm at 777-8333 or by email at dgorm@hilcorp.com. Sincerely, HILCORP ALASKA, LLC Chad A Helgeson 2020.05.15 08:43:37 -08'00' Chad Helgeson Area Operations Manager Attachments: 1) AOGC Inspection Form Confirmation Email (dated 3/2/2020) 2) Well 2-48 SVS Test Report (dated 3/2/2020) / ƒ ; u Qje � \ \ E ID a- � / _ ( I ) ƒ ) \ \ ) \ k \ ƒ } \[) \ \ \ ) ) \ | fƒ\k ƒ0. e ; ( \/k 0Qt a a ƒ #@®� ( \ \ kk\\ (k §53) 2 `\2§ y/` B\)) @ !�vZ ;If,`g®- f :\«§ ) \/)k`\\� 2 % ( `��� ����` \ g \ ^ �a&] } ƒ$A2 / \\)}/P Ju / 4 2i 4 p >z o0 } z p y Z O o v r N vi � M � M M O r p 0. F" d � O O � M N M N 5 L w � 0.1 O a ti qJ 3 O O O O � M L C 0. d '000 v d c qai ti y v� y u R �p d � Q o4a � Fv U vj F' U v y aM° a ti a o 0 d vi L W R O O A z-- � m d E zea N N 0 0 0 0 v 4 v NI 3 N m a Colombie, Jody J (CED) 0�) Lo 009 From: Regg, James B (CED) Sent: Monday, May 11, 2020 2:50 PM To: Chad Helgeson Cc: David Gorm; Colombie, Jody J (CED) Subject: RE: OTH-20-029 Notice of Violation for MPI 2-48 Extension granted until Friday, May 15, 2020 Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reaeCdalaska.¢ov. From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, May 11, 2020 2:43 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Gorm <dgorm@hilcorp.com> Subject: OTH-20-029 Notice of Violation for MPI 2-48 Jim, We received the Notice of Violation for well MPI 2-48 at Endicott from AOGCC on April 281h. It asks us to respond within 14days of receipt of the letter. We have been working this during this time, but have been having some delays in getting questions answered with the unique working from home situations, etc. We think we have everything collected, can we have till Friday this week to finalize and get the letter back to AOGCC, which would be 17 days from receipt of the letter? Chad Helgeson Operations Manager North Slope Team Hilcorp Alaska, LLC 907-777-8405(0) 907-229-4824(C) THE STATE °fALASKA April 21, 2020 GOVERNOR MIKE DUNLEAVY CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7015 0640 0003 5185 6557 Mr. Chad Helgeson Operations Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-029 Notice of Violation Duck Island MPI 2-48 (PTD 1951660) Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov On March 10, 2020, the Alaska Oil and Gas Conservation Commission (AOGCC) received a miscellaneous well safety valve system test report for Duck Island Unit MPI 2-48 documenting a test completed on March 2, 2020. The test report included safety valve system components associated with "2-48" and "2-48 B -leg" and remarks that "Well 2-48 was tested with an additional Wing Choke and PSL [leg B]". Responding to AOGCC's request for clarification about the MPI 2-48 B -leg, Hilcorp noted in emails dated March 10 and 11, 2020 that a second flowline was installed off the MPI 2-48 flow cross on February 28, 2020. Production from MPI 2-48 through the twin flowlines to the production header commenced March 1, 2020. MPI 2-48 B -leg flow was shut-in March 10, 2020 after AOGCC questioned the lack of approval of well test and safety valve system changes. Hilcorp submitted a "Request for Approval of Well and SVS Testing in Support of Twinned Flowlines" for MPI 2-48 on March 11, 2020. Failure to obtain approval of well test and safety valve system changes prior to commencing production is a violation of 20 AAC 25.230 and 25.265. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written summary of Hilcorp's internal investigation and describe what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Information requested in this notice is in accordance 20 AAC 25.300; failure to comply with this request will be an additional violation. Docket Number: OTH-20-029 April 21, 2020 Page 2 of 2 The AOGCC reserves the right to pursue additional enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Jim Regg at (907) 793- 1236 (email: jim.regg@alaska.gov). Sincerely, v Jeremy M. Price Chair, Commissioner ■ Complete items 1, 2, and 3.■ .. 0 Agent Print your name and address on the reverse 0 Addreso that we can return the card to you. EBW.1',,cJ by (Pri N r� q) C. D e of Del ,bry %Zt ■ Attach this card to the back of the mailpiece, $ U1 Extm Services & Fees (cneckbo ' or on the front if space permits.from D afferent item - - If yEs a enter dsilvery below: 0 No Mr. Chad Helgeson 0 ❑AEURSIgnet—R1-r,oE It Operations Manager [] Mutt Signature Resirktetl Delivery $ Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 3. serice Type ❑ Priority Mail Expreese III 1111111111111 1111 �l1111 • Siliftetun"RmtrictedDed � d�ed 959 4351 8190 1 05 6 o � �Ma .veryry OReaWMcl meaeP Merchandise ❑ Collect on Delivery ❑ Collect on Delivery Restricted Delivery ❑ Signature Conflrmetlonn' O Signature Confirmation2. Article Number (Tran firm seNiCe 18 5185 –' - etricted Delivery 6557 Restricted Delivery 0640 (10033 715 X PS Form3811, JDIy 2015 PSN 7530-02-000-9053 I" .. Ln un u1 0 F1 q) Certified Mal Fee A $ U1 Extm Services & Fees (cneckbo ' ❑R rnR 1pt(1rrnimpy $ iTl ❑Rehm Receipt(ele nlc) $ 0 0 ❑CertMetlf,!MResM WDel er, $ 0 ❑AEURSIgnet—R1-r,oE It [] Mutt Signature Resirktetl Delivery $ O Postage S Postmerk Here °o T Mr. Chad Helgeson Ln $ Operations Manager ratHilcorp Alaska LLC 0 a. r` 3800 Centerpoint Drive, Suite 1400 C, Ani-horaae. AK 99503 Domestic Retum Receipt THE STATE °fALASKA April 21, 2020 COVLRNOR MIKL DUNLG;ll7 Mr. David Germ Operations Engineer Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-011 Well Testing and Safety Valve System Changes MPI 2-48 (PTD 1951660) Duck Island Unit Dear Mr. Gorm: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.aloska.gov By letter dated March 11, 2020 Hilcorp Alaska, LLC (Hilcorp) requests approval of an alternative well testing methodology and safety valve system changes for Duck Island Unit well MPI 2-48. The well's flow rate is being artificially restricted with a flowing wellhead pressure of approximately 1,000 psi due to flowline erosion velocity limitations. Hilcorp's requests the use of a second flowline attached to MPI 2-48 — installed February 28, 2020 — to enable the well to flow at full rate into the 300 -psi production header. The "twin" flowline has been tied into the existing flowline of long-term shut-in well MPI 2-50 (PTD 1930670) which is adjacent to MPI 2- 48, carrying the extra well flow into the production header. The production tree of MPI 2-50 is isolated from its flowline. As an alternate method of well testing, Hilcorp proposes the summation of the individual well tests of each of the MPI 2-48 flowlines. Those individual tests will be performed back-to-back to ensure consistent plant conditions and sufficient accuracy for allocation purposes. The MPI 2-48 safety valve system has been enhanced by adding a low-pressure detection device in the twin flowline linked to the existing safety valve control panel. Detection of a low-pressure situation in either of the flowlines closes the surface safety valve, the actuated wing valves on both flowlines, and the subsurface safety valve. Performance testing of the MPI 2-48 safety valve system involves independently actuating the low-pressure switches to verify regulatory compliance. The Alaska Oil and Gas Conservation Commission APPROVES Hilcorp's request to use the alternate well testing methodology and to install, maintain, operate, and test the twin flowline safety valve system as described in its application, with the following conditions: - The low-pressure detection devices and surface safety valve for the twin flowlines must be uniquely identified and labeled; Docket Number: OTH-20-011 April 21, 2020 Page 2 of 2 - Hilcorp must submit separate test reports for the twin flowline safety salve system tests. Any questions regarding this approval should be directed to Jim Regg at 907-793-1236 (email: i im.regg(a,alaska.gov). Sincerely,` Jeremy M. Price Chair, Commissioner Email: AOGCC Inspectors H nilcom Alaska, LLC March 11, 2020 RECEIVE® Mr. David Roby Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 MAR 11 2020 �M Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Re: END 2-48 (PTD # 1951660) Request for Approval of Well and SVS Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 2-48 (PTD # 1951660) in support of a flowline twinning project. Background END 2-48 is an Endicott natural flow producer completed in the Kekiktuk formation in the Lower Subzone S3A3 formation. The well has been on steady state production since 1995 and is one of the field's producers with a GOR (90,000 scf/bbl) and Water Cut (-98%). Production is currently restricted with a flowing tubing pressure of 1000 psi due to flowline erosion velocity limitations. To allow the well to flow at full rate to the —300 psi production header, we would like to connect a 2nd "twin" flowline to the tree to carry a portion of the production from END 2-48 to the flowline of adjacent long term shut-in producer END 2-50 (PTD#193067). END 2-50 is disconnected and would remain completely isolated from the twinned flowline. Justification Twining END 2-50 in this configuration will allow for increased production as well as accurate well testing and allocation within the operating limits of the Endicott MPI test separator. Additional well drawdown is expected to encourage additional 53A3 contribution which will help GOR as FTP decreases. Well Testing Methodology Hilcorp would utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). END 2-48's well tests would be obtained through a summation of individual tests of the original (2-48) and twin (2-486) flowlines. Currently Endicott wells receive a minimum of monthly tests. With the addition of testing from the twinned (2-48B) flowline, a minimum of two tests would be taken to Page 12 ensure one combined 2-48 well test per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain the same utilizing individual tests and flowline On/Off times as determined by the wing valves' open/closed position. Production values for each flowline would then be combined and reported as a single value for END 2-48. This methodology would result in no change or disruption to 2-48's well testing or production reporting. Safety Valve System Low Pressure Switch Configuration Hilcorp would operate and test the SVS systems with the addition of a second low pressure switch to protect against a pressure drop in the twinned (2-4813) flowline. The second low pressure switch would be connected from the twinned (2-4813) flowline to END 2-48's safety valve panel. END 2-48's surface and subsurface safety valves would remain unchanged, and the overall safety valve system functionality would be unaffected. When the low pressure switch from either flowline was tripped, both END 2-48's surface and subsurface safety valves would actuate. Additionally, actuated wing valves on either side of the flow cross would close on a low pressure trip. Once installed, this configuration would be function tested and an AOGCC witnessed performance test would be requested. As part of the performance test, each flowline low pressure switch would be tripped independently to verify the correct system actuation pressure for the respective flowline. If you have any additional questions, please contact me at 777-8333 or dgorm@hilcorp.com. Sipeere[y, David Gorm Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments - END 2-48 Wellhead Twinning Concept Diagram - END 2-48 & END 2-48B Redlined P&ID's - MPI Wells General Layout END 2-48 Flowline Twinning - Wellhead arrangement New flowline to 2-48B flowline & test/production slot 2-50 Existing SSV Closes with trip of either flowline PSL Actuated wings close with trip of either flowline PSL Existing flowline to test/production slot 2-48 -i I r--- -------------------------- �:'`-�---• r------ ' I //'�� [� i\© 4 I i I I I I I � New Wing Valve with Instrument Flange on —�V Downstream Side .----------- ----------- I Existing FI o7i line © _ C31 t New PSL Set @ 150 PSI New Choke n ■ W s+tr 0 • • RECEIVE: Post Office Box 244027 3 Anchorage,AK 99524-4027 HilcorpAlaska,LLC JUL 2�1'] 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster E® AUG 2 3 2,016 Alaska Oil & Gas Conservation Commission SCM 333 West 7th Avenue, Suite 100 193-- /6(0 Anchorage, AK 99501 I Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp . Orig iI New I API_WeliNo !PermitNumber] WellName WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-288 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 ;DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/015 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EIDO1 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/128 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 ,50029219460100 1940460 DUCK IS UNIT SDI 3-17A/130 3-17A 150029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 • Post Office Box 196612 =u Anchorage, Alaska 99519 -6612 f May 22, 2012 c6)o— "S") UG Mr. Jim Re `° It a . Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, / I 1_;L - 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 2 Date: 03/2W2012 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 END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2-04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 1 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / 1-15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0 -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 _) END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / Q-12 , 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 II Producers with sustained casing prco �� �� l�� due to ���� 9auolofl Regg, James B (DOA) '----- ---- -------------- ----------- ------'-------'—'--- ---'- ,---'-- -'---- From: AK, D&C Well Integrity Coordinator - - . . ^ .~ ^ \\����� �f/�// Sent: Thuradoy.JunaOS.2O11S:1SPK8 ' /i \ /' To: Maunder, Thomas E (DOA); Regg, James B (DOA); 8chvvartz, Guy L (DOA) Cc: AK, D&C Well lntegrity Coordinator; Walker, Greg (D&C); King, Whitney; Vazir, Mehreen Subject: Producers with sustained casing pressure on IA due to proration Jin/Ton/Guy. The following wells were found to have sustained casing pressure on the IA during the proration June 8th. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If either of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. C al_ 0 (PTO#1870090) 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 (SO7)65S-51OO Ext. 1154 A 1 - 20\ 6 ~"~~~~ . J, ~ k.`~iJ10~~ 03/03/09 (rr ~7li~'~~I~~~~fr~ $..5ai ~'~ ;:~E Cap ',?C};^ NO.5129 Alaska Data & Consulting Services < ;,~~ k pp pp .~ °` "` ~ ~ !Y~ ~ ~ . k y ~ ~~ ~ ~ ~ ~ Company: State of Alaska 2525 Gambell Street, Suite 400 ""' " " "'~"" ` "" Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken A7TN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WPII .Inh fk 1 nn rlncrrin}inn rlsln RI r`nli.r f`r1 ;\ ti' . "a L3-11 11999066 RST <" - 12/08/08 1 1 04-21 11968976 RST ly,~' _ 12/14/08 1 1 2-48/0-13 12071897 RST ~ 09/25/08 1 1 r~ciax N~,nrvvw~cuuc rse~.cir i nr ~rUrvrrvu Nrvu tse i unnrmv ~rvt curr twcn i v: 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 99503-2838 ATTN: Beth Received by:_ • END2-48/0-13 (PTD 1951660) Classified as Problem Well . . All, Well END2-48/0-13 (PTD 1951660) has been found to have sustained casing pressure on the IA. The Operator reported lAP at 2500 psi on 05/01/07 and difficulty keeping pressure bled off. A subsequent TIFL on 05/04/07 failed, after which the AL was blinded and a re-TIFL failed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED , 2. SL: DGL Vs / 3. DHD: Re-TIFL A wellbore schematic has been included for reference. «2-48.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 sCANNED jUN 2. {) 2007 Content-Description: 2-48.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/12/20073:47 PM . KB. ELEV = 56.00' BF ELEV = 14.50' MAX OEV = 95°@ 11216' HORIZONTAL COMPLETION 10-3/4", 45. 5 #1ft, NT80, Btrs Csg 1 4541' 5T ART BUILDING ANGLE @9680', 7-518", 29.7#/ft, U5595 BTC MOD /10722' I >- 41/2" PORTED JOINT 10289 - 10330 41/2" BLANK LINER 10330 - 10662' 4 1/2" 12.6# L-80 NSCT :>- SLOTTED LINER 10662' -11804' 4-1/2", 12.6#/ft L-80 N5CT /11827' 1 Date By 12/13/95 SGK Comments COMPLETION >- TREE: CAMERON 4-1/16" 5000 psi WELLHEAD: FMC SSH 13-5/8" SOOO psi o SSSVLANDINGNIPPLE 11547' HES "HXO" (3.813" 1.0.) . 4-1/2", 12.6#/ft, N5CT 13CR~ 80 tbg GLM's, HES MBX ,1" BK Latch NO. TVOSS MO-BKB 6 3495 3579 5 5236' 5371 4 6290 6460 3 7019 7213 7711 7928 2 8398 8637 >- . . 4-1/2" 'X' NIPPLE 110161' I (3.813" 1.0.) TIW SBR (TOP) 110215' I 7 -5/8" TIW SS 110221' I HORPZONTAL PACKER 4-1/2" 'XN' NIPPLE 110278' I (3.725" I.D.) DEV = 50· ENDICOTT WELL: 2-48/0-13 API NO. 50-029-22612-00 COMPLETION DIAGRAM BP EXPLORATION (ALASKA),INC Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563~3309 (Fax) July 11, 1996 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD SLIM1 GR for well 2-48/O-13, Job # 96113, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 1 Depth Shift Display 2 Blueline I Film State of Alaska ,.- Alaska Oil & Gas Conservation · " Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 ~.~... 1 OH LIS Tape 1 Blueline 1 RFolded Sepia ARCO Alaska, Inc. Dede Schwsrtz, ATO-1336 Anchorage, AK 99510-0360 1 OH LIS Tape I RRolied Sepia Exxon Company U.S.A. Alaska Interest Organization At'tn: Susan Nisbet 800 Bell Street, EB3083 Houston, TX 77002-7420 I OH LIS Tape 1 Blueline 1 RFolded Sepia UNOCAL Attn: Debra Childers 909 W.9th Ave. Anchorage, AK 99519-0247 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Amoco Production Company Attn: Shirly A. Kuhr 18506 Osprey Circle Anchorage, AK 99516 I OH LIS Tape 1 Blueline 1 RFolded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. P et r.o.t.e ct nj~ca~ct~ ~. ~!~.1'~ MB3-3 Anclt'or~¢e, Alaska 99519-6612 ~UL Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: '~~ (~)~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-166 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22612 4. Location of well at surface ¢ ............................ :.~ .1'#~ 9. Unit or Lease Name '~ .,..,__~ ,.*..'i~:,~ ?i r~'} ~?.; ? I~~ Duck Island Unit/Endicott 3226' NSL, 2311 WEL, SEC. 36, T12N, R16E ~ 0~':?- Attop of productive interva,~ ~~ ~ ;~ ~2,~,.~ 10. Well Number 4786' NSL, 4488' WEL, SEC. 36, T12N, R16E 2-48/O-13 At total depth ' i ~ '~'-":ii i 11. Field and Pool 618' NSL, 5208' WEL, SEC. 25, T12N, R16E "- ~ .......... ~ -" Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADL 034633 [ I I6' offshore 116. No. of Completions. 12' One 12. Date 1Spudded1/07/95 13. Date T.D.12/07/95Reached 14. Date Comp.,12/1 2/95Susp" or Aband. 15. Water depth,if MSLI 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 11836 10065 F~ 11836 10065 FT~ []Yes •No I 1547' MD! 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, DIFL/ZDI_./CN/GR/CHT, CBL, CDL/CNL, LWD, SBT, GYRO 23. CASING, LINER AND CEMENTING RECORD CASING SE-CrlNG DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BO'iq'OM SIZE CEMENTING RECORD AMOUNT PULLED 30' Struct. Drive Surface 110' 20" Driven 10-3/4" 45.5# L-80 42' 4541' 13-1/2" 747 sx PF 'E', 493 sx 'G', 150 sx PF 'E' 7-5/8" 29.7# USS-95 40' 10722' 9-7/8" 566 sx Class 'G' 4-1/2" 12.6# L-80 10217' 11827' 6-3/4" Uncemented slotted liner 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Slotted Liner 4-1/2", 13CR80 10227' 10221' MD TVD MD TVD 10062'-11804' 10066'-10065' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND Of MATERIAL USED Freeze protect w/120 bbls diesel to 1800' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12/15/95 I Flowing Date °f Test IH°u rs Tested TEsTPRODUCTION FOR ! OIL'BBLpERIOD. GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO Flow TubinglCasing PressurelCALCULATED . IOIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. I ~_4-HOUR RATE I 28. CORE DATA Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. !'i~ i'/.!~"~ :' '~ ! ~'~/ii'~ ;: '~ ORIGINAL ,. Form 10-407 Rev. 07-01-80 Submit In Dupplicate Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) LCU 9840' 9506' Kekik'tu k 9912' 9573' Top 3A 10504' 9972' ORi¢I IAL 31. List of Attachments Summary of Daily Drilling Reports, Surveys Signed St~,eSoh,,r~ ,~//,¢,(... ~ Title Senior Drilling Engineer Date ~' "' k.._.) ' '% Prepared By Name/Number Kathy Camp'o/amo~, 564-5122 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 Well: 2-48/0-13 Pilot Hole ~ AFE: 727102 Rig: Doyon 15 Days (from morning cost reports): 17 Nov 7 1995 (1) Rig moved 80 %, Rig waited : Production facilities. Rig moved 100 %. Rigged up ESD system. Rigged up Divertor. Made up BHA no. 1 .~ Tested Divertor. Rigged up Rigging equipment, Made up BHA no. 1 . Circulated at 110 ft. Nov 8 1995 (2) Set tool face. Functioned downhole tools at 110 ft. Drilled to 1113 ft. Circulated at 1113 ft. Pulled out of hole to 0 ft. Serviced Top drive. R.I.H. to 1113 ft. Drilled to 1689 ft. Circulated at 1689 ft. Rigged down Rigging equipment. Drilled to 2200 ft. Nov 9 1995 (3) Drilled to 2457 ft. Circulated at 2457 ft. Pulled out of hole to 1113 ft. R.I.H. to 2457 ft. Drilled to 3599 ft. Circulated at 3599 ft. Pulled out of hole to 2356 ft. R.I.H. to 3599 ft. Drilled to 4267 ft. Circulated at 4267 ft. Nov 10 1995 (4) Circulated at 4267 ft. Pulled out of hole to 1019 ft. Pulled BHAo Made up BHA no. 3 . R.I.H. to 4267 ft. Drilled to 4553 ft. Circulated at 4553 ft. Pulled out of hole to 3598 ft. R.IoH. to 4553 ft. Circulated at 4553 ft. Pulled out of hole to 1016 ft, Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 4541 ft (10.75 in OD). Circulated at 4541 ft. Nov 11 i995 (5) Circulated at 4541 ft. Tested High pressure lines. Pumped spacers - volume 100 bbl. Mixed and pumped slurry - 390 bbl. Displaced slurry - 428 bbl. Rigged down High pressure lines. Mixed and pumped slurry - 56 bbl. Rigged down Divertor. Rigged up BOP stack. Tested BOP stack. Installed Wear bushing. Made up BHA no. 4 . Tested M.W.D. tool - Via string. Serviced Block line. Serviced Draw works. R.I.H. to 4452 ft. Circulated at 4452 ft. Tested Casing. Nov 12 1995 (6)' Tested Casing. Drilled cement to 4541 ft. Drilled to 4563 ft. Circulated at 4563 ft. Performed formation integrity test. Drilled to 5597 ft. Circulated at 5597 ft. Pulled out of hole to 4451 ft. R.I.H. to 5597 ft. Drilled to 6455 ft. Nov 13 1995 (7) Drilled to 6482 ft. Repaired Mud pumps. Drilled to 7270 ft. Circulated at 7270 ft. Pulled out of hole to 1011 ft. Pulled BHA. Nov 14 1995 (8) Made up BHA no. 5 . R.I.H. to 4541 ft. Serviced Top drive. RoI.H. to 4937 ft. Took MWD survey at 4937 ft. R.I.H. to 7137 ft. Washed to 7270 ft. Drilled to 8271 ft. Circulated at 8271 ft. Pulled out of hole to 7230 ft. R.I.H. to 8271 ft. Nov 15 1995 (9) Singled in drill pipe to 8271 ft. Drilled to 8837 ft. Repaired Shaker discharge line. Drilled to 8930 ft. circulated at 8930 ft. Pulled out of hole to 1027 ft. Pulled BHA. Made up BHA no. 6 R.I.H. to 4920 ft. Took MWD survey at 4920 ft. R.I.H. to '8930 ft. Drilled to 8976 ft. Nov 16 1995 (10) Drilled to 9560 ft. Nov 17 1995 (11) Drilled to 9749 ft. Circulated at 9749 ft. Pulled out of hole to 1000 ft. Pulled BHA. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 7 Serviced Block line. R.I.H. to 4925 ft. Took MWD survey at 4925 ft. R.I.H. to 8900 ft. Nov 18 1995 (12) R.I.H. to 9679 ft. Reamed to 9679 ft. Drilled to 9791 ft. Repaired Suction valve. Drilled to 10050 ft. Nov 19 1995 (13) Drilled to 10076 ft. Circulated at 10076 ft. Drilled to 10148 ft. Circulated at 10148 ft. Pulled out of hole to 1016 ft. Pulled BHA. Made up BHA no% 8 . R.I.H. to 2000 ft. Serviced Top drive. R.I.H. to 4922 ft. Took MWD survey at 4922 ft. R.I.H. to 9932 ft. Reamed to 10148 ft. Drilled to 10320 ft. Nov 20 1995 (14) Drilled to 10635 ft. Circulated at 10635 ft. Pulled out of hole to 1018 ft. Pulled BHA. Made up BHA no. 9 . R.I.H. to 4493 ft. Nov 21 1995 (15) R.I.H. to 4530 ft. Serviced Block line. Took MWD survey at 4904 ft. R.I.H. to 10246 ft. Reamed to 10635 ft. Drilled to 10990 ft. Nov 22 1995 (16) Drilled to 11000 ft. Circulated at l1000'ft. Pulled out of hole to 10075 ft. R.I.H. to 11000 ft. Circulated at 11000 ft. Pulled out of hole to 999 ft. Pulled BHA. Ran electric logs. Rigged up Drillstring handling equipment. Ran Drillpipe to 1000 ft (3.5 in OD). Rigged up Drillstring handling equipment. Ran DrillPipe to 11000 ft (5 in OD). Circulated at 11000 ft. Mixed and pumped slurry - 77 bbl. Pulled Drillpipe in stands to 10132 ft. Circulated at 10132 ft. Mixed and pumped slurry - 77 bbl. Pulled Drillpipe in stands to 9400 ft. Nov 23 1995 (17) Circulated. at 9400 ft. Batch mixed slurry - 77 bbl. Circulated at 9400 ft. Pulled Drillpipe in stands to 7850 ft. Circulated at 7850 ft. Pulled Drillpipe in stands to 1000 ft. Pulled Drillpipe in stands to 0 ft. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 10 . R.I.H. to 4535 ft. Serviced Block line. R.I.H. to 4924 ft. Repaired Kelly/top drive hose. Serviced Drillfloor / Derrick. R.I.H. to 4924 ft. R.I.H. to 8300 ft. Washed to 8701 ft. Drilled cement to 8837 ft. Well: 2-48/0-13 Horz Rig: Doyon 15 AFE: 727102- Days (from morning cost reports): 19~ Nov 24 1995 (1) Drilled cement to 9100 ft. Drilled to 9275 ft. Nov 25 1995 (2) Drilled to 9672 ft. Circulated at 9672 ft. Pulled out of hole to 9250 ft. Washed to 9250 ft. Pulled out of hole to 1020 ft. Pulled BHA. Serviced Drillfloor / Derrick. Made up BHA no. 2 R.I.H. to 2160 ft. Nov 26 1995 (3) R.I.H. to 4916 ft. Took MWD survey at 4916 ft. R.I.H. to 9672 ft. Drilled to 9953 ft. Nov 27 1995 (4) Drilled to 9962 ft. Circulated at 9962 ft. Pulled out of hole to 2192 ft. Pulled BHA. Repaired M.W.D. tool. Made up BHA no. 3 . R.I.H. to 4392 ft. Serviced Block line. Repaired Internal BOPs. R.I.H. to 4917 ft. Took MWD survey at 4917 ft. R.I.H. to 9620 ft. Reamed to 9714 ft. R.I.H. to 9962 ft. Drilled to 10036 ft. Nov 28 1995 (5) Drilled to 10370 ft. Circulated at 10370 ft. Pulled out of hole to 9800 ft. Nov 29 1995 (6) Pulled out of hole to 2192 ft. Pulled BHA. Made up BHA no. 4 R.I.H. to 4913 ft. Took MWD survey at 4913 ft. R.I.H. to 9046 ft. Tested MWD - Via annulus. Pulled out of hole to 2189 ft. Pulled BHA. Serviced M.W.D. tool. Made up BHA no. 5 . R.I.H. to 4535 ft. Serviced Block line. R.I.H. to 4913 ft. Took MWD survey at 4913 ft. R.I.H. to 9116 ft. Washed to 9116 ft. R.I.H. to 9240 ft. Nov 30 1995 (7) R.I.H. to 10006 ft. Washed to 10370 ft. Drilled to 10554 ft. Circulated at 10554 ft. Pulled out of hol~ to 2192 ft. Pulled BHA. Made up BHA no. 6 . Serviced Drillfloor / Derrick. R.I.H. to 4903 ft. Took MWD survey at 4903 ft. R.I.H. to 9100 ft. Dec 1 1995 (8) ~ R.I.H. to 10413 ft. Washed'to' 10554 ft. Drilled to 10736 ft. Circulated at 10736 ft. Pulled out of hole to 9016 ft. R.I.H. to 10736 ft. Circulated at 10736 ft. Flow check. Pulled out of hole to 1146 ft. Pulled BHA. Serviced Top drive. Tested BOP stack. Made up BHA no. 7 . Tested M.W.D. tool - Via string. R.I.H. to 4440 ft. Dec 2 1995 (9) Serviced Block line. R.I.Ho to 10554 ft. Took MWD survey at 10554 ft. R.IoH. to 10736 ft. Circulated at 10736 ft. Pulled out of hole to 9000 ft. Flow check. Laid down 7860 ft of 5 in OD drill pipe. Pulled BHA. Rigged down Top ram. Tested BOP stack. Rigged up Casing handling equipment. Held safety meet- ing. Ran Casing to 10722 ft (7.625 in OD). Dec 3 1995 (10) Ran Casing to 10722 ft (7.625 in OD). Circulated at 10722 ft. Mixed and pumped slurry - 116 bbl. Rigged down Casing handling equipment. Rigged down BOP stack. Serviced Drillstring handling equipment. Made up BHA no. 8 . Dec 4 1995 (11) Serviced Top drive. R.I.Ho to 10363 ft. Drilled cement to 10635 ft. Circulated at 10635 ft. Tested Casing - Via annulus and string. Pulled out of hole to 10635 ft. Ran electric logs. Dec 5 1995 (12) Made up BHA no. 9 . Tested Survey instruments - Via string. R.I.H. to 3985 ft. Serviced Block line. R.I.H. to 10585 ft. Took MWD survey at 10585 ft. Drilled cement to 10746 ft. Circu- lated at 10746 ft. Circulated at 10746 ft. Serviced Fluid sys- tem. Logged hole with LWD: Directional (DIR) from 10580 ft to 10620 ft. Drilled to 10746 ft. Dec 6 1995 (13) Drilled to 10984 ft. Pulled BHA. Circulated at 10984 ft. Pulled out of hole to 10984 ft. Downloaded MWD tool. Made up BHA no. 10 . Tested M.W.D. tool - Via string. Serviced Top drive. R.I.H. to 10902 ft. Circulated at 10902 ft. Drilled to 11197 ft. Dec 7 1995 (14) Drilled to 11537 ft. Circulated at 11537 ft. Pulled out of hole to 10615 ft. Circulated at 10615 ft. Pulled out of hole to 3892.28 ft. Pulled BHA. Dec 8 1995 (15) Downloaded MWD tool. Made up BHA no..11 Tested MW/) - Via string. R.I.H. to 11474 ft. Reamed to 11474 ft. Drilled to 11836 ft. Circulated at 11836 ft. Pulled out of hole to 10700 ft. Circulated at 10700 ft. Pulled out of hole to 3615 ft. Pulled BHA. Dec 9 1995 (16) R.I.H. to 3649 ft. Serviced Block line. R.I.H. to 11700 ft. Reamed to 11836 ft. Circulated at 11836 ft. Pulled out of hole to 11836 ft. Circulated at 11836 ft. Pulled out of hole to 10700 ft. Circulated at 10700 ft. Pulled out of hole to 3451 ft. Pulled BHA. Ran Casing to 1606 ft (4.5 in OD). Circulated at 1606 ft. Serviced Top drive. Ran Casing on landing string to 11827 ft. Dec 10 1995 (17) Ran Casing on landing string to 10574 ft. Circulated at 10574 ft. Ran Casing to 11827 ft (4.5 in OD). Circulated at 11827 ft. Set Production packer at 10221 ft with 3500 psi. Displace treat- ment. Pulled Drillpipe in stands to 10217 ft. Circulated at 10217 ft. Laid down Dritlpipe of 10217 ft. Laid down Tubing of 1100 ft. Laid down Drillpipe of 960 ft. Conducted slickline operations on Slickline equipment - Setting run. Dec 11 1995 (18) Conducted slickline operations on Slickline equipment - Setting run. Rigged~down Top ram. Tested Top ram. Conducted slickline operations on Slickline equipment - Setting run. Rigged down Slickline unit. Rigged up Tubing handling equipment. Ran Tubing to 10219 ft (4.5 in OD). Dec 12 1995 (19) Ran Tubing to 10227 ft (4.5 in OD). Stung into Permanent packer. Space out tubulars. Circulated at 10227 ft. Ran Tubing to 110226 ft (4.5 in OD). Rigged down Tubing handling equipment. Worked on BOP - BOP stack. Installed Xmas tree. Removed Hanger plug. Tested Tubing. Tested Production packer - Via annulus. Freeze protect well - 25 bbl of Diesel. Freeze protect well - 120 bbl of Diesel. Rigged down High pressure lines. PAGE ********* ANADRILL ********** ********* SCHLUMBERGER ********** *********************************************************** *********** SURVEY PROGRAM *********** COMPANY SSD WELL NAME 2-48/0-£3 (PN) LOCATION 1 ENDICOTT LOCATION 2 BOYON 15 MAGNETIC DECLINATION 28,65 GRID CONVERGENCE ANGLE 0.00 DATE: ~ELL NUMBER 0 AP! NO, 50-029-22612-00 WELL HEAD LOCATION: LAT(N/-S) 0.00 D£P(E/-~) 0,00 AZIMUTH FROM ROTARY TABLE TO TARGET IS * GYRO SURVEYS TiE iN POINT(TiP) : MEASURED DEPTH 77,00 TRUE VERT DEPTH 77,00 iNCLINATiON 0.00 AZIMUTH 0,00 LATITUDE(N/-S) 0,00 DEPARTURE(E/-W) 0,00 321,03 RECEIVED BPXA PDC PAGE ************* ANADRILL ************~* SURVEY CAlCUlATIONS ************* ~IR~ULAR ARC ME?HOD******** MEASURED iNTERVAL VERTICAL DEPTH DEPTH 77,00 0,0 77,00 i80,00 103,0 180,00 271,00 91,0 27i,00 362,00 91,0 361,95 453.00 91,0 452,77 TARGET STATION AZIMUTH LATITUDE SECTION !HCLN. H/-~ ft deg deg ft 0,00 0,00 0,00 0,00 0,00 0,03 227,40 -0,02 0,72 0,9! 316,10 0,49 3,56 2,68 318,50 2,60 9,1~ 4,46 312,20 6,57 DEPARTURE ~ISPLACEMEH? at E/'W ft ft 0,00 0,00 '0,02 0,03 -0,54 0,73 -2,45 3,57 -6,48 9,22 AZIMUTH deg 0,00 227,40 312,09 316,71 3i5.40 DLS deg/ 100f~ 0,00 0,03 1,00 2,0~ 546,00 ?3,0 545,39 638,00 92,0 636,77 728,00 90,0 725,88 825,00 97.0 82!,47 917.00 92,0 911,76 I7,41 5,90 307,60 II,92 27.58 7,33 302,90 17,99 39,69 8,77 306,60 25,20 55,59 i0,77 305,60 34,89 72,67 11,39 306,60 45,31 -!2.95 17.60 312.S3 1.6i -2i.62 28,13 309,76 i,66 -31.95 40,69 308,26 1,70 -45,26 ,7,14 307,63 -59,54 14,89 307 ov 0,71 · - ,~Y 1048,19 1141,11 1238,57 1335,77 1432,61 131,2 1040.40 92,? 113!,52 97,5 1227,03 97,2 1321,92 96,8 1415.92 97,46 II.23 304,36 60,24 114,75 1-1,36 301,51 70,!2 132.91 1i,57 299,72 80.00 152,78 13.57 302,02 90,88 I74,96 14,18 305,70 103,82 -80.49 100,53 306,81 0,36 -95,7~ 118,70 306,22 0.62 -112,43 137,99 '305,43 0,42 -130,58 159,09 304,84 2,12 -149,84 -182,29 304,72 1,11 1526,75 1619,72 1716,86 1813,33 1911,45 94,1 1507,25 93,0 1597.50 97.1 1691.76 96,5 1785,50 98,1 1880,80 I96,91 13,86 305.00 !17,02 218,15 13.96 301,14 129,20 240,32 I3,98 302,88 141,63 261,97 13,37 302,59 153,96 283,90 14,19 299.15 165,93 -I68,44 205,10 304,79 0.39 -187.15 227,42 304,62 1,00 -207.03 250,84 304,38 0.43 -22A ~ .,~i 273,64 304,24 0,63 -246,28 296,97 303,?7 1.15 2007,87 2104,18 2200,58 22?7,35 2390,80 9A,4 1974 oq 96.3 2067.87 96,4 2161,47 ~6,8 2255,58 93,4 2346,30 305,44 I3,66 299,21 177,25 326,92 14,I6 299,I0 188,52 348.28 13,54 296,39 199,63 369,17 13,38 299,71 210,56 390,42 14,40 305,20 222,J2 -266.54 320.10 303,52 0,55 -285,76 343,16 303,32 0,52 -307,00 366,i9 303.03 0,67 -325,69 388,67 .~ 411.07 302,79 1,76 2481,31 2576,14 2671,99 2769,87 2864,63 90.5 2434,03 94,8 2526,02 95,9 2619,10 97.9 2714,21 ?4,$ 2805,?0 411,85 14,06 305,73 235,53 433,93 14,05 303,51 248,61 455,72 13,57 303,04 261.16 477,48 13,77 299,49 273,i5 500,05 15,46 304,04 285,77 -363,6? 433,30 302,?3 0,40 -3~2,64 456,31. qnq.01.~.. O,~= - 401 . 77 47? ,~Y" 303,03 0,52 -421.J~=" 502,30 302,94. 0.~8 -44!,:'~. 526,1~ 302,?0 2,15 2960,73 3057,54 3152,82 3249.95 3345,63 96,1 2898,63 96.8 29?2,07 95,3 3083,96 97.1 3177.77 95.7 3270,40 524,32 15.00 306,10 300.26 548,57 15,35 302,31 314 ~' 572,21 !5.29 299,65 327,47 595.77 14.78 300,73 340,14 618.12 14.19 299,44 352,14 -462,48 551,41 302,9? 0,7~ -483,44 576,74 303,05 1,09 -505,02 60'I,?0 302,96 0,74 -52~.60 627,07 302,~5 0,~0 -547,5! 650,98 302,75 0,7i 3440.68 3534,34 3630.54 3727,05 382!,61 95,0 3362,63 93.7 3453.47 96,2 3546,70 96,5 3640,41 94,~ 3732,26 639.68 13,81 302.17 363,9! 660,97 14,37 298,24 375,36 682,87 !4,16 2~8.37 386.69 704,29 13,54 299,22 397,90 725,23 !3.97 300,09 409,02 -567,25 673,95 302,68 0,80 -586.95 696,71 302,60 1,16 -407,77 720,35 302,47 0.27 -627,96 743,41 302,35 0,65 -647.50 765,87 302,28 0.51 2-4~/0-13 ****~******** ANADRILL ************** SURVEY CALCULATIONS ~************ CIRCULAR ARC ~£THOD******** MEASURED iNTERVAL VERTICAL OEPTH DEPTH f~ f~ ft 3916,88 95,3 3824,78 4010.91 94,0 3916.20 4105.17 94,3 4007,74 4204.00 98,8 4103.57 4297,60 93.6 4194.36 TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deg deg ft 746,54 I3.63 301.33 420,63 767,49 13,42 305,56 432,73 789,07 14.23 303,46 445,48 811.64 14.10 297,00 457,64 832,36 14,06 296,07 467,81 DEPARTURE DISPLACE~£~T as AZIMUTH E/-W fs ft deg -667,04 788,59 302,24 -685,38 810,56 302,27 -703,94 833.06 302,33 -724,80 857,19 302,27 -745,17 879,85 302,12 DLS deg/ lOOft 0,47 1,08 1,01 1,60 0,24 4392,05 4488,75 4577.77 4671,00 4767,9! 94,4 4286.02 96,7 4379,97 89.0 4466.52 93,2 4557,17 96.9 4651.34 853,13 13.85 297.57 478,09 874,12 13.54 297,48 488,67 893.24 13.53 297,76 498,33 913,21 13,50 297,20 508,38 934,32 13,80 299,63 519,26 -765,49 902.52 301,99 0.44 -785,79 925,35 301,88 0,31 -804.25 946,13 301,78 0,08 -823,58 967,85 301,69 0,15 -843,69 990,68 301,61 0,67 4861,92 4956,86 5052,10 5149,69 5245,67 94,0 4742,64 94,9 4834.83 95,2 4927,17 97,6 5021.57 96,0 5114,29 955,12 13.76 299,01 530,23 976,23 13,88 300,12 541,42 998,02 14,45 300,45 553,17 102i,26 14,98 300,71 565,79 1044,I9 14,94 296,98 577,74 -863,21 1013,05 301,56 -882,93 1035,71 301,52 -903,06 1059,02 301,49 -924,41 1083,81 301,47 -946,10 L108,55 301,41 0,16 0,31 0,61 0,55 1,00 5340.69 5437,89 5533,71 5629,7i 5726,50 95,0 5206,14 97,2 5300,32 95,8 5393,35 96,0 5486,41 96,8 5580.12 1066,67 14,77 299.96 589,34 1089,30 13,85 303,08 601,87 1111,05 13.91 301.19 614,10 1133,32 14,51 302,73 626,58 1156,36 14,49 303,19 639,77 -967,50 1132,87 301,35 -987,98 1156,88 301,35 -1007,45 1179.86 301,36 -1027,44 1203,43 301,38 -1047,77 1227,65 301,41 0,82 1,23 0,48 0,73 0,12 5821.57 5916,65 6012,98 6109,44 6204,42 95,1 5672,13 95,1 5764.05 96,3 5857,31 96,5 5950.84 95,0 6042,75 1179,02 14,64 301,70 652,59 1202,02 15,00 302,24 665,47 1224,87 14.02 302,20 678,35 1247,11 14,27 301,23 690,73 1269,76 14,94 302,97 703,47 -1067,95 1251,56 301,43 -1088,58 1275,88 301,44 -1109,00 1300,02 301,45 -1129,05 1323,58 301,46 -1149,33 1347,53 301,47 0,42 0,41 !,02 0,36 0,~5 6298,69 6392,99 6487,80 6581,89 6677,66 94,3 6133,76 94,3 6224,82 94,8 6316.56 94,1 6407,84 95,8 6500,82 1293,14 15,31 302,88 716,84 1316,53 14,79 304,87 730,47 1339,52 14,47 304,80 744,15 1361,35 13.59 303,37 756,94 1383,31 14,14 305,00 769,84 -1169,98 1372,12 301,50 -1190,31 1396,58 301,54 -1209.97 1420,49 301,59 -1228,85 1443,28 301,63 -1247,83 1466,20 301,67 0,39 0,78 0,33 1,01 0,70 6771,28 6667.06 6962,64 7056,62 7151,91 93,6 6591,53 95,8 6684,21 95,6 6776,82 94,0 6867,91 95,3 6960,17 1405,64 14,53 306,07 783,31 i428,80 14,67 303.34 797,05 1451,32 14,01 302,89 809,98 1473,37 14,48 303,97 822,73 1496,09 14,48 303,07 B35,89 -1266,69 1489,32 301,73 -1286,53 1513.42 301,78 -1306,35 1537,08 301,80 -1325,64 1560,20 301,82 -1345,51 1584,01 301,85 0.5I 0,73 0,70 0,58 0,24 7244,96 7339,47 7433,74 7527,0? 7624,58 93,1 7050,22 94,5 7141,67 94,3 7232,84 93,4 7323,09 97,5 7417,34 1518,53 14.70 305,37 849,07 1541.31 14,56 302,08 862,32 1564,00 14,92 302,35 875,10 1586,57 14,69 301,79 887,77 1610,24 14,96 303,52 901,23 -1364,89 1607,43 301,88 -1384,73 1631,28 301,?I -1405,02 1655,26 301,92 -1425,23 1679,11 301,92 -1446,24 1704,06 301,93 0,67 0,89 0,3? 0,28 0,53 PACE HEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 7717,88 93,3 7507.49 7813,56 95,7 7599,96 7906.91 93.4 7690.21 8001.31 94,4 7781,52 8095.29 94,0 7872.46 8188,83 8285.70 8379,77 8475.48 8569.07 ~664.68 8755.36 8850.00 8951.05 9046.34 9141.51 9235.84 9331.91 9423.74 9520.42 9615.79 9709,00 9806,37" 9903,33 9996.70 10091.81 10186.16 10279.00 10373.96 I0471.12 10565.31 10657.45 10756.15 10849,06 10953°77 93.5 7963,05 96,9 8056,97 94,I 8148.25 95.7 8241.22 93.6 8332,I6 95,6 8425.11 90.7 8513.35 94,6 8605,51 101,0 8704,01 95,3 8796.64 95,2 8888,27 94.3 8977,96 96,1 9067.91 91,8 9152,00 96,7 9237.86 95,4 9319.39 93,2 9395,70 97,4 9472,23 97.0 9545.94 93.4 9614,75 95.i 9683.61 ~4,4 9751,46 92.8 9818.03 95.0 9885,45 97,2 9953.61 94,2 10019.43 92,1 10083.51 98,7 10152.67 92,9 10218.84 104,7 10294,73 ************* AHADRILL SURVEY CALCU~TIOH$ **~**~****~ CIRCULAR ARC TARGET S?ATIOH AZIMUTH LATITUD~ SECTIOH INCLH, H/-S ft de9 deg ft 1633,13 14.85 303,56 914,49 1656.58 14,89 303,97 928,14 1679,34 14,76 302,87 941,29 1702,11 14,65 302,85 954,29 1724,69 14.60 303,26 967,24 1746.68 14,21 300.63 979,56 1769,09 14.18 302,72 992,03 1790,49 13,80 299,79 1003.83 1811.66 13.65 299.89 1015,13 1832,46 13,68 302.73 1026,62 1853,67 13,43 301,60 1038,55 1873,42 ~3.24 302,07 1049.58 1893.75 13,05 301.51 1060,92 1914.8I 12,74 298,74 1072,24 1935,80 14.37 303,30 1083,79 1960.53 16,99 306,83 1098,61 1988.83 19,07 306.76 1116,09 2021,66 22.02 308.93 1136,81 2057.69 25,32 308,76 I159,92 2101.42 29.41 313,10 1189,I0 2150,44 33.05 314,16 1223,22 2203,53 37.03 313,63 1260,31 2263,29 39,33 314,92 1302,33 2326,15 41.74 320,63 1349,00 2389,25 43,35 323.68 1398,85 2454,76 43,88 324,34 1451.93 2520,27 44,15 322,21 1504,47 2584.97 44.23 322,08 1555,57 2651,80 45,31 324,08 1609,04 2720,85 45.59 326,25 1665,86 2788,03 45,75 324,56 1721,32 2854,02 46.i4 326,69 1775,97 2924,14 44.89 325,72 1834,48 2989,11 44,28 326.50 1888,63 3061,03 42,82 324,62 1948o13 2-48/0-13 D~PARTUR£ ~ISPLAC£M£HT at E/-W ft ft -1466,24 1728.05 -1486.65 1752,59 -1506,59 1776.46 -1526,71 1800.43 -1546,61 1824.16 AZIMUTH de§ 301,95 301,98 302,00 302,0! 302,02 -1566.35 1847.43 302.02 -1586o57 1871.18 302,02 -1606.00 1893,~2 302,01 -1625,69 - 1916.60 301,98 -1644.57 1938,70 301,97 -1663,55 1961.11 301,98 -1681,32 1982,03 301.97 -1699,61 2003,55 '301,97 -1719,I1 2026,09 301,95 -1738.21 2048,41 301,94 -1759,21 2074,07 301.98 -1782,59 2103,17 302,05 -1809.19 2136.70 302.14 -1837.90 2173.31 302,26 -1871.37 2217,20 302.43 -1907.13 2265,70 302,68 -1945.69 2318,21 302,93 -1988.77 2377,24 303,22 -2031,02 2438,20 303,59 -2069.73 2498.11 304,05 -2108,28 2559,87 304,55 -2147,48 2622,04 305,01 -2187,19 2683.95 305,42 -2227,35' 2747,75 305,84 -2266,90 2813.17 306,31 -2305.15 2876.92 306,75 -2342,53 2939,64 307,17 -2381,68 3006,29 307,61 -2418,05 3068.20 307,99 -2458,84 3137.06 308,39 DLS deg/ 'lOOft 0,12 0,11 0.33 0,11 0,12 0,82 0.53 0,85 0,16 0,72 0,38 0,24 0,24 0,68 2,04 2,92 2,22 3,17 3,59 4,70 3,86 4,28 2,50 4,56 2,80 0,74 1,59 0,14 1,87 1,62 1,29 1,72 1,45 0,87 1,86 77,00 'SO~O0 E7!, O0 DEF'TE e=r-~' .-. n.'..: f~ f: ft deg d~ ft 91,0 ZTi,CO 0,70 0,91 316,10 .... ,,~, ~z,~0 6,57 z-~::-'~ ,39 · - 5, 307,60 725, ~A,R2 ROA,A0 ,z: .... =.,7, - - - 70,02 1048,:., £&~.l, __ ! 33=... 7.-; !432, .-5! 1813,30 ?2,9 ~,o,,52 1!0,3i '"" z~ ,~.6 ~!,51 70,13 :' ........ ':'~ "~" ~" 13,57 .,...'-w ,,*_, 188,65 !3,86 305,00 117,02 1597,50 lo,v., o0!,14 1~/,20 .. ~ - . . ~.,,.j ! 785,.;~.-?':_,~,"='"', ,5.~ ! "a, o/'-'" 302~ 5',:-* 153, % ' ri,qr-- ~ · - ,-~ ~-_~':,cO 271,46 14,:y ~Y:'"'". 15 165,7o .'. 6,'~ 1974,2;' .... ., ~i. ,ol ~,_ _. iq,AA .. 2S~, ,".:.. 177,25 ~" O~L7 0'7.. 96,.:: ,.~ .... ,..,, 5,12, i 14,16 ~97,I0 188,52 95~4 216!,47 -'~"- 27 · .. ~-'- ?A,3 ~s9,--8 ~,'-.-...-, ~o oo "'"" "' 2!0,56 ..... " "'" ..... "'"" ~= i4:40 ~'= ..:~, :?o,cv or.','_. ,?:/.~, 20 222.,62 -~.-,. ,-.-. ,w~ :-, 15,"":' om: ~- ':-'-'f-, I .-: :.o.~c<: %v. -. . ~./ ='J:d ~..,,..,;.,+ _-d ~:yz~,:, 522,37 ..... 302 "' 314,51 · -' "-.2*0.? 5'5,.3 '-,~,"", --,, ",-', o ...... -, out-:.- · .",:, >,_,,-o--' ~, .--_-- 299,65 · /,: ~i/,',/.,' 5,t,~, i3 i ,. - .'~,,'o Y00,73 340,14 ";'~-7 "":,-=--", an S,qg.~ ~4.,~o 2.o9,44 3.=,2,14 ~, :.'.':' ~62,63 .~37,76 !3,81 302,17 362,9! :?.,.,, 650,59 '~ ~x ~',,. y~' ', 6~/~,~-..~, ...... .... ~ 690,63 I 3,97 303,09 ~, 03 · o,ev, 6.:.. 'Z' -"'.) ff ** 3,3.-30,54 '.-=:727.05 '.7'A£ ~ -_ - ,.-:-£ 2-48/0-13 DF.,P.-~:%~ "'"'"'"" ^'"'="'"'~"'"' AZIMUT~ DLS ~'-W dea'_/ o ft ft de,g 10Oft 0,00 0,00 0,00 O,GO -0,02 0,03 .2.?.7, ~00,03 ..~. 0,73 312,09 1,00 -..- ,4~; 3,57 0.,,' -1 _ ,.,z,...; _i ,,'?5_. -6,45. 9,~ 3!5,40 ,_,° .~_.. -12,75 17,60 3!2,63 1,6I -,:.t ,-:.: 28,:0' ~ 30; ,7. i, ,.~. 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"' ': ' " ' '-'-?..3745~,40 .,/:.' 3~1,S9 1,03 2526.55 -2804.62 -~-: 3774,83~' ::- '312,01 2,32 :' ' 2554,67 -2822,64 .';;:;;.3807,05 ..,'.~, 312,15 "' 3,41 ~::;!2580,19 -2838,78 -"~Li3836,15?~'.>.::312.27 1.36 D~F'TH .ft 11473.60 "11503.30 11537,30 11569,20 11598,20 11633,00 11663.50 11696,90 11727,10 :. .; .";'- .* :7.~.?-c.... ,~., r.... :i; -. . · . . . . , .-.-4/?~..-. _ ~.- :...-. '; ' i / " ' ' '": :: " ~ '- ' · . .... ;- -...-_-, · ; -. . . ... · 7':' * .. · :. . · ¥ · .~ ~ -. -' :~._...:,.).~.- '-.. ~ '. ... . ' ~ :,"_ .~ ~ ' .. ~,.;. . .................... ~.... . _ ..... -- .:;:-= ...... .~.: ..... .,~--..:-... '..._.. - ..... ; "~...- . -~ . ,-_ ._,., . ,;.~>,').'-~.,-<¥ ....;: :'~ ...... .. - . '. ,..~.., ::. .... · , ; ..,'* . -,: ~,,-,j'-'? : ....- _ .. . · - - -.,. .. · ;~' E;';~,;'..:,:,_.:.,t;.,....,'., .'. .... ..;.~- .. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 December 1995 Transmittal of Data ECC #: 6530.01 Sent by: HAND CARRY Data: SBT/GR Dear Sir/Madam, Reference: 2-48/O-13 PH ~' ~-- ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 PleaSe sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 -780~ate: Received~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS Date: 12 December 1995 Transmittal of Data Sent by: HAND CARRY 6185.13 Run ~ 1 6530.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 /7 Anchorage, AK 99elS. // Or FAX to (907) 563~D~ Receivedby: ~ / ~~ ~~ Da~0~.~. LARRY GRANT . Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A/<, 99501. Date: 7 December 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~,,~.. / ~ 2-48/0-13 PH DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run ~ 1 5869.07 Run # 1 5921.11 Run # 1 6530.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 -PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF 1 ZDL/CN FINAL BL+RF 1 DIFL FINAL BL+RF 1 BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF Run Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5756.08 6185.13 6530.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~AX to (907) 563-7803 Received by:/"--~~ ///~?~ Date: RECEIVED DEC '1 4 1 g5 Alaska Oil & Gas Oons. Commissior Anchorage MEMORANDUM. State of Alaska Alaska Oil and Gas Conservation Commission TO' David Johns_~~, DATE: Chairman---x"' . . . November16, 1995 THRU: Blair Wondzell, ,~~ FILE NO: P. I. Supervisor QKHJKPCD.DOC FROM: SUBJECT: Lou Grimaldi, Petroleum Inspector Rig BOPE inspection Doyon rig #15 BPX well #2-48/O-13 Endicott Field PTD # 95-166 Thursday, November 16, 1995' I traveled to' the Endicott Field to make a Rig BOPE inspection on Doyon rig #15. · The rig was drilling ahead when I arrived, i found all BOPE equipment to be in place and in apparent good condition. I discussed with Eddie Vaughn (BPX Drilling Foreman) the upcoming completion on this well. .. The rig was clean and had the appearence of. regular maintenance. Access to the rig was adequate. The location surrounding the rig was clean and orderly. SUMMARY: I made a Rig/BOPE inspection on Doyon rig 15. · Attatchments: QKHJKPCD.XLS CC' ERATION: Drig Contr: Operator: · Location:' STATE OF ALASKA ALASKA' OIL AND GAs CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT Drilling X Workover Nabors . BPX Section 36 T. 12N Cmpl. Well Name: Rig No. 15 Rep: _.. R. 16E M. UIC 2-48/o-13 Rep. Eddie Vaughn DATE: 11 / 16/95 PTD# 95-166 Rig Ph.# 659-6510 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kilt Ln.)- Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: IN.COMPLIANCE IN COMPLIANCE INSPECTION ITEMS (C.) MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) ~Hydraulic choke panel Choke manifold INSPECTION ITEMS (E.) MISC. EQUIPMENT Flare/vent line All turns targeted (downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping Rig in good shape IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK 9/11/95 None Kill Sheet Current? Yes Distribution: orig - Well File c - Open/Rig c- Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: F1-022 (Rev. 3/93) Louis R Grimaldi Eddie Vaughn QKHJKPCD.XLS TONY KNOWLES, GOVERNOR ALASF~ OIL A~N~D GAS CONSERVATION CO~VDIISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-143,3 FAX: (907) 276-7542 October 31, 1995 ..- .: Sieve Shultz, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: .. . . Duck Island Unit/Endicott 2-48/O-13 BP Exploration (Alaska), Inc.- ' Permit No 95-166 Surf Loc 3226'NSL, 2311'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc 580'NSL, 5183'WEL, Sec. 25, T12N, R16E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddiling operations until ali 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) of the BOPE test performed before drilling below the surface casing. shoe must be given so that a representative of the Commission may witness the test. Notice may be nspector on the North Slope pager at 659-3607. David W. Johnston ~ -' ~ Chairman '~ ~ - . BY ORDER OF THE C MISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation- w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ,a. Type of work Drill [] RedrillFIIlb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenElI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 3226' NSL, 2311' WEL, SEC 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 4968' NSL, 4623' WEL, SEC 36, T12N, R16E 2-48/0-13 2S100302630-277 At total depth 9. Approximate spud date Amount 580' NSL, 5183' WEL, SEC25, T12N, R16E 11/01/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and fVD) property line ADL312827 4700 feet 2-46/Q-15 & 2-50/U-08 feet 2560 11815'MD/10076'TVD feet 16. To be completed for deviated wells !17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kiokoff depth 900 feet Maximum hole angle 9o o Maximum surface 4188 psig At total depth (TVD) 9616'/5150 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30' Struct. Drive Pipe 90' Surface Surface 130' 130' Drive 13-1/2" 10-3/4" 45.5# L-80 BTC 4480' Surface Surface 4536' 4424' 747sxPF'E', 493sx 'G', 150sxPF'E' 9-7/8" 7-5/8" 29.7# uss-95 Butt 10762' Surface Surface 10762' 10076' 537sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 1615 10200' 9933' 11815' 10076' Uncemented Slotted Liner Slotted 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural !~. ' ~' P Conductor · ~'' '" ~ I ~ ~ Surface Intermediate 0CT '1 9 1995 Production Liner ~J¢ 1¢il .& 6as Cons. Commissior~ Perforation depth: measured ' 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[] 21' Iherebycertifythatthef°reg°in¢lcistrue'-'a'nd~tt°thebest°fmykn°wledge,.,. . ,//?~_'-~ /7- ~ kd\ b~gnea .;,4. .,/) ,/~'~..~,._.~ /~~/%\^, Title Senior Drilling En~lineer Date ~ '" """ ""' ' '[3-~ission Use Only Permit Number APl number Approv~ date See cover letter /~,~-,//.~"~' 50-O~._~'-'2..2.~/2_, /'©//~,,,~///~,,~--' for other requirements Cor~ditions of approval Samples required [] Yes 'j~ No Mud log required []Yes ,1~ No Hydrogen sulfide measures .J~ Yes [] No Directional survey required ,~ Yes [] No Required working pressure for BOPE []2M; 1-13M; 1~'I5M; 1-110M; I-I15M; Other: Original Signed By by order of Approved by 0avid W. Johnston Commissioner me comm.ssion aate/,O,/,~Z,~J~ Form 10-401 Rev. 12-1-85 Submit in ' Well Name: ] 2-48/O-13 Well Plan Summary Type of Well (producer or injector): I 3A4 Producer I Surface Location: 3226FSL 2311 FEL S36 T12N R16E UM Target Location: 4968FSL 4623 FEL S36 T12N R16E UM Bottom Hole Location: 580 FSL 5183 FEL S25 T12N R 16E UM I AFENumber: [727102 I Estimated Start Date: [ 11-1-95 IMD: I 11815 I Rig: [DOYON 15 / I [Operating days to complete: I 32 [TVD: 110076 I I KBE: [56 Well Design (conventional, sHmhole, etc.): [ SLIMHOLE HORIZONTAL Formation Markers Horizontal Well Bore: Formation Tops MD TVD (BKB) UPPER SV SHALE 3434 3356 BASE UPPER SV 3765 3676 TOP SV MARINE 4224 4121 SHALE BASE SV MARINE 4363 4256 SHALE SV-5 4256 4363 BASE SV-5 4636 4521 TOP UGNU 5859 5706 . TOP WESTSAK 6845 6661 r~ ,. ., . ~ 1~ D TOP 7825 7611 SEABEE/AYLYAK 0C T '! 9 !995 TOP SHALE 8986 8736 WALL/TUFFS fila$~ 0il & Gas Cons. Commiosion HRZ 9558 9291 finchorallo BASE HRZ 9843 9566 PUT RIVER Absent LCU 9843 9566 ITKILYARIAK 9843 9566 KEKIKTUK 3C 9896 9616 5150 psi Abnormally High Pressure Possible 3B 10211 9876 5150 psi.Abnormally High Pressure Possible 3A 10430 10001 4720 psi. 2B 10246 2M 10326 2A 10361 lC 10611 GOC 3B OWC 3A2 10136 Casing/Tubing 'rogram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 13.5 10.75 45.5 L-80 BTC 4480 0 4536/4424 9.875 7.625 29.7 USS-95 Butt 10762 0 10762/10076 6.75 4.5 12.6 L-80 1615 10200/9933 11815/10076 Logging Pro Open Hole Logs: Cased Hole Logs: ,ram. DIFL/ZDL/CN/GR/CHT (PILOT HOLE) FMT as appropriate (PILOT HOLE) Horizontal Hole MWD,GR (Horizontal Hole) SBT/Gyro Mud Program: Special design considerations ] Refer to attached change over procedures to displace mud to [Flo Pro Surface Mud Properties: [ SPUD Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 300 40-60 30-60 60-80 8.5-9.5 none- 10 to to to to to to to 9.5 100 20-40 15-20 20-30 8.5-9.5 none-10 Intermediate Mud Properties: Subject to Pilot Hole Properties. The mud weight in change based on pilot hole drilling results, intermediate hole may vary based on pilot hole results. Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2-10.8 50-6- 20-30 12-15 25-30 9.5-10.0 <6 Production Mud Properties: Subject to [ FLO PRO change based onPilot hole drilling results I Density Marsh Yield 10 sec 10 min LSRV Fluid (PPG) Viscosity Point gel gel cps Loss 9.2 NA 40-45 18-23 24-29 + 50,000 +6 Clorides mg/liter + 40,000 K:N ratio >2 OCT 'i 9 1995 Oil & Gas Cons. Commission Anchorage Well Control: Well control equipment consisting of 5000 psi. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: [KOP: 1900 Maximum Hole Angle: Close Approach Well: 48 in pilot hole and 90.0 in High angle hole 2-46/Q- 15 and 2-50/U-08 The above listed wells will be secured during the close approach. Deep well intersections NONE. Disposal: Annular Injection: The Doyon solids handling unit will be utilized for the entire well. cuttings that cannot be injected should be hauled to CC-2A. All other Insure the Annular Injection Guidllines are followed. DO NOT EXCEED 35,000 bbls IN ANY ANNULUS. Maximum injection rate is 3 BPM and maximum volume is 1,000 bbls in any 24 hr period. Maximum injection pressure is 2000 psi. The following well(s) are approved for annular injection: AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (aBES) (aBES) END - MDI 2-40/S-22 0 35,000 1-1-95 thru 12-31- 3-31-95 95 END _ MPI 1-31/M-21 0 35,000 1-1-95 thru 12-31- 95 END-MPI 1-19/I-18 0 35,000 6-28-95 thru 12-31 - 95 END_MPI 1-33/M-23 0 35,000 8-31-95 thru 12-31- 95 END - MDI 1-23/O-15 6756 35,000 1-1-95 thru 12-31- 3-31-95 95 OCT '1 9 1995 Alaska Oil & Gas Cons. Commission Anchorage 2-48/O- 13 Operation Summary le ~ 2. 3. 4. Test diverter. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadrill & Gyrodata to insure they are following JORPS. hole to 4424' TVD. Drill o 6. 7. help pick final TD (175' below lower most possible perforation in 3A4). Have sample catchers and well site geologist on site before drilling the Kekiktuk. 9. Use key seat wiper for Tuffs and HRZ. 10. RU E/Line & run open hole logs (DIFL/DZL/CN/GR)+ FMT. 11. Sequentially spot balanced plugs across the reservoir, and to 9000 for the kickoff plug Co Man Reset Well Name User Defaults in DEAP 2-48/O-13 pilot to 2-48 / O-13 I-Ioriz. 12. WOC 12 hours. Directionally drill intermediate hole to 10,762 TVD. Well site geologist will help pick final target TVD based on pilot hole results. 13. Run 7-5/8" production casing and cement. Straight blade centralizers should be run 2 per joint through the pay zone and one per joint to 300' above the reservoir section. 14. After 24 hours WOC, run bond logs on wire as deep as possible. 15. PU 6-3/4" BHA and drill 10' outside 7-5/8" casing. Change over mud system to FloPro. No FIT should be necessar~y.~ (Reference Recommended Practices for Intermediate Hole V1.0 page 4 of 4 12-20-94) Directionally drill horizontal section to 11815'. 16 .Make hole opener run with 7-5/8" casing scraper spaced out to the packer setting depth approximately 10,200'. 17. Run 4-1/2" L-80 slotted/solid liner with liner top packer at 10,200' ( Objective is to place the XN nipple in liner to 50 degrees ). Release from the packer and displace Flo Pro mud to filtered sea water. Spot lithium hypo chloride breaker across the liner. 18. RU wireline and set standing valve in 4-1/2" XN profile in the liner top. Run 10-3/4" 45.5 ppf surface casing. Cement surface casing. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. ND diverter. NU Bop's & test. Drill out shoe and perform LOT. Directionally drill pilot hole to 10,928' TD. Well site geologist will 19. Run 4-1/2" 13CR-80 completion with SBR and locate onto slick stick on the SS packer. 20. ND Bop's. NU and test 4-1/16" 5M# tree. Test packer. 21. Freeze protect tubing. 22. RD MO Rig. Distance to nearest well 2-46 / Q-15 11.7' at 576'MD and 2-50 / U-08 11.7' at 476'MD Max surface pressure 4188 at total depth (TVD) 9616 @ 5150 psig OCT ~ 9 1995 Alaska Oil & Gas Cons. Commission Anchorage 2-48/0-13 Cementing Summary 2-48 / O-13 CEMENT PROGRAM- HALLIBURTON 10-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 747 THICKENING TIME: 5+ hfs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 493 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Lead slurry w/30% excess over gauge hole. 2. Tail slurry to 34034w/30% excess over guage hole. 3434 'MD = top of SV shale 2. Top job volume 150 sx. 9-7/8 Pilot Hole Abandonment CEMENT TYPE: Premium ADDITIVES: .2% Halad 344,.2% CFR-2 WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. SACKS: 742 THICKENING TIME: 3hrs CEMENT VOLUME Volume based on placing cement to 500' above the top of the Kekektuk with 10% excess. OCT I 9 i995 Alaska Oil & Gas Cons. Commission Anchorage MIX WATER: 5.00 gps 9-7/8" Kick Off Plug CEMENT TYPE: Premium ADDITIVES: .6% CFR-3,.25% LAP WEIGHT: 17ppg YIELD: .99ft3/sx APPROX. SACKS: 323 THICKENING TIME: 2:45hrs CEMENT VOLUME Volume based on placing cement 100' above kickoff point of 9100' with 30% excess. MIX WATER: 3.6gps 7 5/8" PRODUCTION CASING CASING SIZE: 7-5/8", 29.7# CIRC. TEMP 135°F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 537 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. Note: Cement to be mixed on fly the last half to have .4~ of Super CBL per sack added and increase density to 16.5 ppg. (1.05 cu-ft/sx) Have Halliburton record density on chart recorded. SPACERS: Pump 50 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Displace at 14 bpm with rig pumps. CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 9896. Gas Cons. Commission Anchorage ~5 10:40 Anad 11 DPC gO; ;44 2160 P.08 SHARED, SERVICES DRILLI,NG I ~- I d-qU/U-15 [HA UbUIIUNi , VERTICAL SECTION VIEW ~o-~ ........... ......... Section at: 327.S¢ TVD Scale.' 1 inch = 1200 feet o-- ~ ; . Der Scale.' ~ inch = ~200 feet , Drawn ' ~0/05/95 0-- , ~ Marker Identification- MD BKB SECTN INCLN ~ ~ A) TIE-IN 9100 8847 1852 14.28 ~ B] CURVE 8/100 9797 9522 2006 ~4.28 ~ C) END 8/~00 CURVE 10762 ~0076 2705 90.00 0-- ' ...... 01 TARGET (aSL) 10762 ~0076 2705 90.00 ~ ' El ID tt8~5 ~0076 3758 go.o0 ~r~ ~ ~¢~' '*~ ......................... 3~ ~ ~ ~ - ~ ~r ....................... ~ ...... ',z~ ~a ~c~t- '~- - ~': ~ ......... - ........ '" - ..... '-· ---A~PC~ ~~,~ ~.,,~,--v F'EA:SIP~L~ITy PLA N ', h40T APPl?~Vi-~ ~'~R o~-., , ~ . . _ ...... ~ _ , .,, EXECUTI()N~~ ~u_. ._..', _. PL &N -~~~~ : ~ ~-": ._ . . ....... . ' , ', '~- ~''~ i:~"~'~ I ', '0Cl I 919'~:':;~., ........... ! I ,,- -- ',' &lasl a ~il & Gas Cons. ;ommissi, ~ni ' -- _ j. A mhorage ~' ....... ........ ]", ............ 'r~'~- ~r .... . ................. , -%m~[7~ ..... : .... ~ ..... . ~o ~oo ~oo ~soo ~qoo 3ooo' 3soo ~2oo ~soo s~oo [ooo ssoo ~oo 7~oo Sect~oa lU · SHARED" SI-RVICt-S. DI::tTLL:[NG 2-48/0-~3 [HA SECTION) (P3) VERTICAL 'SECTION VIEW 'U---- · ~ ~.~,. .~ im~ ' ,.]~L,L,IUll IlL, ."1~'/ \%-- Oep Scale.' ! inch = 300 feet 0-- .! HapkeP Identification HD BKB . SECTN A) TIE-IN 9JO0 8847 1852 ~4.; , I B) CURVE 8/100 .9797 9522 2006 0 ...... · , C) END B/t00 CURVE 10762 10076 2705 go.i ~ ' 01 IIR~EI IBSU ~076;~ 100715 2705 90.1 ~ ...... nc--- ~-\ , . - .i ' . ' ... ,\~ . , . ' ~[ '~ -' . . .. ,', ' " ' A[~,'-.DRILI AKA DPc' ; "' "~:., ,. !!31LiTY )LA[q ' j ,' ~ % , . , . D. F()R ,_ __ . ,, ~..._ ~. .. E ~EC.IjTIC ~~.. -,~,, , . pbkN ~'~: ~. ( l- ~~' ~T~ .... - · , ~ ~ ~ . 7 ' "" .~_= :=_ . - .: :.~ ..... , ._ -: , S:..._..._. ......... ', 1 ...... . ..... .... '~'~' ~'"~ " , I , ~"-1 '. '~2~ -~'flc-' ~ '' , ~ '-~ ', ' ,' . '. ~. '.: . ~. . . T 7 T- -;....- , (Ana~rill [c) g50I3P3HAW ;2.51),02 1:55 PM'P; O0 O0 ' ~500 1650 JSO0 .4950 2100 2250 2400 2550 2700 ...2850 3000. 3150 3300 3450 3500 ',3750 3§00 4050. 4200 Section OepartU're' ,.' ,.., .' ,,' .. Il IIIl ' Ilii : . . 0ct-06-95' 10:42 Anad~-~xl DPC 907 ~44 2160 P-10 mill SHARED'SERVICES DRILLING i i imm mm Marker Identifica[ion A) TIE-IN' B) CURVE 8/100 C) END B/lO0 CURVE D) TARGET (BSL) E) TD MD N/S 9100. 1093 9797": 1183 10762 ' 1742 10762 1742 liB15 2634 E/W 1742 1889 2313 2313 2873 2-'48/0-~3 (HA SECTION) (P3) PLAN VIEW CLOSURE 3898 feet at Azimuth 312.52 DECLINATION.' +0'.000 (E)- SCALE ' t inch : 500 feet DRAWN. · 10/0§/95 3250 3000 2750 .2500 (~Pill (C)~ O~3P~tAW 2.~.02 i:~ PM P) I F'E/k$i ~ ~ t TTM PU ~',N , .. NO'l'/-\P -~R'O'~/Ft~ :OR ¢ - . ' ., EXE~.2'UT ON ~. ........ : .... -.. . , . I ................ ~ ~ . . . ............ ~. .. --, , . ........ ~ " ¢ ~. : ()CT 'i a i995 ~ [ ~1 ~ Gas ;OHS. 6on~mmsmn ~ -. ---~.~.. ~oh(~rage. ......... ~ . :-.- , 50 1250 lO00 750 500 250 .0 250 <- WEST' EAST -> 2250 2000 1750 1500 250 ";' Z .o 0ct-06-95 10:42 Anadr:ll DPC 907 ~4 2160 P.1 SHARED i iiii Marker Identification ' MD A) -TIE~IN ' glO0 B) CURVE 8/~00 9797 C) END 8/.100 CURVE - 10752 Ol TARGET (8SL] 10762 E) TO ! t815 SERVICESDRILLING · la i i .xs- ~x, 12-48/0-13, (HA SECTION) (P3) ~ '~~ PLAN VIEW ~742 2313. i74~ 23~3 2634 2873 CLOSURE ' 3B98 feel DECLZNAT[ON' +O.O00-(E) SCALE.. .....'-! Jnc~ = 300 feel . DRAWN ' · J0/05/95 ' " 'N~ /' ' F:"'?:.,;" cf::" 1 lq.-"(' ' ,.; _, F'I._ ~,N ' \ 'lqO"F/-.,P~PRO YED FOR: .IXX r LAhl "/-,~ '!~7 c~-m~--- " ~ 'i';- "]~--~ .... ' . ' .... X N ~ -" .. - . .... · ...... [ . -I .. ! .. · I ,< . ., ,~ r-- ........ I ........ " - . . ~ -.. ............................. 3300 3150 ~00 2850 2700 2550 2400 2250 2100 1950 1800 1650 1500 ~350 1200 <- WESI P-07 I I I I I I I ~~; .............................. Inj. Well Name ...... ~. , .,~7,~,;~ Sud Csg Dep VOLUME (BBLS' Method of displosal=pumping down outer annulus SOURCEWELL DATE OF DIESEU Dally Cum. MUD/CTGS BRINE WATER COMPLICATIONS, COMMEN~ NUMBER INJECTION FREEZE PROT, T o t a I ........................ ~ =: :~ ~ ~4~ Page 1 Request for Annular Injection Well 2-48/O-13 will be drilled in accordance with the attached Permit to drill. The following criteria for annular injection have been met. 1)The Surface casing will be set 4424 TVD BKB which is below the required SV shale 3,200'-3,500' TVD. 2) A determination has been made the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 3) Pumping into hydrocarbon reservoir will not occur. OCT '!9 i995 ~,laska (J~l & Gas Cons, Commission Anchorage Pilot Hole Abandonment Plug Well 2-48 / O-13 RIH to TD of pilot hole 10 MD. with open ended DP. Circulate. RU Hallibui'ton. In sequential stages lay 152 of balanced plugs across the reservoir. Volume based on bringing cement top 500' above reservoir and 10% excess over gauge hole. G Cement +.2%Halad 344+.2% CFR-2 15.8 ppg 1.15 Yield TT 3 Hours POH to 9467' Reverse ciculate off Cement plug. Lay 57 bbl balanced plug. Volume based on placing cement to 100' above KOP of(9100') + 30% excess G Cement .6% CFR-3,.25% LAP 17 ppg .99 Yield TT 2:45 hours POH Wait on cement a minimum of 12 hours. Hazards: Pressure: Pressure: It is possible that a limited extent 3B/3C sand connecting to gas injection well 2-12/Q-16 could be pressured up to 5150 psig @ 9560' TVDSS (emw = 10.4 ppg). Differential reservoir pressures of 1150 psi are possible between the Kekikt~k sands due to offset production and injection operations. Gas: Kekiktuk 3B & 3C sands will be above the original GCC (9850' TVDSS). The 3A4 moved GCC is estimated to be from 9900- 9960 TVD$$. Faults: 500' SW 25-50' throw. 1100' NNW 375' throw Geologic Notes No anticipated structural anomalies Kick Tolerance: 55 bbls 13.0 LOT and 10.4 MW. Close approach:2-46/Q-15 at 576'MD. and 2-50 / U-08 at 476' MD.' H2S: No potential hazardous levels of H2S are anticipated in this well. Lost Circulation: No recent loses have occurred on the MPI. Stuck Pipe: Practice Good Stuck Pipe Prevention Procedure. OCT ~19 1996 0il & Gas Cons. C0mmJss]0~ Anchorage PERMIT CHECKLIST COMPANY de~]~ redrll [] serv [] ON/O~ s~o~ ~dJ ADMINISTRATION 1. Permit fee attached ................... N 2. Lease number appropriate ............... N 3. Unique well name and number ............... Y 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 8. If deviated, is wellbore plat included ......... .~ Y X N 9. Operator only affected party .............. .fi/Y N 10. Operator has appropriate bond in force .......... Y N 11. Permit can be issued without conservationorder ..... Y N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... .~Y/ N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate for C, T, B & permafrost .... Y~ N 20. Adequate tankage or reserve pit ............. 22.21. !! ~ !:-~ ~Ss~ ~nf~ ~d.n~t been approved..~N/~--e u e o p o 23. ~ ai er~er required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate ~.~N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~--~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of E2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y presented on potential overpressure zones ..... 31. Data 32. Seismic analysis 9f shallow gas zones ......... / N //(~/3 ~.. 33. Seabed condition survey (if off-shore) ....... ~ Y N 34. Contact name/phone for weekly progress reports . . .~/.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: ~"4,~'Xcheklist rev 03/94 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 simp!ify finding information, informati~)n 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 NAME : BP EXPLORATION WELL NAME : 2-48/0-13 FIELD NAME : ENDICOTT-MPI BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22612-00 REFERENCE NO : 96113 * ALASKA COMPUTING CENTER * . ****************************** . ............................ . * ....... SCHLUMBERGER ....... * . ............................ . ****************************** COMPANY NAME : BP EXPLORATION WELL NAME : 2-48/0-13 FIELD NAME : ENDICOTT-MPI BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22612-00 REFERENCE NO : 96113 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 96/07/10 ORIGIN : FLIC REEL NAM~ : 96113 CONTINUATION # : PREVIOUS REEL : COMFiENT : B.P. EXPLORATION, ENDICOTT-MPI 2-48/0-13, API #50-029-22612-00 **** TAPE HEADER **** SERVICE NAFiE : EDIT DATE : 96/07/10 ORIGIN : FLIC TAPE NAME : 96113 CONTINUATION # : 1 PREVIOUS TAPE : COMYiENT : B.P. EXPLORATION, ENDICOTT-MPI 2-48/0-13, API #50-029-22612-00 TAPE HEADER ENDICOTT-MPI MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2-~8/0-13 500292261200 BPEXPLORATION SCHLUMBERGER WELL SERVICES lO-JUL-96 BIT RUN 1 ......... 96113 KEMP CARLYLE BIT RUN 2 BIT RUN 3 36 12N 16E 3226 2311 56.00 56. O0 15. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 10722.0 6.750 LIS Tape Vez -fication Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 3RD STRING PRODUCTION STRING This tape includes the data from SLIM1 GR logged from 22-NOV to 8-DEC 1995. The data includes the data that was interpolated at AK ICS as well as raw data. The edited data was depth shifted to the WA GR logged 8-DEC 1995. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iV-OM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INC~: 0.5000 FILE S~Y LDWG TOOL CODE .............. $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (f~F=ASUREDDEPTH) START DEPTH STOP DEPTH 9100.0 11790.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MWD 88888.0 88887.5 10922.0 10921 . 5 10885.0 10886.0 10718.0 10719.5 10559.0 10560.0 10551.0 10553 . 0 10501.5 10502.5 10473.5 10475.0 10439.0 10438.5 10403.0 10402.0 10381.0 10381.5 10361.0 10360.5 10342.0 10338.5 10309.0 10309.0 10305.0 10304.0 10283.0 10282.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10260.0 10202.5 10176.0 10164.0 10123.0 10115.0 10111.0 10106.5 10082 0 10074 0 10050 0 10041 0 10022 0 10003 0 9976 5 9954 0 9943 0 9927 5 9909 5 9887 0 9861.0 9848.0 9831.0 9813.0 9806.0 9785.0 9772.0 9754.0 9749.0 9739.0 9730.5 9696.5 9686.0 9669.0 9665.0 9660.0 9651.0 9640.0 9636.0 9615.0 9597.0 9581.0 9573.0 9564.0 9517.0 9497.5 9479.5 9446.0 9379.0 9361.0 9349.0 9308.0 9266.0 9241.0 9233.0 10259.5 10202.5 10176.0 10163.5 10120.5 10113.5 10106.5 10101.0 10077.5 10068.0 10044.5 10041.0 10022.5 10004.0 9976.5 9953.5 9939.0 9924.0 9909.5 9886.0 9860 5 9849 0 9832 0 9815 0 9806 0 9787 0 9772 5 9754 5 9750 0 9740 5 9733 5 9699 5 9686.5 9670.5 9666.0 9659.5 9652.0 9642.5 9637.5 9617.0 9599.5 9582.0 9574.0 9565.0 9518.5 9499.0 9480.0 9447.5 9379.0 93 62.5 9350.5 9308.5 9267.0 9241.5 9233.5 lO-JUL-1996 09:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 PAGE: 9220.5 9205.0 9172.0 9133.0 9112.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 9220.5 9205.0 9172.0 9133.5 9112.0 99.5 BIT RUN NO. MERGE TOP MERGE BASE This file contains the edited depth shifted data from SLIM1 GR as well as the interpolated GR and ROP. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT ll 66 51 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 NA O0 000 O0 0 1 1 1 4 68 0000000000 GRRWMWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR NA O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 PAGE: NANiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NUMB SglVlp EL~V~ CODE (HEX) GR TIE GAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11789.500 GRRW. MWD -999.250 GRIN. MWD 10.340 ROP.MWD GR.TIE -999.250 DEPT. 11000.000 GRRW. MWD -999.250 GRIN. MWD 89.125 ROP.MWD GR.TIE -999.250 DEPT. 10000.000 GRRW. MWD 117.885 GRIN. MWD 117.885 ROP.MWD GR.TIE 54.879 DEPT. 9100.000 GRRW. MWD 131.650 GRIN. MWD 131.650 ROP.MWD GR.TIE 71.940 40.800 39.400 13.479 72. 750 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUNfl3ER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 PAGE: FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9100.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWArHOLE 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 11790.0 08-DEC-95 5.5C 5.5 REAL- TIME 11836.0 9100.0 11788.0 70 13.4 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ TOOL NUMBER ........... SLIM1 013 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 9. 875 10722.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OF2~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): FLOWPRO NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: This file contains the raw SLIM1 GR data. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:19 PAGE: 7 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 28 66 1 66 0.5 FT 36 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 NA O0 000 O0 0 2 1 1 4 68 0000000000 GR RAW CPS NA O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/HRNA O0 000 O0 0 2 1 1 4 68 0000000000 ROPSMWD F/HRNA O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 INT F/HR NA O0 000 O0 0 2 1 1 4 68 0000000000 VDEPMWD FT NA O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. ROP5.MWD 11790.000 GR.RAW -999.250 GR.INT 10.340 ROP.MWD 40.800 ROPS.INT -999.250 VDEP.MWD 10065.100 DEPT. 11000.000 GR.RAW ROP5.MWD 39.200 ROP5.INT 83.400 GR.INT 83.400 ROP.MWD 39.400 VDEP.MWD 10076.301 40.300 37.500 LIS Tape Ve;~£ication Listing Schlumberger Alaska Computing Center lO-JUL-1996 09:~9 PAGE: DEPT. 10000.000 GR.RAW 117.800 GR.INT 117.800 ROP5.MWD 11.000 ROP5.INT 13.479 VDEP.MWD 9704.400 DEPT. 9100.000 GR.RAW 130.500 GR.INT 130.500 ROPS.MWD 73.300 ROPS.INT 72.750 VDEP.MWD 8848.500 ROP. MWD ROP. MWD 6.800 73.900 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/07/10 ORIGIN : FLIC TAPE NAME : 96113 CONTINUATION # : 1 PREVIOUS TAPE : COFk~NT : B.P. EXPLORATION, ENDICOTT-MPI 2-48/0-13, API #50-029-22612-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/07/10 ORIGIN : FLIC REEL NAME : 96113 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, ENDICOTT-MPI 2-48/0-13, API #50-029-22612-00 48/0 - 13 // / RECEIVED -- - . .' .. .... .... .: .:.: ..,.. _....~ :E;_.':__: ..... ;;:.--:',4;:...."., :.~ .-.... ~.- · . '~. .-..._, .~,--=-_... ::-.-::..: ~ ..... ~ .. ..- . '--~ .... - .............. . ~". . ~.. ,..~ ,. Run 1' 04 - December - 1995 6R- Marked Line Cased Hole WESTERN ATLAS Logging Services 10583 Tape Subfile 2 is typ~LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: - JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2 - 48/O - 13 500292261200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 15-DEC-95 6530.01 R. ECK J. CARLILE 36 .12N 16E 3226 2311 56.00 56.00 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 10.750 4535.0 PRODUCTION STRING 7.625 10722.0 CURVE SHIFT DATA - ALL'PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ SBT GRCH 1 1 04-DEC-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH REMARKS: Marked Line GR/SBT. 45.50 29.70 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MAGNETIC MARKS FOR DEPTH CONTROL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRC~ 8562.0 10583.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... PASS 1 (MAIN. PASS) . THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0 - 13 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 4 30 635 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 50 1014 BYTES * Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 10626.000000 8546.000000 0.500000 Tape File Depth ~ :s = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12484 datums Tape Subfile: 2 140 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10396.0 10583.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH 10402.0 10408.0 10417.5 10436.0 10438.0 10442.0 10446.0 10463.0 10468.0 10472.0 10477.5 10490.5 10494.0 10509.0 10531.5 10559.0 $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 10402.5 10408.5 10418.0 10436.5 10439.5 10442.5 10446.5 10463.5 10468.5 10472.5 10478.0 10491.5 10495.0 10509.5 10532.0 10559.5 PASS 2 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. CN WN FN COUN STAT ?MATCH. OUT : BP EXPLORATION (ALASKA) : 2 - 48/0- 13 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH GR 68 1 GAPI TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10625.000000 Tape File End Depth = 10393.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1396 datums Tape Subfile: 3 54 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8562.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10587.5 04-DEC-95 FSYS REV. J001 VER. 1.1 432 04-DEC-95 10736.0 10621.0 8580.0 10583.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 10722.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): LSND 10.40 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMALOR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT ~ ~E NORMALIZATION IN OIL ZO~ 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): .0 REMARKS: PASS 1 (MAIN PASS) . $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0- 13 : ENDICOTT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR SBT 68 1 GAPI 2 CCL SBT 68 1 3 SPD SBT 68 1 F/MN 4 TEN SBT 68 1 LB 5 TTEN SBT 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 81 310 01 1 4 4 81 150 01 1 4 4 81 636 99 1 4 4 81 635 99 1 4 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) Total Data Records: 199 1014 BYTES * Tape File Start Depth = 10626.000000 Tape File End Depth = 8546.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62411 datums Tape Subfile: 4 275 records... Minimum record length: 62 bytes Maximum record length~ 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10396.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ STOP DEPTH 10586.5 CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER 04-DEC-95 FSYS REV. J001 VER. 1.1 259 04-DEC-95 10736.0 10621.0 8580.0 10583.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 10722.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): LSND 10.40 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT k E NORMALIZATION IN OIL ZO~ 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) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0 - 13 : ENDICOTT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR SBT 68 1 GAPI 2 CCL SBT 68 1 3 SPD SBT 68 1 F/MN 4 TEN SBT 68 1 LB 5 TTEN SBT 68 1 LB 4 4 81 310 01 1 4 4 81 150 01 1 4 4 81 636 99 1 4 4 81 635 99 1 4 4 81 635 99 1 20 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 10625.000000 Tape File End Depth = 10393.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6971 datums Tape Subfile: 5 99 records... Minimum record length: 62 bytes Maximum record length, 1014 bytes Tape Subfile 6 is type: LIS 95/12/15 O1 **** REEL TRAILER **** 95/12/15 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 15 DEC 95 2:02p Elapsed execution time = 1.59 seconds. SYSTEM RETURN CODE = 0 // / Gas co'ns. Commissio~ ~!: :, i~':':'~' .:' ,-'~' "?~ ,,¢~ ,_~.:.-~',-:~:':,~;:-,., :'--~, .-. '~ )~ .'. ~ :- ~ ~_~ ::.~.:.~-':"::,-: ,;:, :. :., -,:..-.... , ;~ - ~--:L:.~.'~'_i.':':.'.~':-Z_ ,'~; :'~'~'-::.,: '- - ~ . ~ ~:~(:-:.:t~-::;:C/:-:.' ::~':~.~:::-;7::z;~':. /.~ ~ . ~f:L~:~; -~L/Z~:.?L:~.~..:'~- ~;'- ~ ..~ . : - -:~::..:::.' :;:::~_~.~.- ~ ~- -::- :...'.b .- ~ · ............. ~ / ...... t.-~'-:.':.'{~ Z__._.'; _:.t :::: Run 1' 21 - November - 1995 DIFL/ZDL/CN/GR ., 9805 10996 WESTE~ ATLAS Logging Services Tape Subfile 2 is type. ~,IS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DAT~-: JOB DATA JOB NIIMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6530.00 J. DAHL SEE REMARKS 2- 48/0- 13 PH 500292261280 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 07-DEC-95 RUN 2 RUN 3 36 12N 16E 3226 2311 56.00 56.00 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 REMARKS: 10.750 4535.0 11000.0 DIFL/ZDL/CN/GR. CIRCULATION STOPPED @ 10:00 (21-NOV-95). LOGS WITNESSED BY: P. BARKER & E. VAUGHN. MAIN PASS IS A COMPOSITE FROM FILES 3 & 5 (SPLICED IN THE FIELD AT 10470'). ALL THREE REPEAT PASSES WERE PRESENTED. TOOL COVERED WITH EXCESSIVE MUD BUILDUP WHEN BROUGHT TO THE SURFACE. CALIPER VERIFIED BEFORE AND AFTER IN CASING. AFTER VERIFICATION SHOWS TOOL STANDOFF DUE TO EXCESSIVE MUD BUILDUP ON TOOL. BARITE PRESENT IN MUD SYSTEM (3.8%), CAN EFFECT PE RESPONSE. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRL FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9805.0 10936.0 9805.0 10996.0 9805.0 10966.0 9805.0 10948.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH LL8 9852.5 9860.0 9903.5 9915.5 9916.5 9916.5 9917.5 9920.5 9924.0 9927.5 9927.5 9931.5 9932.5 9933.0 9941.0 9941.5 9942.0 9942.0 9950.5 9950.5 9950.5 9958.0 9958.5 9958.5 9976.5 9980.5 9981.0 9981.0 9981.5 9983.5 9984.0 9994.0 9996.0 9998.0 9997.0 10001.0 10001.0 10001.5 10000.5 10015.0 10018.0 10018.0 10018.5 10018.0 10021.0 10039.0 10043.5 10043.0 10044.5 10044.5 10047.5 10048.0 10048.5 10048.0 10055.5 10056.0 10056.0 10056.0 10070.0 10074.5 10077.0 10077.5 10080.5 all -- EQUIVALENT UNSHIFTED DEPTH ILD RHOB NPHI 9852.5 9860.5 9903.5 9917.5 9921.5 9924.5 9931.5 9940.5 9976.0 9949.5 9958.0 9984.5 9994.0 9996.5 9981.0 9984.0 10000.5 10015.0 10018.0 10021.0 10038.5 10056.5 10070.0 10074.0 10077.5 10047.5 10077.0 10079.5 runs merged; no case 10081.0 10083.5 10084.5 10088.5 10093.5 10098.0 10100.0 10104.5 10106.0 10108.5 10114.0 10116.5 10117.0 10117.5 10130.0 10134.5 10142.0 10152.0 10160.0 10177.0 10185.0 10187.0 10187.5 10190.0 10190.5 10194.0 10201.5 10221.0 10227.5 10233.5 10234.0 10235.5 10236.5 10243.0 10244.5 10253.5 10254.0 10259.0 10259.5 10265.0 10272.0 10274.0 10277.5 10278.0 10281.5 10284.0 10286.0 10294.0 10305.0 10305.5 10307.5 10323.5 10327.5 10330.0 10330.5 10339.5 10345.0 10345.5 10351.5 10355.5 10085.5 10097.5 10104.5 10116.5 10137.0 10144.5 10177.0 10184.5 10189.0 10228.0 10233.0 10243.5 10259.0 10277.0 10293.5 10304.5 10307.0 10327.0 10330.0 10350.0 10083.5 10099.0 10104.5 10116.5 10137.0 10144.5 10177.0 10185.5 10189.0 10232.0 10244.0 10259.0 10276.5 10293.5 10304.5 10307.0 10327.0 10330.0 10343.0 10350.0 10081.0 10098.0 10103.5 10105.5 10107.5 10112.0 10115.5 10130.5 10135.0 10142.0 10152.5 10185.5 10189.0 10193.5 10201.5 10219.5 10227.5 10232.0 10236.0 10253.0 10259.0 10273.5 10283.5 10305.0 10307.5 10326.5 10328.5 10339.5 10345.0 10355.5 10084.0 10089.0 10093.5 10106.0 10116.5 10143.0 10160.5 10187.0 10190.0 10228.0 10234.5 10236.0 10243.0 10254.5 10259.5 10264.5 10271.5 10274.0 10277.5 10281.5 10285.5 10322.5 10329.5 10345.0 10362.5 10370.0 10378.5 10391.5 10392.0 10405.5 10406.0 10417.5 10426.0 10436.0 10463.0 10481.5 10489.0 10502.5 10503.0 10509.5 10514.0 10519.5 10525.0 10525.5 10528.5 10529.0 10535.0 10536.0 10536.5 10540.0 10550.5 10552.0 10562.5 10586.5 10596.5 10609.0 10611.5 10612.0 10628.5 10649.0 10667.5 10681.0 10681.5 10683.0 10686.0 10689.0 10695.5 10697.0 10704.0 10704.5 10727.5 10747.5 10808.0 10813.5 10814.0 10819.0 10819.5 10822.5 10826.5 10829.5 10838.0 10859.0 10873.0 10887.5 1. $1.0 10378.0 10391.0 10405.5 10488.5 10502.5 10509.0 10514.0 10534.0 10550.0 10611.0 10627.0 10682.5 10685.5 10689.0 10704.5 10807.5 10813.5 10823.0 10827.5 10830.0 10838.5 10361.0 10378.0 10391.0 10406.5 10488.5 10502.5 10509.0 10514.0 10527.5 10533.5 10538.5 10550.0 10611.5 10627.0 10682.5 10685.5 10689.0 10695.5 10703.5 10747.5 10807.5 10813.5 10823.0 10829.5 10838.5 10370.0 10379.0 10392.0 10405.5 10435.5 10489.0 10523.0 10528.0 10535.0 10552.0 10562.0 10595.5 10608.0 10650.0 10667.5 10681.5 10697.0 10727.5 10814.0 10819.0 10826.0 10829.0 10837.5 10858.0 10872.0 10887.5 10406.0 10418.5 10427.0 10437.0 10463.0 10481.0 10502.5 10519.0 10524.5 10534.0 10587.0 10629.5 10682.0 10687.0 10689.5 10819.5 10826.0 10829.0 10918.0 10919 . 0 10919 . 5 10919.5 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 3 DIL 1 3 SDN 1 3 2435 1 3 $ REMARKS: 10916.0 MERGE TOP 9805.0 9805.0 9805.0 9805.0 MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 10936.0 10996.0 10966.0 10948.0 CN WN FN COUN STAT / ??MATCH1. OUT /??MATCH2.OUT / ? ?MATCH3. OUT /??MATCH4. OUT $ : BP EXPLORATION (ALASKA) : 2 - 48/0 - 13 PH : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DIL 68 1 GAPI LL8 DIL 68 1 OHM}4 ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM RT DIL 68 1 OHMM DI DIL 68 1 IN SP DIL 68 1 MV MTEM DIL 68 1 DEGF TEND DIL 68 1 LB TENS DIL 68 1 LB RHOB SDN 68 1 G/C3 DRHO SDN 68 1 G/C3 PEF SDN 68 1 BN/E CALl SDN 68 1 IN NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS NUCT 2435 68 1 CPS 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 175 1014 BYTES * 68 Tape File Start Depth = 11028.000000 Tape File End Depth = 9804.000000 Tape File Level Spacing = 6.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44083 datums Tape Subfile: 2 452 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes T~pe Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. other main pass tool strings per run. RUN NUMBER: ~ TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9804.0 10958.0 DIFL 9804.0 11018.0 ZDL 9804.0 10981.0 2435 9804.0 10964.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE KOINT KNUCKLE KOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 21-NOV-95 FSYS REV. J001 VER. 1.1 1000 21-NOV-95 1654 21-NOV-95 11000.0 10999.0 9800.0 10996.0 1500.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 1503XA 9.875 4535.0 .0 LSND 10.40 51.0 9.6 4.6 MAXIMUM RECORDED 2MPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TO~L TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0 - 13 PH : ENDICOTT : NORTH SLOPE : ALASKA 1.000 .455 .940 .000 1.350 .000 THERMAL SANDSTONE 2.65 .000 1.5 76.0 175.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 * DATA RECORD (TYPE# 0) Total Data Records: 446 974 BYTES * Tape File Start Depth = 11028.000000 Tape File End Depth = 9804.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 107735 datums Tape Subfile: 3 528 records... Minimum record length: 62 bytes Maximum record length: 974 bytes files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY Tape S~bfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10480.0 10658.0 DIFL 10480.0 10718.0 ZDL 10480.0 10681.0 2435 10480.0 10660.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE KOINT KNUCKLE KOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION 21-NOV-95 FSYS REV. J001 VER. 1.1 1000 21-NOV-95 1637 21-NOV-95 11000.0 10999.0 9800.0 10996.0 1500.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 1503XA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 9.875 4535.0 .0 LSND 10.40 51.0 9.6 4.6 175.0 MUD AT MEASUF TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0 - 13 PH : ENDICOTT : NORTH SLOPE : ALASKA 000 .455 .940 .000 1.350 .000 THERMAL SANDSTONE 2.65 .000 1.5 76.0 175.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 84 * DATA RECORD ~ PE# 0) Total Data Records: 91 974 BYTES * Tape File Start Depth = 10728.000000 Tape File End Depth = 10480.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 65930 datums Tape Subfile: 4 171 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape SUbfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10444.0 DIFL 10444.0 ZDL 10444.0 2435 10444.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 10678.0 10738.0 10701.0 10680.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE KOINT KNUCKLE KOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 21-NOV-95 FSYS REV. J001 VER. 1.1 1000 21-NOV-95 1722 21-NOV-95 11000.0 10999.0 9800.0 10996.0 1500.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 1503XA 9.875 4535.0 .0 LSND 10.40 51.0 9.6 4.6 175.0 MUD AT MEASLrff TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: - HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0- 13 PH : ENDICOTT : NORTH SLOPE : ALASKA 0O0 .455 .940 .000 1.350 .000 THERMAL SANDSTONE 2.65 .000 1.5 76.0 175.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 84 * DATA RECORD ( 'E# 0) Total Data Records: 111 974 BYTES * Tape File Start Depth = 10748.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 134510 datums Tape Subfile: 5 191 records... Minimum record length: Maximum record length: 62 bytes 974 bytes ~T~pe subfile 6 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 5 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10470.0 10673.0 DIFL 10470.0 10733.0 ZDL 10470.0 10696.0 2435 10470.0 10675.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 21-NOV-95 FSYS REV. J001 VER. 1.1 1000 21-NOV-95 1740 21-NOV-95 11000.0 10999.0 9800.0 10996.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE KOINT KNUCKLE KOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 4535.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) LSND 10.40 51.0 9.6 4.6 175.0 MUD AT MEASUA TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 48/0- 13 PH : ENDICOTT : NORTH SLOPE : ALASKA 00O .455 .940 .000 1.350 .000 THERMAL SANDSTONE 2.65 .000 1.5 76.0 175.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 84 * DATA RECORD ~ PE# 0) Total Data Records: 344 974 BYTES * Tape File Start Depth = 10743.000000 Tape File End Depth = 9799.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 149025 datums Tape Subfile: 6 424 records... Minimum record length: 62 bytes Maximum record length: 974 bytes ~'Tape subfile 7 is type: LIS 95/12/ 7 01 **** REEL TRAILER **** 95/12/ 8 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 8 DEC 95 11:32a Elapsed execution time = 4.06 seconds. SYSTEM RETURN CODE = 0
