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193-187
lq3 —/• ��- Loepp, Victoria T (DOA) From: Roby, David S (DOA) Sent: Thursday, May 10, 2018 9:54 AM To: Loepp,Victoria T(DOA); Foerster, Catherine P (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: 3M-23 Request for Spacing Exception - Follow-up Follow Up Flag: Follow up Flag Status: Flagged I can't say for certain, since my crystal ball broke and my time machine is in the shop, but it's possible that the reserves will be deferred and not lost. There's a high probability, perhaps a certainty,that the subject well will not recover as much reserves as it could if CP drilled the longer laterals that would require a spacing exception. However, it's possible that the area that would be drained by the extended laterals may be tapped in the future by another well. It's also possible that these laterals are only economically viable because the rig is already on the well and that they would not be drilled at all if they move the rig off the well to do other work while they wait on spacing exceptions. It'll be interesting to see what CP has to say. Dave Roby SCANNED )� �� (907) 793-1232 . 82018 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 Dave Roby at (907)793-1232 or dave.roby@alaska.gov. From: Loepp,Victoria T(DOA) Sent:Thursday, May 10, 2018 9:36 AM To: Foerster, Catherine P(DOA)<cathy.foerster@alaska.gov> Cc: Roby, David S(DOA)<dave.roby@alaska.gov>; Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: 3M-23 Request for Spacing Exception-Follow-up Cathy, I will talk with the CPAI engineer, but I would expect that reserves are being lost by not being able to access them wit the lateral(s)due to the spacing exception requirement. CPAI will get back with me soon on the reserve impact. Thanx, Victoria From: Foerster,Catherine P(DOA) Sent:Thursday, May 10,2018 9:28 AM To: Davies,Stephen F(DOA)<steve.davies@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: 3M-23 Request for Spacing Exception- Follow-up 1 My only question: Are they abaning reserves because going for them wou•ause a delay? From: Davies,Stephen F(DOA) Sent:Wednesday, May 09, 2018 5:54 PM To: Foerster,Catherine P(DOA)<cathy.foerster@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: 3M-23 Request for Spacing Exception- Follow-up Cathy,Victoria: Revised Permit to Drill applications for KRU 3M-23A L4 and KRU 3M-23A 14-01 were received about 3:45 PM.Spacing exceptions are no longer needed because the well branches now lie entirely within the Kuparuk River Oil Pool, more than 500'from the exterior boundary of the pool,and 1,000'from the oil-producing KRU 3M-27A L3 well branch that lies outside of the pool. Dave and I have completed our reviews of these revised applications,and I placed them on Victoria's chair. ConocoPhillips will be anxious to receive approvals tomorrow. I have a doctor's appointment in the morning, and will be in the office shortly after lunch. Please let me know if you need anything further. Thanks, Steve D. 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Foerster,Catherine P (DOA) Sent:Wednesday, May 9, 2018 3:20 PM To: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: 3M-23 Request for Spacing Exception Thank you. From: Davies,Stephen F(DOA) Sent:Wednesday, May 09,2018 3:18 PM To: French, Hollis(DOA)<hollis.french@alaska.gov>; Foerster, Catherine P(DOA)<cathy.foerster@alaska.gov>; Seamount, Dan T(DOA)<dan.seamount@alaska.gov> Cc:Colombie,Jody J (DOA)<jody.colombie@alaska.gov> Subject: FW:3M-23 Request for Spacing Exception Hollis, Cathy and Dan: FYI—AOGCC's decision emailed to CPAI regarding their request for expedited approval for a spacing exception. CPAI acknowledged receipt at 3:13 PM. Please let me know if you have any questions. Thanks, Steve D. 2 i CONFIDENTIALITY NOTICE: This e-mail age,including any attachments,contains information fre 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 forwardhng it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies,Stephen F(DOA) Sent:Wednesday, May 9, 2018 3:10 PM To: 'Kowalewski, Kasper'<Kasper.Kowalewski@conocophillips.com> Cc: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: RE: 3M-23 Request for Spacing Exception Kasper and Keith, Attached is the AOGCC's decision regarding CPAI's request. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission(AOGCC) 907-793-1224 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, se 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kowalewski, Kasper[mailto:Kasper.Kowalewski@conocophillips.com] Sent:Wednesday, May 9, 2018 8:55 AM To: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Cc: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject:3M-23 Request for Spacing Exception Importance: High Steve, For reference, here is an electronic version of the request submitted this morning. To help frame our timing constraints,our rig operations are currently on the last planned southern lateral of this well We may finish that lateral(drilled and lined)as soon as tomorrow evening. Keith will also visit with you on possibly sending a different drilling permit that has a shortened northern lateral.This may buy us an additional day for the AOGCC to make a decision on the requested spacing exception or may end up being the plan forward depending on the AOGCC decision of the request. If you have any questions, please feel free to email or call. In case you can't reach my work number, my cell is 813-29k- 8272. Kindest Regards, KASPER KOWALEWSKI I SUPERVISOR CTD DEVELOPMENT-NORTH CoP Alaska Business Unit I kasper.kowalewski@cop.com 700 G Street,Anchorage,AK 99501 I ATO-696 Office/Cell I +1.907.265.1363/+1.813.298.8272 3 • • w\�• 0 �j/ s9 THE STATE Alaska Oil and Gas ,4 o LAsKA. Conservation Commission =- 333 West Seventh Ave ue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY'* Fax: 907.276.7542 www.aogcc.alaska. ov May 9, 2018 Kasper Kowalewski Supervisor CTD Development—North North Slope Operations and Development ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510SCAND Re: Docket Number: CO-18-012 Request for Spacing Exception Waiver of 20 AAC 25.055 KRU 3M-23 (PTD# 193-187) Dear Mr. Kowalewski: By letter dated May 9, 2018, ConocoPhillips Alaska, Inc. (CPAI) requested expedited consideration of its request for a spacing exception under 20 AAC 25.055 for KRU 3M-23 (PTD# 193-187). CPAI seeks to redrill that development oil well to a new bottom-hole location and to add several horizontal well branches. On May 7, 2018, CPAI submitted Permit to Drill applications to drill and complete two additional development well branches, KRU 3M-23A L4 and KRU 3M-23A L4-01, that will be capable of producing from the Kuparuk River Oil Pool. The bottom-hole locations for these proposed well branches lie in the southeastern quarter of Section 22, T13N, R8E, Umiat Meridian(Section 22). In September 2017, CPAI drilled and completed development well branch KRU 3M-27AL3, and began regular oil production from the Kuparuk River Oil Pool. This well branch lies in the southeastern quarter of Section 22. Well spacing within the Kuparuk River Oil Pool is governed by Conservation Order No. 432D (CO 432D). Section 22 lies outside of the Affected Area of CO 432D and is therefore governed by statewide well spacing regulations. Because those regulations require notice and an opportunity for a public hearing, CPAI's request for expedited approval of an exception to 20 AAC 25.055 for well branches KRU 3M-23A L4 and KRU 3M-23A L4-01 is DENIED. Sincerely, C(4) ' Hollis S. French Chair, Commissioner • . Kasper W.Kowalewski Supervisor CTD Development-North North Slope Operations and Development ConocoPhillips Alaska, Inc. ATO-696 700 G Street AncConocoPhullups phone age,AK 9331 phone 907.265.1363 RECEVE},.. May 9, 2018 MAY 092013 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave#100 AOGCC Anchorage, Alaska, 99501-3539 RE: Request for Spacing Exception Waiver of 20 AAC 25.055 KRU 3M-23 (PTD# 193-187) Dear Commissioners: ConocoPhillips Alaska, Inc. ("ConocoPhillips") respectfully requests an exception under 20 AAC 25.055 for KRU 3M-23 (PTD# 193-187), which is outside the Affected Area of the Kuparuk River Oil Pool. We propose that the spacing for this well's laterals be governed by Rule 3 of Conservation Order No. 432D (Kuparuk River Oil Pool). We request this action on an expedited basis. Lateral coil drilling operations are underway on KRU 3M- 23. Until May 7, 2018, ConocoPhillips mistakenly believed that the laterals were entirely within the Affected Area of the Kuparuk River Oil Pool. An adjacent well (KRU 3M-27 (PTD# 195-214)) in the same section outside the Affected Area was permitted in 1995 as a Kuparuk River Oil Pool well and has been on production since that time. That history partially explains, but does not justify, our failure to more timely identify the need for a spacing exception. On May 7, 2018, Commission Staff brought to our attention that two of the planned KRU 3M-23 laterals cross into a section that is within the Kuparuk Participating Area, and within the stratigraphic extent of the Kuparuk River Oil Pool, but outside the Affected Area (areal extent) of the Kuparuk River Oil Pool. On receipt of this information, we also determined that KRU 3M-27 is outside the Affected Area. ConocoPhillips is currently executing rig operations on KRU 3M-23, and therefore respectfully requests an expedited response from the Commission, so we can complete operations and put this well on production. Doing so is consistent with the Commission's authority under AS 31.05.030 to"adopt. . . orders and take other appropriate action"for the development of oil and gas resources. Under these circumstances, a hearing under 20 AAC 25.540 can be held at a later date without prejudice. If this request for an expedited spacing exception is not granted, ConocoPhillips would not be able to complete the planned laterals and would have to move off the well without reaching the target resource. Basis for Request On May 7, 2018, Commission Staff advised that our application for permit to drill northern laterals from the 3M-23 (located on T13N, R8E Section 27) crossed into the northern area of T13N, R8E Section 22, southeast quarter(Figure 1): • . • CPAI Request for Spacing Exception Waiver of 20 AAC 25.055 for KRU 3M-23 (PTD# 193-187) Page 2 of 3 ■ ,`�A' 12 1, ■ ■ _ __..... .._-_.. _..._. ..1.- .1) 2) 26 21 ! 22 23 24 110. 4Yi 21 ?2 � ,• v _ ... i (.. 2 28 27 26 25 I 29 2a I _' 2,'. 1: `, -' i 7, _.._.• a .. 126 _ - 32 33 6 __ 5 r . ---- (146; I : 1 ■ I • I I ! ......... .-_... 147 . ...1. (10 ;11. _ . .12,. •,13... __ 14 15 I I 1 1 • 1 I 15 14 ii. I 15 1; •.i. 15 1 .., 1 l 'e- 9 1 1 �}�,[ 7 �1j _.. T12NR7E 141 ? 150 ... -i.. X24; :3 i§ f Li.,.. .21,i 2p ■ I I 1 I NOV ConocoPhi I lips ___,_„a_ T13NR8E Sec.22 Alaska Kuparuk Conservation Order Oil Pool Boundary Kuparuk Conservation Order A 28 29 L.._;KRU Kuparuk PA Boundary Oil Pool Boundary QKRU Boundary 0 0.5 1 1.5 2 2.5 3 3.5 --- 5/8/2018 Miles 'KRU Tract Figure 1. Area of focus T13N, R8E Section 22 is outside the Affected Area of the Kuparuk Oil Pool, and therefore not within the spacing rules of Rule 3 of Conservation Order No. 432D (Kuparuk River Oil Pool), which states: Rule 3 Well Spacing (Restated From 432C) There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to an external property line where ownership or landownership changes. For this reason, a spacing exception is required under 20 AAC 25.055(d). Relevant to the requirements of 20 AAC 25.055(d): (1) The planned laterals will cross into T13N, R8E Section 22. This section is included within the Kuparuk Participating Area ("KPA"), but it is not included in the Kuparuk River Oil Pool (Conservation Order No. 432D). ADL 355032, KRU Tract 125 which includes T13N, R8E, Section 22, and ADL 255024, KRU Tract 8 which includes T13N, R8E Section 27 are owned by the same parties at aligned decimals. Both tracts are held by production from the KPA. Since the owners are the same in Section 22 and in Section 27 there can be no injury to the parties by extending Rule 3 to Section 22 on an expedited basis. Nevertheless, per 20 AAC 25.055(d)(1), a notice to these parties is attached. • CPAI Request for Spacing Exception Waiver of 20 AAC 25.055 for KRU 3M-23(PTD#193-187) Page 3of3 (2) A plat, per 20 AAC 25.055(d)(2), is attached to this request. (3) An affidavit, per 20 AAC 25.055(d)(3) is attached to this request. Further Remedial Action that ConocoPhillips Will Undertake Whether or not the Commission grants this spacing exception request, as soon as practicable, ConocoPhillips will apply to expand the Affected Area of the Kuparuk River Oil Pool to include T13N, R8E Section 22, existing well KRU 3M-27, and the new laterals (if this spacing exception request is granted) for 3M-23. We also will examine our well planning processes to make improvements to avoid expedited requests like this in the future. Conclusion For the reasons set forth above, ConocoPhillips respectfully requests that the Commission approve this emergency request for waiver of the spacing requirements under regulation 20 AAC 25.055 for the KRU 3M-23 (PTD# 193-187). Please contact Kasper Kowalewski (265-1363) if you have questions or require clarification of this request. Regards, • Kasper Kowalewski Supervisor CTD Development- North • • • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) VERIFICATION OF FACTS AND Commission in the Matter of the ) AFFIDAVIT OF KASPER W. KOWALEWSKI Request of ConocoPhillips Alaska, Inc.for ) A waiver for the requirements of ) of 20 AAC 25.055(d)3 for Kuparuk River Unit ) 3M-23 Well ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Kasper W. Kowalewski, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Kasper W. Kowalewski. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am the Supervisor CTD Development—North for the well operator,ConocoPhillips Alaska, Inc. ("CPAI"). 3. I am acquainted with the facts associated with the drilling of Kuparuk River Unit 3M-23 Well. 4. I have reviewed the Request for Expedited Waiver of 20 AAC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit"1"and it correctly portrays pertinent and required data. 6. Pursuant to 20 AAC 25.055(d),CPAI,the well operator,prepared a Notice of Request for Waiver to the Provisions of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On or about May 9,2018, pursuant to 20 AAC 25.055(d)(1),CPAI sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed location of CPAI's Kuparuk River Unit 3M- 23 Well. These names and addresses are set forth on Exhibit"2"attached to CPAI's Request for Expedited Waiver of the Provisions of 20 AAC 25.055 dated May 9, 2018. Subscribed and sworn to this 9th day of May,2018. j Kasper W. Kowalewski STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 9th day of Ma ,2018, by Kasper W. Kowalewski. ,A1'):4 ..4 �,, Notary Public, Sta e of Alaska ..••...... III I&?/ ?� -0 .' ..•����� My Commission Expires: PO3LIC # r. :bra ,�® . -,14.0v O F: ....et. • • V m ' 9 r N M V cR Z q , 51 • A' pamd 5)›F ''' E aVm VX o o � o o o W BL-Inde .:�\ F. 3M' 9L)WSM 0 c 92'WE o 'o i 4 4-' y ° N,______4_, 0., 2 03 m ilti Ua O N / 2 Y m R N 1- -' S M i6 > > > a ` a 03 ee�L IVE, 1- Y Y Y Y U U :''ll O o 5 y 1 n ! ` . ■ „''''4, °,,Z-23- >i � � n::‘ � dm R ° N O 6- . C C E E m y m pa c c n o t a ,LC J J Li N V (1] N N N N m = ry - N M Q d - d ', N 3 J M `w I M I o c-1 � C y .. R ,x34 -C 7B co d x r/ \ Lu d' Q..,d. \ 2 CJd emoe J R Qw ;:i:1." MNQaNMQ _ M H o<='"2Na ' � x a'aaxg � N MMMQ M Qm�X Jh .. C o Q C M C N R C n. = M d. L e z -4111( Qaw Y .4!°,-', , ,F . y7„ Q 7o Nf Ya. N food no-o.o>rnaednm QQ Q y a = M z Ec N 7 3 G UmUK \Li. d / O MQ' u CD 0 O o a Y 0 O Q- x g w • Exhibit 2 Notice of Request for Expedited Waiver of the provisions of 20 AAC 25.055 To: Owners, Landowners, and Operators shown below: Be advised that ConocoPhillips Alaska, Inc. on its own behalf and on behalf of Kuparuk River Unit Working Interest Owners has filed with the Alaska Oil and Gas Conservation Commission a request for expedited waiver of the provisions of 20 AAC 25.055 relating to well spacing exceptions for the drilling of the 3M-23 Well. Owners, Landowners, and Operators: Operator: ConocoPhillips Alaska, Inc. 700 G. Street Anchorage,AK 99501 Attention: Erik Keskula Owners: BP Exploration (Alaska) Inc. 900 E. Benson Boulevard Anchorage, AK 995008 Attention: Mr.John Dittrich Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston,TX 77002 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Land Owner: State of Alaska Department of Natural Resources, Division of Oil and Gas 550 West Seventh Ave., Suite 800 Anchorage, AK 99501 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF ) Conservation Order No. 432D CONOCOPHILLIPS ALASKA, INC. ) to establish an allowable gas offtake ) Kuparuk River Field rate and THE MOTION OF THE ) Kuparuk River Unit ALASKA OIL AND GAS ) Milne Point Unit CONSERVATION COMMISSION ) Kuparuk River Oil Pool to revise Rule 12 of Conservation ) Order 432C ) March 20, 2008 IT APPEARING THAT: I. By application dated November 7, 2007, and received by the Alaska Oil and Gas Conservation Commission (Commission) on November 9, 2007, ConocoPhillips Alaska, Inc. (CPAI), as a working interest owner and operator of the Kuparuk River Unit (KRU), requested an order establishing an allowable gas offtake rate for the Kuparuk River Oil Pool (KROP). 2. On its own motion, the Commission proposed revisions to Rule 12 (Administrative Actions) of Conservation Order (CO) 432C to make this rule consistent with the rules governing administrative actions that apply to other pools in the KRU and elsewhere in the state. 3. On November 16, 2007, the Commission issued Administrative Approval CO 432C.002, authorizing CPAI to conduct a pilot gas offtake project for up to 90 days so that data about the potential effects of a gas offtake project could be gathered. 4. On November 19, 2007, notice of a public hearing was published in the ANCHORAGE DAILY NEWS, 5. On December 10, 2007, an individual objected to CPAI's request and a requested that the Commission hold the public hearing. 6. On January 8, 2008, at 9 a.m., a public hearing was held in the Commission's offices at 333 West 7th Ave, Suite 100, Anchorage, Alaska. 7. At the public hearing, the Commission left the record open until the close of business on February 8, 2008. 8. On February 13, 2008, the Commission issued Administrative Approval CO 432C.003, extending the pilot gas offtake project for 30 days to allow the Commission to complete its review of the data CPAI submitted and testimony and comments provided on CPAI's application and the Commission's motion. •Conservation Order 432D Page 2 March 20, 2008 9. On February 21, 2008, the Commission sent CPAI a letter requesting clarification regarding statements CPAI made at and after the hearing regarding mitigation measures. 10. On March 12, 2008, CPAI responded to the Commission's letter and followed up with additional clarification regarding mitigation. FINDINGS: 1. Routinely, there are small KRU gas sales to the Kuparuk Transportation Company, and, occasionally, there are small sales to other entities, including the United States Air Force. 2. On November 7, 2007, CPAI, as a working interest owner, notified the Commission that it had entered into an agreement to sell up to 3 million cubic feet of gas per day (MMCFPD) to Pioneer Natural Resources Alaska, Inc. CPAI, as the KRU operator, requests an order allowing for a KROP gas offtake rate of up to 5 MMCFPD. 4. One individual provided written comments and testimony at the public hearing. The commenter opposes CPAI's request on the belief that the requested gas offtake would diminish the ultimate recovery of KROP hydrocarbons. 5. At the January 8, 2008, hearing, CPAI testified that it would undertake mitigation measures to offset the potential harm in oil recovery associated with the requested allowable gas offtake rate. In its March 12, 2008, letter, CPAI clarified that, because of water transmission difficulties, 100 percent immediate voidage replacement is not possible, and, therefore, CPAI would not undertake additional mitigation measures, but would continue using injection gas in the enhanced recovery patterns where it will provide the greatest benefit in terms of increased oil recovery. 6. As required by Administrative Approvals CO 432C.002 and CO 432C.003, CPAI has submitted weekly reports identifying injection rates, pressures, and temperatures for representative KROP wells. 7. As written, Rule 12 (Administrative Actions) of CO 432C is inconsistent with the administrative actions rules in other KRU and Milne Point Unit orders. Moreover, as written, the Commission could be prevented from timely acting on a request from the operator or on its own motion to administratively waive or amend the requirements of the CO even where notice and public hearing are not required and such action would not promote waste or jeopardize correlative rights, would be based on sound engineering and geoscience principles, and would not result in an increased risk of fluid movement into freshwater. 8. For 2007 the cumulative production from the KROP was approximately 43 million stock tank barrels (MMSTB) of oil, 185 MMSTB of water, and 95 billion standard cubic feet (BSCF) of gas. Cumulative injection for 2007 was approximately 204 MMSTB of water and 81 BSCF of gas. At reservoir conditions the cumulative production and injection was approximately 305 million reservoir barrels (MMRVB) and 272 MMRVB respectively. The requested maximum gas offtake allowable rate of 5 MMCFPD would equate to approximately 1.2 MMRVB per year. Therefore, the requested gas offtake would amount to S • � Conservation Order 4321) Page 3 March 20, 2008 approximately 0.39% of the total yearly reservoir production and approximately 0.44% of the yearly injection volume in reservoir barrels. Since such volumes are smaller than the margin of error for reservoir simulators the effects of the proposed offtake on ultimate recovery can not be determined. CONCLUSIONS: 1. Given CPAI's current reservoir management practices, a 5 MMCFPD gas offtake rate is a de minimis amount that will not meaningfully impact ultimate total oil production from the KROP. 2. While the Commission agrees that additional mitigation measures are not now necessary, there is a need for continued careful surveillance related specifically to the gas offtake allowable to enable the Commission to confirm that a sustained 5 MMCFPD gas offtake rate will not meaningfully impact the ultimate recovery of KROP oil; if this is not confirmed, the surveillance will enable the Commission to act quickly to determine what remedial actions to order. NOW, THEREFORE, IT IS ORDERED: This Conservation Order supersedes CO 432C, dated November 2, 2004. The findings, conclusions and administrative record for CO 432C are incorporated in this order. In addition to the requirements under 20 AAC 25 (to the extent such requirements are not superseded by these rules or other conservation orders), the following rules shall apply to the Kuparuk River Oil Pool within the affected area as described in Appendix A, attached hereto and made a part hereof: Rule 1. Name of Field (Restated From 432C) The name of the field shall be the Kuparuk River Field. (Source CO 173) Rule 2. Definition of Pool (Restated From 432C) The name of the pool in the Kuparuk River Field shall be the Kuparuk River Oil Pool and is defined as the accumulation of oil that is common to and correlates with the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 well between the depths of 6,474 and 6,880 feet. (Source CO 173) Rule 3 Well Spacing (Restated From 4320) There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to an external property line where ownership or landownership changes. Rule 4. Casing and Cementing Requirements (Restated From 432C) a. Casing and cementing requirements are as specified in 20 AAC 25.030, CASING AND CEMENTING, except as modified below. (Source CO 173) b. For proper anchorage and to prevent an uncontrolled flow, a conductor casing shall be set at least 75 feet below the surface and sufficient cement shall be used to fill the annulus behind •Conservation Order 432D Page 4 March 20, 2008 the pipe to the surface. (Source CO 173) c. For proper anchorage, to prevent an uncontrolled flow, and to protect the well from the effects of permafrost thaw-subsidence and freeze back, a string of surface casing shall be set at least 500 measured feet below the base of the permafrost section but not below 2700 feet true vertical depth. Sufficient cement shall be used to fill the annulus behind the casing to the surface. (Source CO 173, CO 193, 203, 209 & 229 -authorized depths of surface casing for various Drill Sites are detailed on following table) 1) Drill Pad 2Z Kuparuk River oil pool wells may be drilled to a maximum depth of 3250 feet true vertical depth before surface casing is set so long as drilling fluid densities are monitored and maintained at 10.0 pounds per gallon. (Source CO 190, modified by AA 190.01 - 190.15) 2) Drill Pad 2X and 2C Kuparuk River oil pool wells may be drilled to a maximum depth of 2975 feet true vertical depth before surface casing is set. (Source CO 190, modified by AA 190.01 - 190.15) 3) In the event that geologic conditions are not as anticipated, the Commission may change the maximum depth for setting surface casing by administrative action, provided a request, in writing, is timely submitted. (Source CO 190) Authorized Surface Casing AA No. Drill Sites Depth Pursuant to Rule 4(c) CO 190 AA 190.1 1F 3350' TVD AA 190.4 2Z 3450' TVD AA 190.6 2K 3000' TVD AA 190.7 2K 3452' TVD AA 190.10 3G 3500' TVD AA 190.11 1A 3900' TVD AA 190.12 3R 4200' TVD AA 190.13 1H 4100' TVD AA 190.14 1H 4400"IND AA 190.15 1Y 4400' TVD Authorized Surface Casing Conservation Drill Sites Depth Pursuant to CO 173 Order Rule 4(e) and 20 AAC 25.035(b) CO 193 2A, 2B, 2D, 2F, 2G, 2H, 2V 3200' TVD CO 203 1 L, I Q, 1R, 2E, 2U, 2W, 3B, 3800' TVD 3C CO 209 1R, 2A, 2H, 2T, 3A, 3B, 3C, 4150' TVD 3F, 3J, 3K, 3M, 3N, 30, 3Q CO 229 2M, 3H 3700' TVD d. The surface casing, including connections, shall have minimum post-yield strain properties of 0.9% in tension and 1.26%in compression. (Source CO 173) •Conservation Order 432D Page 5 March 20, 2008 1) The only types and grades of casing, with threaded connections, that have been shown to meet the requirements in (d) above and have been approved for use as surface casing are the following: (A) 13 3/8 inch, 72 pounds/foot, L-80, Buttress; (B) 13-3/8 inch, 72 pounds/foot,N-80, Buttress; (C) 10-3/4 inch, 45.5 pounds/foot, K-55, Buttress; 2) The Commission may approve other types and grades of surface casing upon a showing that the proposed casing and connection can meet the post-yield strain requirements in (d) above. This evidence shall consist of one of the following: (A) Full scale tensile and compressive tests, (B) Finite element model studies; or, (C) Other types of axial strain data acceptable to the Commission. e. Other means for maintaining the integrity of the well from the effects of permafrost thaw- subsidence and freeze back may be approved by the Commission upon application. (Source CO 173) f. The Commission may approve alternative completion methods (to 20 AAC 25.030(b)(4) and (5)) upon application and presentation of data that shows the alternatives are based on accepted engineering principles. Such alternative designs may include: (Source CO 173) 1) Slotted liners, wire wrapped screen liners, or combinations thereof, landed inside of open hole and may be gravel packed; 2) Open hole completions provided that the casing is set not more than 200 feet above the productive zone. Rule 5. Automatic Shut-In Equipment(Restated From 432C) a. Each well shall be equipped with a Commission approved fail-safe automatic surface safety valve system (SVS) capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an over pressure of equipment may occur. (Source CO 348) b. The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. If the SVS cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. (Source CO 348) 1) Wells with a deactivated SVS shall be identified by a sign on the wellhead stating that the SVS has been deactivated and the date it was deactivated. (Source CO 348) 2) A list of wells with the SVS deactivated, the dates and reasons for deactivating, and the estimated re-activation dates must be maintained current and available for Commission inspection on request. (Source CO 348) c. A representative of the Commission shall be allowed to witness operation and performance tests at intervals and times as prescribed by the Commission to confirm that the SVS is in proper working condition. (Source CO 348) Conservation Order 432D Page 6 March 20,2008 Rule 6. Safety Flares (Restated From 432C) Repealed by 20 AAC 25.235. Rule 7. Gas-Oil Ratio Tests (Restated From 432C) Repealed by Conservation Order 262, dated October 23, 1990. Rule 8. Pressure Surveys (Restated From 432C) a. A bottom-hole pressure survey shall be taken on each well prior to initial sustained production. (Source CO 230) b. The operator shall obtain pressure surveys as needed to effectively manage hydrocarbon recovery processes subject to an annual plan outlined in (d) of this rule. (Source CO 432) c. Bottom-hole pressures obtained by a static buildup pressure survey, a 24-hour shut-in instantaneous test, a multiple flow rate test or an injection fall-off test will be acceptable. Calculation of bottom-hole pressures from surface data will be permitted for water injection wells. (Source CO 230) d. Data from the surveys required in this rule shall be filed with the Commission by April 1 of the subsequent year in which the surveys are conducted. Along with the survey submittal, the operator will provide a proposed survey plan for the upcoming year. Reservoir Pressure Report, Form 10-412, shall be utilized for all surveys with attachments for complete additional data. Data submitted shall include, but are not limited to, rate, pressure, time, depths, fluid gradient, temperature, and other well conditions necessary for complete analysis of each survey being conducted. The pool pressure datum plane shall he 6,200 feet subsea. (Source CO 230, 432) e. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (d) of this rule. (Source CO 230) fi Upon application by the operator, the Commission in its discretion may administratively approve exceptions to this rule. (Source CO 230) Rule 9. Productivity Profiles (Restated From 432C) a. During the first year of production, a production survey shall be run in each well that has multiple sand intervals open to the well bore. (Source CO 173) b. Subsequent surveys shall be run in wells that exhibit uncharacteristic changes in performance. Subsequent surveys shall also be required in wells which have had remedial work performed to change the production profile unless the remedial work results in only one sand interval being open to the well bore. (Source CO 173, 276) c. All completed production surveys taken during a calendar year be filed with the Commission by April 1 of the subsequent year. The Commission may request data be provided in advance of an annual submittal if required. (Source CO 173, 432) d. By administrative order, the Commission shall specify additional surveys should it be determined that the surveys submitted under(a) and (b) are inadequate. (Source CO 173) Conservation Order 432D • Page 7 March 20, 2008 Rule 10. Production Well Tests (Restated From 432C) a. A well test must be performed on each active producing well at least once every 30 days. b. Twinned production wells commingled through the same surface flowline, must be tested at least once every 30 days as a combined production stream and the individual wells must be tested separately at least once every six months or more often if the combined well test indicates uncharacteristic performance. Rule 11. Sustained Casing Pressures (Restated From 432C) a. The operator shall conduct and document a pressure test of tubulars and completion equipment in each development well at the time of installation or replacement that is sufficient to demonstrate that planned well operations will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. b. The operator shall monitor each development well daily to check for sustained pressure, except if prevented by extreme weather conditions, emergency situations, or similar unavoidable circumstances. Monitoring results shall be made available for AOGCC inspection. c. The operator shall notify the AOGCC within three working days after the operator identifies a well as having (1) sustained inner annulus pressure that exceeds 2000 psig or (2) sustained outer annulus pressure that exceeds 1000 psig. d. The AOGCC may require the operator to submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action or increased surveillance for any development well having sustained pressure that exceeds a limit set out in paragraph c of this rule. The AOGCC may approve the operator's proposal or may require other corrective action or surveillance. The AOGCC may require that corrective action be verified by mechanical integrity testing or other AOGCC approved diagnostic tests. The operator shall give AOGCC sufficient notice of the testing schedule to allow AOGCC to witness the tests. e. If the operator identifies sustained pressure in the inner annulus of a development well that exceeds 45% of the burst pressure rating of the well's production casing for inner annulus pressure, or sustained pressure in the outer annulus that exceeds 45% of the burst pressure rating of the well's surface casing for outer annulus pressure, the operator shall notify the AOGCC within three working days and take corrective action. Unless well conditions require the operator to take emergency corrective action before AOGCC approval can be obtained, the operator shall submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action. The AOGCC may approve the operator's proposal or may require other corrective action. The AOGCC may also require that corrective action be verified by mechanical integrity testing or other AOGCC approved diagnostic tests. The operator shall give AOGCC sufficient notice of the testing schedule to allow AOGCC to witness the tests. f Except as otherwise approved by the AOGCC under paragraph (d) or (e) of these rules, before a shut-in well is placed in service, any annulus pressure must be relieved to a S • Conservation Order 432D Page 8 March 20, 2008 sufficient degree (1) that the inner annulus pressure at operating temperature will be below 2000 psig and (2) that the outer annulus pressure at operating temperature will be below 1000 psig. However, a well that is subject to paragraph (c), but not paragraph (e), of these rules may reach an annulus pressure at operating temperature that is described in the operator's notification to the AOGCC under paragraph (c), unless the AOGCC prescribes a different limit. g. For purposes of these rules, "inner annulus" means the space in a well between tubing and production casing; "outer annulus" means the space in a well between production casing and surface casing; "sustained pressure" means pressure that (1) is measurable at the casing head of an annulus, (2) is not caused solely by temperature fluctuations, and (3) is not pressure that has been applied intentionally. Rule 12 Administrative Actions (Revised This Order) Upon proper application, or its own motion, and unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated herein or administratively amend this order as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. Rule 13 Allowable Gas Offtake (This Order) Gas offtake for the Kuparuk River Oil Pool is authorized with the following conditions: 1) The maximum annual average gas offtake rate is 5 million standard cubic feet of gas per day; and 2) In the annual surveillance report, the volume of gas offtake, in units of standard cubic feet and reservoir barrels, must be reported on a monthly basis. • • Conservation Order 432D Page 9 March 20,2008 Annual average gas offtake rate means the daily average rate, calculated by dividing the total volume of gas delivered in a calendar year by the number of days in the year. However, in the first year that gas offtake is initiated under this rule, the annual average gas offtake rate shall be determined by dividing the total volume of gas delivered in the calendar year by the number of days that remained in that year as of the initial delivery. ENTERED at Anchorage,Alaska, and dated March 20, 2008. 4 , Daniel T. Seal, u t, Jr., Chair Alaska Oil a r d As Conservation Commission Jo or , Com sio .yt. Alaska 0 .nd Gas Conservation Commission `1 • "ti:0r0, athy P. Fierster, Commissioner Alaska Oil and Gas Conservation Commission RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown,a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. The application for reconsideration must set out the respect in which the order or decision is be- lieved to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. The failure to act on it within the 10-day period is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FI- NAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision denying reconsidera- tion, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the commission by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included, unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Conservation Order No. 173 Page 5 NOW THEREFORE IT IS FURTHER ORDERED THAT the rules hereinafter set forth apply to the following described area: T 9 N, R 6 E, U.M. T 11 N, R 8 E, U.M. Secs. 1,2,11,12,13 and 14. ALL T 9 N, R 7 E, U.M. T 11 N, R 9 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, ALL 10,11,12,13,14,15, 16,17 and 18. T 11 N, R 10 E, U.M. ALL T 9 N, R 8 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, T 11 N, R 11 E, U.M. 10,11,12,13,14,15, Secs. 3, 4,5,6,7, 8,9,10 ,11, 16,17 and 18. 14,15,16,17,18,19,20, 21,22,23,24,25,26,27, T 9 N, R 9 E, U.M. 28,29,30,31,32,33,34, Secs. 1,2,3,4,5,6,7,8,9, 35 and 36. 10,11,12,15,16,17 and 18. T 12 N, R 7 E, U.M. Secs. 25,26,35 and 36. T 9 N, R 10 E, U.M. T 12 N, R 8 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, ALL 10,11 and 12. T 12 N, R 9 E, U.M. T 10 N, R 6 E, U.M. ALL Secs. 1,2,3,4,9,10,11,12,13, 14,15,16,21,22,23,24, T 12 N, R 10 E, U.M. 25,26, 35 and 36. ALL T 10 N, R 7 E, U.M. T 12 N, R 11 E, U.M. ALL Secs. 3,4,5,6,7, 8,18,19,20, 29,30,31,32 and 33. T 10 N, R 8 E, U.M. ALL T 10 N, R 9 E, U.M. T 13 N, R $ E, U.M. ALL Secs. 13,14,23,2 25,26, 27,28 , 4,35 and T 10 N, R 10 E, U.M. ALL T 13 N, R 9 E, U.M. T 10 N, R 11 E, U.M. ALL Secs. 5,6,7,8,17,18,19 and 20. T 13 N, R 10 E, U.M. ALL T 11 N, R 6 E, U.M. Secs. 25,26, 35 and 36. T 13 N, R 11 E, U.M. Secs. 7, 8,16,17,18,19,20,21, T 11 N, R 7 E, U.M. 28,29,30,31,32 and 33. Secs. 1,2,3,4,9,10,11,12, 13, 14,15,16,17,18,19, 20,21,22,23,24,25,26, 27, 28,29,30,31,32, 33, 34,35 and 36. AGO 10023346 Ai0 11111„, Conservation Order N•49 Page 3 December 16, 1994 2. The KROP has been shown to extend into the NWMP. The northern extent of the pool has not been determined. 3. The physical attributes of the KROP in the NWMP are very similar to the previously defined part of the pool. 4. Development of the KROP in the NWMP can be conducted under existing KROP rules without causing waste or jeopardizing correlative rights. 5. Expansion of the KROP area into the NWMPU is warranted. NOW, THEREFORE IT IS ORDERED THAT the Kuparuk River oil pool rules area described in Conservation Order No. 173 is repealed and hereinafter pertains to the following described area: T9N, R6E, U.M. T11N, R10E, U.M. SECS. 1,2,11,12,13,and 14. ALL T9N, R7E, U.M. T11N, R11E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 3,4,5,6,7,8,9,10,11,14,15,16,17,18, 14,15,16,17 and 18. 19,20,21,22,23,24,25,26,27,28,29,30,31,32, 33,34,35 and 36. T9N, R8E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, T12N, R7E, U.M. 14,15,16,17, and 18. SECS. 25,26,35 and 36. T9N, R9E, U.M. T12N, R8E, U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,15,16,17 ALL and 18. T12N R9E U.M. T9N, R10E U.M. ALL SECS. 1,2,3,4,5,6,7,8,9,10,11 and 12. T12N, R10E, U.M. T10N, R6E, U.M. ALL SECS. 1,2,3,4,9,10,11,12,13,14,15,16,21, 22,23,24,25,26,35 and 36. T12N, R11E, U.M. SECS. 3,4,5,6,7,8,18,19,20,29,30,31,32 and T1ON, R7E, U.M. 33. ALL. T13N, RBE, U.M. TION, RBE, U.M. SECS. 13,14,23,24,25,26,27,28,33,34,35 and ALL. 36. 7/ • • Conservation Order 432B Page 6 December 12,2002 T9N,R6E,U.M. T11N,R10E,U.M. SECS. 1,2,11,12,13,and 14. ALL T9N,R7E,U.M. Ti 1N,RI lE U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 5,6,7,8,16,17,18,19,20,21,22,23,26,27,28, 14,15,16,17 and 18. 29,30,31,32,33,34,35 and 36. T9N,R8E U.M. TUN,R7E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 1,2,11,12,13,14,15,16,21,22,23,24,25,26,35 14,15,16,17,and 18. and 36. T9N,R9E,U.M. T12N,R8E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,15, ALL 16,17and 18. T12N R9E U.M. T9N,R l OE U.M. ALL SECS. 1,2,3,4,5,6,7,8,9,10,11 and 12. T12N,R10E,U.M. T10N,R6E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,14,15,16,17, SECS. 1,2,3,4,9,10,11,12,13,14,15,16,21, 18,19,20,21,22,23,25,26,27,28,29,30,31,32,33, 22,23,24,25,26,35 and 36. 34,35 and 36. T1ON,R7E,U.M. T12N,RI 1 E,U.M. ALL. ,4,5,6,7,8,and 31. T1ON,R8E,U.M. T13N,R8E,U.M. ALL. SECS. 13,14,23,24 ,26,27,28,33,34,35 and 36. T1ON,R9E,U.M. • ,U.M. ALL. ALL T10N,R10E.U.M. T13N,R10E,U.M. ALL ALL TION,RI 1E,U.M. T13N,RI 1E,U.M. SECS. 5,6,7,8,17,18,19 and 20. SECS. 7,8,16,17,18,19,20,21,28,29,30, 31,32,and 33. T1 IN,R6E,U.M. SECS. 25,26,35 and 36. T14N R9E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13,14, T1 IN,R7E,U.M. 15,16,17,18,20,21,22,23,24,25,26,27, SECS. 1,2,3,4,9,10,11,12,13,14,15,16, 28,29,32,33,34,35 and 36. 17,18,19,20,21,22,23,24,25,26,27,28,29, 30,31,32,33,34,35 and 36. T14N,R10E U.M. SECS. 15,16,17,18,19,20,21,22,27,28,29, T1 IN,R8E,U.M. 30,31,32,33,34 and 35 ALL T15N,R9E U.M. T1 IN,R9E,U.M. State lands within SECS. 25,26,27,31, ALL 32,33,34,35,and 36. • • Conservation Order 432C Page 4 November 2,2004 Umiat Meridian T9N,R6E,U.M. T11N,R10E,U.M. SECS. 1,2,11,12,13,and 14. ALL T9N,R7E,U.M. T11N,R11E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 5,6,7,8,16,17,18,19,20,21,22,23,26,27,28, 14,15,16,17 and 18. 29,30,31, 32,33,34,35 and 36. T9N,R8E U.M. T12N,R7E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 1,2,11,12,13,14,15,16,21,22,23,24,25,26,35 14,15,16,17, and 18. and 36. T9N,R9E,U.M. T12N,R8E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,15, ALL 16,17and 18. T12N R9E U.M. T9N,R10E U.M. ALL SECS. 1,2,3,4,5,6,7,8,9,10,11 and 12. T12N,R10E,U.M. T1ON,R6E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,14,15,16,17, SECS. 1,2,3,4,9,10,11,12,13,14,15,16,21, 18,19,20,21,22,23,25,26,27,28,29,30,31,32,33, 22,23,24,25,26,35 and 36. 34,35 and 36. T10N,R7E,U.M. T12N,R11E,U.M. ALL. SECS: 1,2,3,4,5,6,7,8,9,10,11,12 and 31. T10N,R8E,U.M. T13N,R8E,U.M. ALL. SECS. 13,14,23,24,25,26 ,28,33,34,35 and 36. T1ON,R9E,U.M. , = : ALL. ALL TION,R10E,U.M. T13N,R10E,U.M. ALL ALL T10N,R11E,U.M. T13N,R11E,U.M. SECS. 5,6,7,8,17,18,19 and 20. SECS. 7,8,16,17,18,19,20,21,27, 28,29,30, 31,32,33,and 34. T11N,R6E,U.M. SECS. 25,26,35 and 36. T14N R9E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13,14, T11N,R7E,U.M. 15,16,17,18,20,21,22,23,24,25,26,27, SECS. 1,2,3,4,9,10,11,12,13,14,15,16, 28,29,32,33,34,35 and 36. 17,18,19,20,21,22,23,24,25,26,27,28,29, 30,31,32,33,34,35 and 36. T14N,R10E U.M. SECS. 15,16,17,18,19,20,21,22,27,28,29, T11N,R8E,U.M. 30,31,32,33,34 and 35 ALL T 15N,R9E U.M. T11N,R9E,U.M. State lands within SECS. 25,26,27,31, ALL 32,33,34,35, and 36. • Conservation Order 432D • Page 10 March 20, 2008 Appendix A to Conservation Order 4321) Kuparuk River Oil Pool Affected Area Umiat Meridian T9N, R6E, U.M. T1I IN,R1OF.,U.M. SECS. 1,2,11,12,13,and 14. ALL T9N,R7E, U.M. T11N, R11E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,1 1,12,13, SECS. 5,6,7,8,16,17,18,19,20,21,22,23,26,27,28, 14,15,16,17 and 18. 29,30,31,32,33,34,35 and 36. T9N,R8E U.M. T I2N,R7E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, SECS. 1,2,11,12,13,14,15,16,21,22,23,24,25,26,35 and 14,15,16,17,and 18. 36. T9N,R9E, U.M. T12N,R8E, U.M. SECS. 1,2,3,4,5,6,7,8,9,10,1 1,12,15, ALL 16,17and 18. T12N R9E U.M. T9N,RIDE U.M. ALL SECS. 1,2,3,4,5,6,7,8,9,10,11 and 12. T12N,R10E, U_M; TION,R6E,U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,14,15,16,17, SECS. 1,2,3,4,9,10,1 1,12,13,14,15,16,21, 18,19,20,21,22,23,25,26,27,28,29,30,31,32,33, 22,23,24,25,26,35 and 36. 34,35 and 36. TION,R7E,U.M. T12N,RI 1E, U.M. ALL. SECS. 1,2,3,4,5,6,7,8,9,10,11,12 and 31. TION.R8E,U.M. T13N,R8E,U.M. ALL. SECS. 13,14,23,24,25,26,27,28,33,34,35 and 36. TION,R9E,U.M. ALL, ALL TION,RIOE,U.M. T13N,R1OE,U.M. ALL ALL T1QN, RI 1E,U.M. T13N,RI1E,U.M. SECS. 5,6,7,8,17,18,19 and 20. SECS. 7,8,16,17,18,19,20,21,27,28,29,30, 31,32,33,and 34. TI IN,R6E,U.M. SECS. 25,26,35 and 36. T14N R9E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13,14, TI IN, R7E,U.M, 15,16,17,18,20,21,22,23,24,25,26,27, SECS. 1,2,3,4,9,10,11,12,13,14,15,16, 28,29,32,33,34,35 and 36. 17,18,19,20,21,22,23,24,25,26,27,28,29, 30,31,32,33,34,35 and 36. TI4N,R1OE U.M. SECS. 15,16,17,18,19,20,21,22,27,28,29, TI IN,R8E,U.M. 30,31,32,33,34 and 35 ALL T15N, R9E U.M. TI IN, R9E, U.M. State lands within SECS. 25,26,27,31, ALL 32,33,34,35,and 36. • • ck 1 3 1 11j Q "Ct' G ¢ I 1 ...... _,........, c� --kI < _. Vi ca N NN fl A l 2 Jr 0,-) con ,X ..r-i-1 05 ,p„ , ,r * ' > C 40 J M I N r:. N ti al. eall .1 ilk t (` .' C7 ' O 0 M _1 J co N. N-- J N N CO 2 2 N M CO co S 193187 WELL LOG 2 TRANSMITTAL 9 1 8 6 29 187 PROACTIVE DiAINOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road MAR 2 9 2018 Suite C Anchorage, AK 99518 AOGCC Fax: (907) 245-8952 %W ) JP' 2 9 1 8 6 1) Caliper Report 18-Mar-18 3M-23 1 Report /CD 50-029-22426-00 2 9 1 8 7 2) Jewelry Log 18-Mar-18 3M-23 Color Log /CD 50-029-22426-00 L__4v,11P, • Signed : Date : (,ate Print Name: / 1;�I� �' 1.. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D;\AchivesWasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx i 1 9 31 87 4102918 6 Memory Multi-Finger Caliper CIO Log Results Summary Company: ConocoPhillips Alaska, LLC. Well: 3M-23 Log Date: March 18, 2018 Field: Kuparuk Log No.: 16567 State: Alaska Run No.: 4 API No. 50-029-22426-00 Pipe Description: 3.5 inch 9.3 lb. L-80 8rd Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 12,283 Ft.(MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of the Comm DS Nipple at 12,267.2 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good condition with respect to internal corrosive and mechanical damage,with no significant wall penetration or areas of cross-sectional wall loss recorded. The caliper recordings indicate the presence of light to moderate deposits throughout the majority of the 3.5 inch tubing logged, increasing in severity with depth from-1,750 to 12,283 feet(end of tubing), restricting the I.D.to 2.62 inches in Joint 390.2 at 12,268 feet. A graph illustrating minimum recorded diameters on a joint-by-joint basis across the 3.5 inch tubing logged is included in this report. The presence of the deposits may mask additional damage to the tubing. This is the fourth time a PDS caliper has been run in this well and the first time this 3.5 inch tubing string has been logged since the RWO (2013). MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 16%)are recorded throughout the 3.5 inch tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss(>9%)are recorded throughout the 3.5 inch tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : Description Minsmum i.D. Jou Deposits on DS Nipple 2.62 in. 390.2 12,268 Ft. (MD) Deposits on Locator 2.63 in. 390.5 12,283 Ft. (MD) Deposits 2.64 in. 390.4 12,278 Ft. (MD) Deposits 2.69 in. 390.1 12,267 Ft. (MD) Deposits 2.70 in. 390 12,252 Ft. (MD) D. Henley, B. DiMatteo HY. Yang J. Fama F ielri E:n}ineer(s) Analyst(s) ik K-:••st ,.,'_ ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (3.5'-12,283.3') Well: 3M-23 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: March 18,2018 Approx.Tool Deviation ■ Approx. Borehole Profile 1 7 1,554 100 3,111 GLM 1 150 4,681 0 E200 6,230 — Z - GLM 2 'o 250 7,860 300 9,418 350 10,981 390.5 12,283 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=390.5 • • ill Minimum Diameter Profile i IP Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 0.1 3 l 1 201 622 45 1 1,399 70- 2,177 95- 2,955 117- 3,666 142 4,433 167 5,213 1 L CI = 192 5,980 ze s w 0 217 6,764 Q 239 7,476 260 8,173 285 8,953 310 9,729 335 10,511 360 11,295 385 12,074 I s Pi PDS Report Overview 1-4.10.E Body Region Analysis Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 8rd Analyst: HY.Yang Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD 2.992 in. 3 ft. 12,283 ft. Penetration(%wall) Damage Profile(%wall) 500 mil Penetration body INNI Metal loss body 0 50 100 0.1 400 hid 300 45 — 200 li> 100 95 K GLM 1 (6:30) - 0 0 to 20 to 40 to over w-4 20% 40% 85% 85% 142 Number of joints analyzed(total=404) 404 0 0 0 =_- _7_-__- 192 Damage Configuration(body) 10 8111 ■■■ GLM 2 (9:30) 239 6 4 ■■■■ 285 111111111111111 NI -=2 iii ■■■ 335 0 IIPIPisolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=6) 385 6 0 0 0 0 Bottom of Survey=390.5 ! 0 PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 3 0 0.02 9 0 2.94 Pup J 1 7 0 0.04 16 8 2.91 Shallow Pitting. Lt Deposits. 1 1,1 34 0 0.03 12 3 2.93 Pup Lt. Deposits, ■ 1.2 38 0 0.04 14 4 2.92 Pup Lt. Deposits. ■ 2 46 0 0.03 11 4 2.92 Lt.Deposits. ■ 3 77 0 0.04 16 7 2.95 Shallow Pitting I. 1 4 106 0 0.04 14 6 2.94 a 5 136 0 0.04 16 7 2.93 Shallow Pitting. i 6 168 0 0.03 11 3 2.92 Lt.Deposits, ■ 7 199 0 0.04 14 4 2.94 ■ 8 231 0 0.03 11 4 2.93 Lt.Deposits. ■ 9 262 0 0.03 11 4 2.92 Lt.Deposits. ■ 10 294 0 0.04 14 6 2.94 a 11 326 0 0.03 12 4 2.94 ■ 12 357 0 0.03 11 3 2.94 ■ 13 389 0 0.03 12 6 2.94 a 14 418 0 0.03 12 5 2.95 a 15 450 0 0.04 16 7 2.92 Shallow Pitting. Lt Deposits. 15.1 479 0 0.02 9 1 2.92 Pup Lt. Deposits. 15.2 489 0 0 0 0 2.87 CAMCO 2.875 DS NIPPLE 15,3 490 0 0.01 5 1 2.92 Pup Lt. Deposits. 16 500 0 0.04 14 7 2.88 Lt.Deposits. 17 529 0 0.02 9 2 2.89 Lt.Deposits. 18 560 0 0.03 11 4 2.94 ■ 19 591 0 0.03 12 3 2.91 Lt.Deposits. ■ 20 622 0 0.03 12 4 2.92 Lt.Deposits. ■ 21 653 0 0.03 11 2 2.91 Lt.Deposits, a 22 685 0 0.03 10 3 2.92 Lt.Deposits. ■ 23 716 0 0.03 12 4 2.93 Lt.Deposits. ■ 24 747 0 0.04 16 9 2.91 Shallow Pitting. Lt Deposits. I 25 776 0 0.03 12 2 2.95 ■ 26 807 0 0.03 . 12 4 2.92 Lt.Deposits. a 27 839 0 0.03 11 4 2.92 Lt.Deposits. ■ 28 871 0 0,03 10 3 2.93 Lt.Deposits. ■ 29 902 0 0.03 11 4 2.91 Lt.Deposits. ■ 30 933 0 0.04 14 5 2.93 ■ 31 963 0 0.04 14 6 2.93 Lt.Deposits. a 32 993 0 0.03 12 4 2.95 ■ 33 1025 0 0.04 14 5 2.93 Lt.Deposits. a 34 1056 0 0.04 16 9 2.91 Shallow Pitting. Lt Deposits. 35 1085 0 0.02 9 4 2.94 J 36 1117 0 0.03 11 3 2.91 Lt.Deposits. ■ 37 1149 0 0.03 11 3 2.92 Lt.Deposits. ■ 38 1179 0 0.03 11 4 2.95 ■ 39 1211 0 0.03 11 4 2.94 ■ 40 1243 0 0.03 11 3 2.93 Lt.Deposits. 41 1275 0 0.02 9 4 2.93 42 1307 0 0.03 11 5 , 2.93 ■ 43 1335 0 0.03 11 2 2.90 Lt.Deposits. ■ 44 1367 0 0.03 12 4 2.93 IPenetration Body Metal Loss Body Page 1 ! • 1111 - iiiPS PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 45 1399 0 0.03 11 3 2.92 Lt.Deposits. 46 1431 0 0.03 11 3 2.93 Lt.Deposits. 47 1463 0 0.02 9 2 2.92 Lt.Deposits. 48 1495 0 0.04 14 7 2.94 49 1524 0 0.03 12 3 2.91 Lt.Deposits. 50 1554 0 0.02 9 2 2.90 Lt.Deposits. 51 1586 0 0.03 12 3 2.90 Lt.Deposits. !I 52 1618 0 0.04 14 , 7 2.93 Lt.Deposits. 53 1647 0 0.02 9 3 2.92 Lt.Deposits. 54 1679 0 0.03 11 2 2.88 Lt.Deposits. 55 1711 0 0.02 7 1 2,92 Lt.Deposits. 56 1742 0 0.02 9 1 2,92 Lt.Deposits. U 57 1774 0 0.03 10 2 2.91 Lt.Deposits. U 58 1805 0 0.02 7 2 2.90 Lt.Deposits. r 59 1835 0 0.01 4 0 2.88 Lt.Deposits. 60 1866 0 0.01 5 0 2.90 Lt.Deposits. 61 1897 0 0.02 7 1 2.90 Lt.Deposits. U 62 1929 0 0.02 9 2 2.88 Lt.Deposits. • 63 1959 0 0.02 7 1 2.88 Lt.Deposits. 64 1991 0 0.02 9 1 2,90 Lt.Deposits. • 65 2023 0 0.02 7 0 2,90 Lt.Deposits. • 66 2053 0 0.02 9 0 2.89 Lt.Deposits. • 67 2085 0 0.02 9 3 2.88 Lt.Deposits. C 68 2114 0 0.02 7 0 2.91 Lt.Deposits. 69 2146 0 0.02 9 0 2.89 Lt.Deposits. • 70 2177 0 0.04 14 3 2.89 Lt.Deposits. r 71 2208 0 0.01 5 0 2.89 Lt.Deposits, 72 2240 0 0.02 7 0 2.91 Lt.Deposits. II 73 2271 0 0.01 4 0 2.90 Lt.Deposits. 74 2303 0 0.02 7 0 2.91 Lt.Deposits. • 75 2335 0 0.01 5 0 2.88 Lt.Deposits. 76 2367 0 0.02 7 0 2.91 Lt.Deposits. ■ 77 2399 0 0.02 7 0 2.89 Lt.Deposits. • 78 2431 0 0.02 9 2 2.90 Lt.Deposits. • 79 2460 0 0.02 7 1 2.87 Lt.Deposits. 1 80 2490 0 0.03 12 1 2,91 Lt.Deposits. r 81 2521 0 0.01 5 0 2.89 Lt.Deposits. • 82 2553 0 0.01 5 0 2.89 Lt.Deposits. • 83 2585 0 0.02 7 0 2.88 Lt.Deposits. U 84 2617 0 0.02 7 0 2.90 Lt.Deposits. s 85 2648 0 0.00 . 2 0 2.88 Lt.Deposits. 86 2679 0 0.03 11 3 2.90 Lt.Deposits. 87 2710 0 0.02 9 1 2.90 Lt.Deposits. 1 88 2738 0 0.02 7 0 2.90 Lt.Deposits. 89 2770 0 0.02 9 2 2.91 Lt.Deposits, A 90 2800 0 0.03 11 2 2.89 Lt.Deposits. r 91 2831 0 0.02 7 0 2.88 Lt.Deposits. is 92 2862 0 0.02 9 1 2.87 Lt.Deposits. • 93 2892 0 0.01 5 0 2.87 Lt.Deposits. 94 2924 0 0.00 2 0 2.87 Lt.Deposits. IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 95 2955 0 0.01 3 0 2.90 Lt.Deposits. 1 96 2986 0 0.01 3 0 2.88 . Lt.Deposits. • 97 3018 0 0,02 9 1 2.86 Lt.Deposits. 98 3047 0 0.01 5 0 2.90 Lt.Deposits. 99 3079 0 0,01 5 0 2.89 Lt.Deposits, 100 3111 0 0.02 7 0 2.88 Lt.Deposits. • U 101 3143 0 0.02 . 9 0 2.86 Lt.Deposits. 102 3174 0 0.01 4 0 2.87 Lt.Deposits. 103 3206 0 0.01 5 0 2.87 Lt.Deposits. 104 3238 0 0.00 2 0 2.89 Lt.Deposits. 105 3269 0 0.01 3 0 2.87 Lt.Deposits. 106 3301 0 0,01 3 0 2.88 Lt.Deposits. 107 3331 0 0.02 7 0 2.90 Lt.Deposits. U 108 3362 0 0.01 3 0 2,85 Lt.Deposits. 109 3394 0 0.01 5 0 2.90 Lt.Deposits. 110 3425 0 0.01 5 0 2.87 Lt.Deposits. 110.1 3456 0 0.01 4 0 2.86 Pup Lt. Deposits. 110.2 3466 0 0 0 0 2.75 GLM 1 (LATCH @ 6:30) 110.3 3473 0 0.01 5 0 2.89 Pup Lt. Deposits. 111 3483 0 0.03 10 2 2.91 Lt.Deposits. 112 3512 0 0.00 2 0 2.89 Lt.Deposits. 113 3544 0 0.00 2 0 2.90 Lt.Deposits. 114 3574 0 0.02 9 2 2.89 Lt.Deposits. • 115 3603 0 0.02 7 0 2,89 Lt.Deposits. 116 3634 0 0.02 7 0 2.90 Lt.Deposits. 117 3666 0 0.01 3 0 2.88 Lt.Deposits. 118 3697 0 0.01 5 . 0 2.88 Lt.Deposits. 119 3728 0 0.03 10 2 2.89 Lt.Deposits. 111 120 3757 0 0.01 5 0 2.88 Lt.Deposits. 121 3788 0 0.01 5 0 2.89 Lt.Deposits. • 122 3820 0 0.00 2 0 2.86 Lt.Deposits. 123 3850 0 0.02 9 2 2.90 Lt.Deposits. 124 3879 0 0.01 5 0 2.87 Lt.Deposits. 125 3911 0 0.03 12 2 2.90 Lt.Deposits. 126 3939 0 0.02 9 0 2.86 Lt.Deposits. 127 3971 0 0.02 9 1 2.89 Lt.Deposits. • 128 4002 , 0 0.00 2 0 2.87 Lt.Deposits. 129 4034 0 0.03 11 0 2.87 Lt.Deposits. • 130 4065 0 0.01 3 0 2.87 Lt.Deposits. 131 4097 0 0.02 7 0 2.89 Lt.Deposits. 132 4129 0 0.03 11 2 2.90 Lt.Deposits. 133 4158 0 0.04 14 5 2.90 Lt.Deposits. C 134 4188 0 0.02 7 1 2.89 Lt.Deposits. 135 4219 0 0.01 5 1 2.89 Lt.Deposits. 136 4248 0 0.02 9 0 2.88 Lt.Deposits. • 137 4280 0 0.02 7 1 2.90 Lt.Deposits. 138 4311 , 0 0.02 7 2 2.87 Lt.Deposits. V 139 4340 0 0,02 7 0 2.90 Lt.Deposits. 140 4369 0 0.01 4 0 2.89 Lt.Deposits. 141 4401 0 0.01 3 0 2.89 Lt.Deposits. Penetration Body Metal Loss Body Page 3 • • (PS PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 li 142 4433 0 0.01 5 0 2.88 Lt.Deposits. 143 4464 0 0.02 7 0 2.90 Lt.Deposits. U 144 4496 0 0.01 5 0 2.87 Lt.Deposits. II 145 4527 0 0.02 7 0 2.87 Lt.Deposits. 146 4558 0 0.01 5 0 2.90 Lt.Deposits. en 147 4589 0 0.03 10 1 2.88 . Lt.Deposits. 148 4621 0 0,02 9 0 2.88 Lt.Deposits. • II 149 4652 0 0.02 7 1 2.90 Lt.Deposits. 150 4681 0 0.02 7 0 2.89 Lt.Deposits. ii 151 4713 0 0.01 5 0 2.88 Lt.Deposits. i 152 4745 0 0.01 4 0 2.87 Lt.Deposits. 153 4777 0 0.01 4 0 2.90 Lt.Deposits. 154 4808 0 0.02 9 1 2.89 Lt.Deposits. • 155 4840 0 0.01 5 0 2.89 Lt.Deposits. 1 156 4872 0 0.02 9 1 2.87 Lt.Deposits. • 157 4901 0 0.01 4 0 2.89 Lt.Deposits. i 158 4933 0 0.01 5 0 2.91 Lt.Deposits. III 159 4965 0 0.02 7 1 2.89 Lt.Deposits. • IN 160 4996 0 0.03 10 2 2.88 Lt.Deposits. I 161 5025 0 0.01 5 0 2.86 Lt.Deposits. 162 5057 0 0.02 7 0 2.90 Lt.Deposits. U 163 5089 0 0.01 5 0 2.88 Lt.Deposits. I 164 5121 0 0.01 5 0 2.89 Lt.Deposits. 165 5153 0 0.01 3 0 2.89 Lt.Deposits. 166 5183 0 0.03 10 2 2.86 Lt.Deposits. C 167 5213 0 0.02 7 0 2.90 Lt.Deposits. 168 5244 0 0.02 7 1 2.90 Lt.Deposits. N 169 5276 0 0.01 3 0 2.90 Lt.Deposits. 170 5308 0 0.03 11 2 2.87 Lt.Deposits. r 171 5337 0 0.01 4 0 2.87 Lt.Deposits. 172 5369 0 0.01 3 0 2.86 Lt.Deposits. 173 5400 0 0.04 14 2 2.89 Lt.Deposits. A 174 5430 0 0.01 3 0 2.90 Lt.Deposits. 175 5460 0 0.01 5 0 2.87 Lt.Deposits. i 176 5491 0 0.01 3 0 2.88 Lt.Deposits. 177 5522 0 0.01 3 0 2.90 Lt.Deposits. 178 5552 0 0.01 5 0 2.90 Lt.Deposits. • 179 5584 0 0.02 9 1 2.88 Lt.Deposits. • 180 5612 0 0.02 7 0 2.90 Lt.Deposits. i 181 5642 0 0.01 5 0 2.89 Lt.Deposits. tt 182 5673 0 0.02 7 0 2.89 Lt.Deposits. • 183 5705 0 0.01 5 0 2.88 Lt.Deposits. • 184 5736 0 0.03 10 1 2.88 Lt.Deposits. • 185 5766 0 0.02 7 0 2.88 Lt.Deposits. 186 5798 0 0.02 7 1 2.89 Lt.Deposits. • 187 5828 0 0.03 10 1 2.86 Lt.Deposits. • 188 5858 0 0.02 9 2 2.91 Lt.Deposits. • 189 5886 0 0.01 5 0 2.88 Lt.Deposits. 190 5918 0 0.02 7 0 2.89 Lt.Deposits. N 191 5949 0 0.00 2 0 2.88 Lt.Deposits. i IPenetration Body Metal Loss Body Page 4 • • PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 192 5980 0 0.01 5 0 2,90 Lt,Deposits. 193 6012 0 0.01 5 0 2.87 Lt.Deposits. 194 6044 0 0.03 10 2 2.87 Lt.Deposits. a 195 6073 0 0.03 10 2 2.91 Lt.Deposits. • 196 6105 0 0.02 7 0 2.88 Lt.Deposits. 197 6136 0 0,02 7 0 2.89 Lt.Deposits. 198 6168 0 0.02 7 1 2.88 Lt.Deposits. 199 6199 0 0.03 10 0 2.88 Lt.Deposits. • 200 6230 0 0.02 7 1 2.88 Lt.Deposits. U 201 6262 0 0.02 9 0 2.88 Lt.Deposits. • 202 6293 0 0.01 3 0 2.90 Lt.Deposits. • 203 6324 0 0.02 7 0 2.90 Lt.Deposits. 204 6356 0 0.03 10 0 2,88 Lt.Deposits. • 205 6388 0 0.01 5 0 2.90 Lt.Deposits. l 206 6420 0 0.02 9 0 2.88 Lt.Deposits. 207 6452 0 0.01 3 0 2.89 Lt.Deposits. 208 6484 0 0.01 5 0 2.90 Lt.Deposits. 209 6516 0 0.01 5 0 2.88 Lt.Deposits. 210 6546 0 0.02 7 1 2.87 Lt.Deposits. 211 6577 0 0.03 10 1 2.87 Lt.Deposits. 212 6607 0 0.02 9 0 2.86 Lt.Deposits. • 213 6637 0 0.02 9 1 2.89 Lt.Deposits. • 214 6669 0 0.01 5 0 2.88 Lt.Deposits. 215 6700 0 0.02 9 1 2.86 . Lt.Deposits. • 216 6732 0 0.01 5 0 2.89 Lt.Deposits. 217 6764 0 Q.02 7 0 2.89 Lt.Deposits. 218 6795 0 0.02 7 1 2.89 Lt.Deposits. U 219 6826 0 0.02 7 1 2.88 Lt.Deposits. • 220 6858 0 0,01 5 0 2.88 Lt.Deposits. 221 6890 0 0.02 7 0 2.90 Lt.Deposits. U 222 6921 0 0.01 5 0 2.90 Lt.Deposits. 223 6951 0 0.01 5 0 2.89 Lt.Deposits. • 224 6983 0 0.01 5 0 2.88 Lt.Deposits. • 225 7015 0 0.02 9 1 2.90 Lt.Deposits. 226 7047 0 0.01 4 0 2.87 Lt.Deposits. 227 7079 0 0.02 9 1 2.89 Lt.Deposits. 228 7108 0 0.02 7 0 2.89 Lt.Deposits. • 229 7140 0 0.02 9 1 2.89 Lt.Deposits. • 230 7169 0 0.02 9 0 2.91 Lt.Deposits. a 231 7201 0 0.03 10 0 2.87 Lt.Deposits. 232 7232 0 0.03 12 1 2.89 Lt.Deposits. 233 7264 0 0.01 5 1 2.91 Lt.Deposits. l 234 7293 0 0.03 11 1 2.88 Lt.Deposits. • 235 7325 0 0.01 5 0 2.90 Lt.Deposits. 236 7355 0 0.02 7 0 2.89 Lt.Deposits. 237 7386 0 0.02 9 0 2.90 Lt.Deposits. • 238 7417 0 0,02 7 1 2.89 Lt.Deposits. • 238.1 7449 0 0.02 7 0 2.89 Pup Lt. Deposits. 238.2 7458 0 0 0 0 2.77 GLM 2(LATCH®9:30) 238.3 7466 0 0.01 5 0 2.87 Pup Lt. Deposits. 'Penetration Body Metal Loss Body Page 5 • PDS Report Joint Tabulation Sheet WeH: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhifips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 239 7476 0 0.01 4 0 2.88 Lt.Deposits. 239.1 7508 0 0.00 2 0 2.87 Pup Lt. Deposits. 239.2 7515 0 0 0 0 2.87 BAKER 80-40 SEAL ASSEMBLY 239.3 7532 0 0 0 0 2.83 BAKER FHL PACKER 239.4 7544 0 0 0 0 2.84 Pup Lt. Deposits. 240 7546 0 0.02 7 0 2.87 Lt.Deposits. • 241 7578 0 0.02 7 0 2.88 Lt.Deposits. 242 7609 0 0.00 2 0 2.86 Lt.Deposits. • 243 7640 0 0,01 5 0 2.85 Lt.Deposits. 244 7672 0 0.02 9 0 2.85 Lt.Deposits, U 245 7703 0 0.01 4 0 2.87 Lt.Deposits. I 246 7734 0 0.01 4 0 2.83 Lt.Deposits. 247 7766 0 0.01 4 0 2.86 Lt.Deposits. 248 7797 0 0.00 2 0 2.86 Lt.Deposits. 249 7829 0 0.01 4 0 2.84 Lt.Deposits. 250 7860 0 0.02 9 0 2.87 Lt.Deposits. mit 251 7892 0 0.03 11 0 2,87 Lt.Deposits. 252 7923 0 0.02 9 0 2.84 Lt.Deposits. • 253 7954 0 0.01 5 0 2.87 Lt.Deposits. • • 254 7986 0 0.02 , 7 0 2,86 Lt.Deposits. 255 8015 0 0.02 9 0 2.87 Lt.Deposits. • • 256 8047 0 0.02 9 0 2.88 Lt.Deposits. 257 8078 , 0 0.01 4 0 2.85 Lt.Deposits. 258 8110 0 0.01 5 0 2.87 Lt.Deposits. 259 8141 0 0.01 5 0 2.86 Lt.Deposits. • 260 8173 0 0.02 7 0 2.86 Lt.Deposits. • 261 8204 0 0.02 9 0 2.88 Lt,Deposits. • 262 8236 0 0.03 11 0 2.86 Lt.Deposits. ■ 263 8267 0 0.02 7 0 2.86 Lt.Deposits. • 264 8298 0 0,02 7 0 2.85 Lt.Deposits. • 265 8329 0 0.04 14 0 2.85 Lt.Deposits. 266 8360 0 0.01 5 0 2.85 Lt.Deposits. 267 8392 0 0.01 5 0 2.85 Lt.Deposits. 268 8422 0 0.01 5 0 2.86 Lt.Deposits. • 269 8454 0 0 0 0 2.84 Lt.Deposits. 270 8485 0 0.03 12 0 2.86 Lt.Deposits. • 271 8517 0 0.00 2 0 2.82 Lt.Deposits. 272 8548 0 0.00 2 0 2.84 Lt.Deposits. 273 8580 0 0.02 7 0 2.86 Lt.Deposits. • 274 8611 0 0,01 5 0 2.83 Lt.Deposits. • 275 8641 0 0.01 5 0 2.84 Lt.Deposits. 276 8671 0 0.03 12 0 2.87 Lt.Deposits. 277 8703 0 0.02 . 7 0 2.83 Lt.Deposits. • • 278 8734 0 0.02 7 0 2.84 Lt.Deposits. 279 8765 0 0.01 5 0 2,84 Lt.Deposits. 280 8796 0 0.02 9 0 2.85 Lt.Deposits. • 281 8827 0 0.01 5 0 2.84 Lt.Deposits. • 282 8859 0 0.01 5 0 2.83 Lt.Deposits. • 283 8890 0 0.01 5 0 2.82 Lt.Deposits. 284 8921 0 0.02 7 1 2.85 Lt.Deposits. • Penetration Body Metal Loss Body Page 6 • 1111. PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 • 285 8953 0 0.01 5 0 2.82 Lt.Deposits. • 286 8984 0 0.01 5 0 2.84 Lt.Deposits. 287 9015 0 0.03 11 0 2.85 Lt.Deposits, ■ 288 9046 0 0.01 4 0 2.83 Lt.Deposits. 289 9077 0 0.03 11 0 2.84 Lt.Deposits. e 290 9109 0 0,00 2 0 2.83 Lt.Deposits. 291 9140 0 0.01 5 0 2.83 Lt.Deposits, 292 9172 0 0.01 5 0 2.83 Lt.Deposits. • 293 9203 0 0.02 7 0 2.83 Lt.Deposits. 294 9233 0 0.02 9 0 2.86 Lt.Deposits. • 295 9264 0 0.01 5 0 2.81 Deposits. 296 9295 0 0.00 2 0 2.82 Lt.Deposits. 297 9327 0 0.01 4 0 2.83 Lt.Deposits. 298 9356 0 0 0 0 2.82 Lt.Deposits. 299 9387 0 0.01 5 0 2.84 Lt.Deposits. 300 9418 0 0.01 5 0 2.82 Lt.Deposits. 301 9450 0 0.01 4 0 2.84 Lt.Deposits, 302 9481 0 0.01 4 0 2.82 Lt.Deposits. 303 9512 0 0.02 9 0 2.82 Lt.Deposits. • 304 9542 0 0.02 9 0 2.84 Lt.Deposits. • 305 9574 0 0.02 7 0 2.83 Lt.Deposits. • 306 9603 0 0.01 5 0 2.83 Lt.Deposits. 1 307 9634 0 0.02 7 0 2.83 Lt.Deposits. • 308 9666 0 0.01 4 0 2.82 Lt.Deposits. 309 9697 0 0,02 7 0 2.81 Deposits. 310 9729 0 0.04 14 0 2.82 Lt.Deposits, 311 9760 0 0.01 4 0 2.79 Deposits. 312 9791 0 0 0 0 2.80 Deposits. 313 9823 0 0.00 2 0 2.80 Deposits. 314 9855 0 0.01 5 0 2,82 Lt.Deposits. • • 315 9886 0 0.02 9 0 2.78 Deposits. 316 9917 0 0.01 4 0 2.79 Deposits. • 317 9949 0 0.02 7 0 2.75 Deposits. 318 9981 0 0.03 11 0 2,82 Lt.Deposits. 319 10012 0 0.00 2 0 2.81 Deposits. 320 10043 0 0.01 4 0 2.82 Lt.Deposits. 1 321 10075 0 0.01 4 0 2.80 Deposits, 322 10107 0 0.01 4 0 2.81 Lt.Deposits. 323 10138 0 0.01 5 0 2.80 Deposits. • 324 10170 0 0.03 11 0 2.82 Lt.Deposits. 325 10201 0 0.01 5 0 2.81 Deposits. • 326 10233 0 0.01 4 0 2.79 Deposits. 327 10262 0 0.01 4 0 2.81 Deposits. 328 10293 0 0.01 4 0 2,78 Deposits, 329 10323 0 0.02 7 0 2.77 Deposits. • 330 10354 0 0.01 5 0 2.80 Deposits. 331 10385 0 0.02 7 0 2.79 Deposits. • 332 10417 0 0.02 7 0 2.80 Deposits. • 333 10448 . 0 0.00 2 0 2.79 Deposits. 334 10479 0 0.00 2 0 2.78 Deposits. IPenetration Body Metal Loss Body Page 7 • 1110 R.S PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss LD• Comments (%wall) (in.) (in.) % (in.) 0 50 100 335 10511 0 0.00 2 0 2.78 Deposits. 336 10542 0 0.01 5 0 2.78 Deposits. • 337 10573 0 0.02 9 _ 0 2.79 Deposits. 338 10605 0 0.01 5 _ 0 2.81 Deposits. 339 10636 0 0.01 4 0 2.78 Deposits. 340 10668 0 0.01 5 0 2.78 Deposits. • 341 10698 0 0.02 7 _ 0 2.81 Deposits, 342 10730 0 0.02 7 0 2.83 Lt.Deposits. U 343 10761 0 0.02 9 0 2.82 Lt.Deposits. U 344 10792 0 0.01 4 0 2.80 Deposits. 345 10824 0 0,02 7 _ 0 2.79 Deposits. • 346 10855 0 0.01 5 0 2.75 Deposits. 347 10886 0 . 0.02 7 0 2.81 Deposits. • 348 10918 0 0 0 ; 0 2.80 Deposits. 349 10949 0 0.01 5 0 2.78 Deposits. 350 10981 0 0.00 2 0 2.78 Deposits. 351 11012 0 0.00 2 0 2.80 Deposits. 352 11044 0 0.02 7 0 2.78 Deposits, • 353 11076 0 0.02 9 0 2.81 Deposits. • 354 11107 0 0.02 7 , 0 2.80 Deposits. • 355 11138 0 0.01 4 0 2.78 Deposits. 356 11169 0 0.03 11 0 2.73 Deposits. ■ 357 11201 0 0.01 4 0 2.79 Deposits. 358 11232 0 0.01 5 0 2.80 Deposits. • 359 11264 0 0.01 5 0 2.77 Deposits. 360 11295 0 0.02 7 0 2.79 Deposits. 361 11325 0 0.02 7 0 2.76 Deposits. • 362 11357 0 0 0 0 2,73 Deposits. 363 11387 0 0 0 0 2.73 Deposits. 364 11418 0 0 0 0 2.74 Deposits. 365 11450 0 0 0 0 2.72 Deposits, 366 11480 0 0 0 0 2.72 Deposits. 367 11511 , 0 0 0 0 2.72 Deposits. 368 11543 0 0 0 0 2.73 Deposits. 369 11574 0 0 0 0 2.74 Deposits. 370 , 11606 0 0 0 0 2.71 Deposits. 371 11636 0 0 0 0 2.72 Deposits. 372 11667 0 0 0 0 2.72 Deposits. 373 11698 0 0 0 0 2.72 Deposits. 374 11729 0 0 0 , 0 2.72 Deposits. 375 11761 0 0.00 2 _ 0 2.72 Deposits. 376 11792 0 0.00 2 0 2.72 Deposits. 377 11824 . 0 0 0 0 2.71 Deposits. 378 11855 0 0 0 0 2.72 Deposits. 379 11886 0 0.02 7 _ 0 2.70 Deposits. • 380 11917 0 0 0 0 2.71 Deposits. 381 11949 0 0 0 0 2.73 Deposits. 382 11980 0 0.00 2 0 2.73 Deposits. 383 12011 0 0 0 0 2.74 Deposits. 384 12042 0 0 0 0 2.72 Deposits. IPenetration Body Metal Loss Body Page 8 • S PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 3 ft. 12,283 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 385 12074 0 0 , 0 0 2.73 Deposits. 386 12105 0 0 0 0 2.71 Deposits. 387 12136 0 0 0 0 2.70 Deposits. 388 12168 0 0.00 2 0 2.71 Deposits. 389 12199 0 0 0 0 2.70 Deposits. 390 12230 0 0 0 0 2.69 Deposits. 390.1 12261 0 0 . 0 0 2.69 Pup Deposits. 390.2 12267 0 0 0 0 2.62 CAMCO DS NIPPLE 2.81 PROFILE 390.3 12268 0 0 0 0 2.70 Pup Deposits. 390.4 12274 0 0 0 0 2.64 Pup Deposits. 390.5 12283 0 0 0 0 2.63 BAKER LOCATOR Penetration Body Metal Loss Body Page 9 . ! • VSPDS Report Cross Sections M Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8rd Analyst: HY.Yang Cross Section for Joint 390.2 at depth 12,267.529 Tool speed= 49 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=43° '''''''N\N\ 7 \` 1 I Minimum I.D.=2.615 in. Deposits on DS Nipple Minimum I.D.=2.62 in. HIGH SIDE=UP • . • • (f . PDS Report Cross Sections Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8rd Analyst: HY.Yang Cross Section for Joint 390.5 at depth 12,283.239 Tool speed= 49 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=43° _— 7 , 1 \ ' Minimum I.D.=2.630 in. Deposits on Locator Minimum I.D.=2.63 in. HIGH SIDE=UP . • • Ca PDS Report Cross Sections Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8rd Analyst: HY.Yang Cross Section for Joint 390.4 at depth 12,278.126 ft. Tool speed=50 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=43° / \ •I i I ` l \ l i Minimum I.D.=2.638 in. Deposits Minimum I.D.=2.64 in. HIGH SIDE= UP . • • IRS. PDS Report Cross Sections Well: 3M-23 Survey Date: March 18,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8rd Analyst: HY.Yang Cross Section for Joint 390.1 at depth 12,266.649 ft. Tool speed=51 Nominal ID=2.992 Nominal OD=3.5 " Remaining wall area= 100% '~----,„ Tool deviation=43° 1 I 1 , \ / Minimum I.D.=2.691 in. Deposits Minimum I.D.=2.69 in. HIGH SIDE= UP KUP PRODill 3M-23 * Conocoihillips ' , ", n Well Attributes Max Angle&MD TD Alaska,Inc. 1A• Wellbore API/UWI Field Name Wellbore Status ncl I") MD(ttKB) Act Btm(ftKB) craw rH,afirw". 500292242600 KUPARUK RIVER UNIT PROD • 70.34 11,019.39 12,750.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-23,9/3020138:1623 AM SSSV:NIPPLE Last WO: 9/1/2013 41.00 12/29/1993 Vertical schematic(actual) Annotation Depth(11KB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,398.0 5/31/2013 Rev Reason:PULL PLUG/CATCHER,GLV C/O hipshkf 9/28/2013 HANGER 31.3 LIAR.' Casing Strings C- Casing Description OD(in) ID(In) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED ` Casing Description OD(In) ID(In) Top(ttKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "1111""""1X1111"11111""" """"""" saguittasuuu SURFACE 9 5/8 8.535 41.9 5,437.2 3,306.7 53.50 L-80 BTC Casing Description '00(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...-WVLen(I.,.Grade Top Thread PRODUCTION 7 6.276 36.8 12,721.6 6,374.0 26.00 L-80 BTCMODR3 Tubing Strings Tubing Description String Ma.-.ID(in) Top(ttKB) Set Depth(tt..Set Depth(1VD)(...Wt(Iblft) Grade Top Connection i1/41-:' 4...-TUBING WO 2013 , 31/21 2.9921 31.31 7,536.4] 4,070.0) 9.301 L-80 ISrd Completion Details CONDUCTOR 43.0-121.0 Nominal ID Top(RKB) Top(TVD)(ttKB) Top Incl(") Item Des Com (In) 31.3' 31.3 0.54 HANGER FMC TUBING HANGER 2.992 NIPPLE;516.5 516.5 516.5 0.09 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 7,532.7 4,068.6 68.43 LOCATOR BAKER SEAL ASSEMBLY LOCATOR 2.992 1-i 7,533.9 4,069.1 68.43 SEAL ASSY BAKER 80.40 SEAL ASSEMBLY(OAL=16.46') 3.000 Tubing Description I String Ma...ID(In) Top(ttKB) -Set Depth(ft..Set Depth(TVD)(...Wt(IbWt) Grade I Top Connection STRADDLE PKR Ill 3 1/2 2.992 7,522.4 12,294.0 6,067.7 9.30 L-80 III 8RD EUE Mod ASSY Completion Details GAS LIFT;3,485.5RS Nominal ID Top(ttKB) lop(TVD)MKS) Top 1001(°) Item Dee Com (In) ..t 7,522.4 4,064.8 68.43 SLEEVE HR LINER SETTING SLEEVE 5.250 7,536.4 4,070.0 68.43 NIPPLE RS PACKOFF SEAL NIPPLE 4.250 • 7,538.9 4,070.9 68.42 PBR BAKER 80-40 PSR 4.000 7,551.3 4,075.5 68.39 PACKER BAKER FHL PACKER 2.992 12,267.2 6,048.8 45.02 NIPPLE CAMCO DS NIPPLE 2.81"PROFILE 2.812 SURFACE,41.95,x37.2- • 12.282.3 6,059.5 44.94 LOCATOR BAKER LOCATOR 2.992 12,282.5 6,059.6 44.94 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.000 Tubing Description (String Ma,..IID(In) TOP(ttKB) I Set Depth(ft.."Set Depth(TVD)(...I Wt(IbM) (Grade (Top Connection GAS LIFT;7.4773 it* TUBING Original 5 7!8 4.000 12,283.5 12,325.4 6,090.01 Completion Details Nominal ID Top(MB) Top(TVD)(RKB) Top Incl(•) Item Des Com (in) 12,283.5 6,060.3 44.94 PBR BAKER PBR 4.000 r-. ! 12,296.5 6,069.5 44.88 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 SLEEVE;7.522.4 j-• 12,297.4 6,070.2 44.87 PACKER BAKER SAE-3 PERMANENT PACKER 3.250 LOCATOR;7,532.7 M 12,302.3 6,073.6 44.85 XO Reducing Cross Over 4.5 x 3.5 2.992 SEAL ASSY;7533.9 I`_,11 12,313.4' 6,081.5' 44.80 NIPPLE CAMCO'D'NIPPLE 2.75"PROFILE 2.750 NIPPLE;7,536.4 12,324.5 6,089.4 44.76 WLEG BAKER SOS WIRELINE GUIDE 2.992 Perforations&Slots PER;75369 Shot Dens Top(TVD) Btm(TVD) (shotslf PACKER;7,5513 " Top(ttKB) Btm(ttKB) (ttKB) (ttKB) Zone Date t) 'Type Com 12,423.0 12,443.0 6,159.8 6,174.2 C-4,3M-23 9/12/2001 4.0 APERF 2 1/8"Enerjet w/PJ chgs, 111 O deg ph,+/-90 deg orient I12,450.0 12,466.0 6,179.2 6,190.7 A-2,3M-23 9/7/2001 4.0 APERF 2 1/8"Enerjet w/PJ chgs, 0 deg ph,+/-90 deg NIPPLE;12,267.2orient • 12,474.0 12,484.0 6,196.5 6,203.7 A-1,3M-23 9/6/2001 4.0 APERF 2 1/8"Enerjet w/PJ chgs, 0 deg ph,+/-90 deg LOCATOR;12,2823 Orient 12,484.0 12,502.0 6,203.7 6,216.6 A-1,3M-23 4/23/1994 4.0 IPERF 4.5"BH Ultrapak 180 SEAL ASSY;12,282.5, drip ph PER 12283.5 12,484.0 12,494.0 6,203.7 6,210.9 A-1,3M-23 9/12/2001 4.0 RPERF 2 1/8"Enerjetw/PJ chgs, O deg ph,+/-90 deg •SEAL ASSY;12296.5 �.�'; orient PACKER;12.297.4 ',-"' Mandrel Details St ' ad C ' on Top(TVD) Valve Latch Port Size TRO Run o f !,M Top(ftKB) (MB) Make Model OD(In) Sery Type Type (in) (psi) Run Data m NIPPLE;12,313.4 JE' 1 3,485.5 2,596.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,256.0 9/26/2013 11 2 7,477.3 4,048.3 Cameo KBMG 1 GAS LIFT OV BK 0.250 0.0 9/26/2013 WLEG 123245 2 Notes:General&Safety End Date Annotation 7/16/2006 NOTE:WORKOVER-Straddle Packer sat to repair casing holes with drill pipe 5/12/2007 'NOTE:WORKOVER 11/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 - APERF;12,423.0.12,4430--- Y APERF;124500-12.46 6.0 APERF;12474.0.12484.0- RPERF;12,4840-12494.0-�_, i. (PERF;12,484.0-12,502.0-_. - PRODUCTION;356-12,721.6 4- 193187 • WELL LOG TRANSMITTAL RECEWED MAR 2 9 201? 9 18 4 PROACTIVE DiAC,NOSTiC SERVICES, INC. , OGCC To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) Caliper Report 27-Mar-18 3M-23 1 Report /CD 50-029-22426-00 2) 1110 41111 Signed : 4. Date . 1 (D/ 1 Print Name: IN \. A A Q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE{p)MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheeis\ConocoPhillips_Transmit.docx 411 -1--9--3 1 8 7 • 29 1 84 Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, LLC. Well: 3M-23 Log Date: March 27, 2018 Field: Kuparuk Log No.: 18525 State: Alaska Run No.: 5 API No. 50-029-22426-00 Pipe Description: 3.5 inch 9.3 lb. L-80 8RD Top Log Interval: 12,020 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 12,325 Ft. (MD) Pipe Description: 7 inch 26 lb. L-80 BTCMODR3 Top Log Interval: 12,325 Ft. (MD) Pipe Use: Casing Bottom Log Interval: 12,480 Ft. (MD) Inspection Type : Pre-Sidetrack Casing Inspection COMMENTS : This caliper data is tied into the WLEG at 12,324.5 feet(Driller's Depth). This log was run to assess the condition of the casing respect to corrosive and mechanical damage and I.D. restrictions prior to sidetrack operations. A 3-D log plot of the caliper recordings across the 7 inch casing logged and a graph illustrating minimum recorded diameters on a joint-by-joint basis are included in this report. The caliper recordings indicate the 7 inch casing logged appears to be in poor condition with respect to internal corrosive and mechanical damage. Outside of the perforation intervals, the caliper recorded multiple holes from 12,334 feet to 12,406 feet. Recorded damage appears as a deep line of corrosion throughout the majority of casing logged and heavily eroded perforations. Cross-sectional wall loss between 44% and 67% metal volume is recorded from—12,390 feet to 12,480 feet (end of log). The caliper recordings indicate intermittent deposits from 12,020 feet(top of casing)to—12,390 feet, restricting the I.D. to 5.75 inches at 12,334 feet. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to poor condition with respect to internal corrosive and mechanical damage, with a maximum recorded wall penetration of 54%at an isolated pit in pup joint 391.1 (12,310 ft). Recorded damage appears as isolated pitting, specifically in the upset near the joint make-up. Additional wall penetrations of 44% and 39% are recorded at isolated pitting in the make-up in joint 388 (12,167 ft)and joint 386 (12,105 ft) respectively. In addition, the caliper recordings indicate apparent damage to the seal assemblies as seen in the included 3-D log plot of the caliper recordings across the 3.5 inch tubing logged. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. The caliper recorded deposits throughout the tubing logged, restricting the I.D. to 2.70 inches on the DS Nipple at 12,267 feet. A graph illustrating minimum recorded diameters on a joint- by-joint basis across the tubing logged is included in this report. This is the fifth time a PDS caliper has been run in this well, the first time the 7 inch casing has been logged, and the second time this 3.5 inch tubing string has been logged since the RWO in 2013. Due to the purpose of this log and the short duration between the current and previous log (March 18, 2018), no comparison graph of the 3.5 inch tubing is included in this report. sCANNEO " It 74 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : Description; Percent Wail Penetratio:. Isolated Pitting 54 391.1 12,310 Ft. (MD) Isolated Pitting 44 388 12,167 Ft. (MD) Isolated Pitting 39 386 12,105 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the tubing logged. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 3%) are recorded throughout the tubing logged. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : Joint Deposits on DS Nipple 2.70 in. 390.2 12,267 Ft. (MD) Deposits 2.72 in. 386 12,108 Ft. (MD) Deposits 2.72 in. 384 12,063 Ft. (MD) Deposits 2.73 in. 385 12,092 Ft. (MD) Deposits 2.73 in. 383 12,028 Ft. (MD) 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : Description Percent` ""penetration Dep: Multiple Holes 100 3 12,406 Ft. (MD) Multiple Holes 100 2 12,334 Ft. (MD) Line Corrosion 38 1 12,327 Ft. (MD) 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : Percent Wail Loss Eroded Perforations 67 5 12,467 Ft. (MD) Eroded Perforations 47 4 12,460 Ft. (MD) Multiple Holes 44 3 12,395 Ft. (MD) No other significant areas of cross-sectional wall loss (> 10%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : Joint Depth Heavy Deposits 5.75 in. 2 12,334 Ft. (MD) Deposits 5.88 in. 3 12,388 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. B. DiMatteo C. Waldrop P. Rafferty .igineer(s) Analyst(s) Witnes ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: pDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ,cf-i3CS. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M-23 Date : March 27, 2018 Description : Detail of Caliper Recordings Across 7 Inch Casing Logged. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map i,',�1ft:150ft 0 inches 100 5.8 inches 6 8 0° 0° 90° 180° 270° 0° Maximum I.D. I 5.8 inches 6.8 1 Minimum I.D. I I 5.8 inches 6.8 1LJLV - 3.5" Tubing Joint 1 ` � g 38%Walt - +a , .. Penetration 12330 — _ ---- _ t t - 12340 - Joint 2 _ . Multiple Holes 12350 ,r-- - A — AIL. — - Heavy Deposits !' — _ In... ie- w Min.I.D.=5.75" 12360 —'MPle- .- _ ME FSI _ 12370 - _. — Aim- x> 12380 --_ - Joint 3 12390 Multiple Holes :....44%Wall Loss Deposits - Min.I.D.=5.88" 12400 • • • — a_ 12410 '�_ Ilirr-- • _- -. - 12420 a- .__ _ - 12430 Perforations Joint 4 4111E - - a Eroded — - Perforations 12440 7 47%Wall Loss — « :...»�,. V- ^'t 12450 ---Mil - - - a is .. —..iii a 6` ''erforations 12460 Joint 5 r ifol . . , Eroded 12470 .r - Perforations :NOMMEN ...•mms,M11111Ik ..5111111 . 4. 67%Wall Loss erfor w s mann � Minimum I.D. I I 5.8 inches 6.8 Maximum I.D. I— —i 5.8 inches 6.8 Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map 1ft:150ft 0 inches 100 5.8 inches 6.8 0° 0° 90° 180° 270° 0° • • f . Minimum Diameter Profile Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters(in.) 1.75 2 3 4 5 6 I • I -12,325 1 - -12,331 2 12,374 i 4) C E G 7 3 Z a ID G iii- 12,417 4 - 12,460 5 1 • • PDS Report Overview Body Region Analysis Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 BTCMODR3 6.276 in. 12,325 ft. 12,480 ft. Penetration(%wall) Damage Profile(%wall) 10 INN Penetration body Nom Metal loss body 0 50 100 8 6 411111111 M 2 zhill ilill IIIIIIIII0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed (total=5) 3 0 1 0 2 1111 OW Damage Configuration(body) III 10 4111■ 8 6 11111111 11■■ 4V 5111■ 2 lull.. IIII 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=3) 1111•■ 11 0 0 1 0 2 Bottom of Survey=5 = Perforations • • 111 PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf L-80 BTCMODR3 Casing 6.276 in. 0.362 in. 12,325 ft. 12,480 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 12325 0.14 0.14 38 2 5.96 Line Corrosion. Lt.Deposits. ■mu 2 12331 0.12 0.37 . 100 . 10 5.75 Multiple Holes! Heavy Deposits. stiommminium 3 123 74 0.21 0.69 100 44 5.88 Multiple Holes!Deposits. somomm 4 12417 0.85 0.80 100 47 6.20 Eroded Perforations Lt.Deposits. 1111111111111111 5 12460 0.52 1.03 100 67 6.01 Eroded Perforations Lt.Deposits.I a... Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 1 • • PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 3 at depth 12,405.930 ft. Tool speed=44 Nominal ID=6.276 Nominal OD= 7 /ice Remaining wall area=83% Tool deviation=42° ail 1 Finger=22 Penetration=0.685 in. Multiple Holes 0.69 in.= 100%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 2 at depth 12,334.440 ft. Tool speed=45 Nominal ID=6.276 Nominal OD= 7 Remaining wall area=92% Tool deviation=43° 1 1 die _V Finger=22 Penetration=0.367 in. Multiple Holes 0.37 in.= 100%Wall Penetration HIGH SIDE=UP • • Js PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 5 at depth 12,467.070 Tool speed= 45 Nominal ID=6.276 Nominal OD= 7 Remaining wall area= 33% Tool deviation=42° --,i i 111 \ / N / Finger=9 Penetration=0.725 in. Eroded Perforations 67%Cross-Sectional Wall Loss HIGH SIDE=UP • • • PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 4 at depth 12,459.950 Tool speed= 45 Nominal ID=6.276 Nominal OD= 7 Remaining wall area= 53% Tool deviation=43° Finger= 11 Penetration=0.672 in. Eroded Perforations 47%Cross-Sectional Wall Loss HIGH SIDE= UP i • Cia PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 2 at depth 12,334.400 ft. Tool speed=45 Nominal ID=6.276 Nominal OD= 7 Remaining wall area=92% Tool deviation=43° 1‘, Minimum I.D.=5.750 in. Heavy Deposits Minimum I.D.=5.75 in. HIGH SIDE=UP • • PDS Report Cross Sections _171-[7:1-S___... Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTCMODR3 Analyst: C.Waldrop Cross Section for Joint 3 at depth 12,388.270 ft. Tool speed=45 Nominal ID=6.276 Nominal OD= 7 -„. Remaining wall area=94% Tool deviation=44° K 1 / / \ • P Minimum I.D.=5.876 in. Deposits Minimum I.D.=5.88 in. HIGH SIDE=UP • • Iii3. PDS Multifinger Caliper 3D Log Plot � Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M-23 Date : March 27, 2018 Description : Detail of Caliper Recordings Across 3.5 Inch Tubing Logged. Comments Depth Maximum Penetration Nominal LD. 3-D Log Image Map lft:120ft 0 % 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° Maximum I.D. I 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 'LUAU Ri■ Joint 383 lillUMIIIIIIIII s< Deposits 12030 1 ISIIII Min.LD.=2.73" SIMI . , , . . , r 12040 - IIII = ^ IliI . = la U ,, 12050 _ I . 1=1 . ,, . ..... „ . ... . .... i Joint 38411 ' _ Deposits �. • ' t .r ,' Min.I.D.=2.72" 12080 k _ U 4 12070IF , ir a,, — -,,...-- 4M ,y2 12080 -4^ • • Deposits Min.I.D.=2.73" 12090 .. 12100, I t ^ 12110I . .. . , ii,. Joint 386 Isolate r Isolated Pitting lit the Upset. 39%Wall 12120 Ii — PenetrationOS Deposits r Min.I.D.=2.72" 1. i - , 12130 . 3 . 7- 12140• a r e . Joint 387 12150i -- Deposits w _ Min.I.D.a 2.74" Ili 1 : 7 . r 12160 .` • Isolated Pitting i' r the Up< A 12170 _ • S Joint 388 i Isolated Pitting 12180 44%Wall - Penetration , i a " Deposits ":: Min.I.D.=2.73" y 12190" 4. - . 12200 h P Y 12210 - . Joint 389 Deposits 4 Min.I.D.=2.78" .. .11, — 12220 _ 5 It I T Lavas -316 - P"` r r - 12230 _ a • - i L at. s 12240 Joint 390 s ' • Deposits ` — _ Min.I.D.=2.73" y, 12250 ' ra — It ? - rte: Ir. 12260- I Pup Joint - " Deposits ' Min.I.D.=2.77" .I' • 0 . . .. . i... 7...,...........- Eli II 12270 En III Pup Joints MP- N *ow Deposits big II Min.ID.=2.77" Eta III Tea Il 12280 MIll _________ iii4t.... . miti=riiiii _ r 'I Baker Seal Assembly ."" Itilt II pA -parent Damage __. : -: in 12290 _ ,the Seal 11111 ...11111 • `• . Assemblies MINIM Baker PBR 111Baker PBR01111111.111111111 Baker Seal .--- 111111111111111111Biaiillitir — " A" Assembly IIIIII 12300 t, 1011111111rilift 1 ', eal Assembly 111111_!...1.111 Baker Packer _ \ Cross-Over IMMElk=1111 Mil I Pup Joint t=0.- Mr=ME isolated Pitting .1/111111111111 - 4' 54%Wall 12310;11.."'" """--- Penetration MIR II .... i 4 / D Nipple(Milled to MINNIMINIIIIImar liralli .... ... ,,... 2.80) ffeeesee...... ... _......-_ Pup Joint MU iii Isolated Pitting in Deposits 12320 tfi . the Pup Joint Min.I.D.=2,74" Ai I F-Al NI _ - ( WLEG 7—•=0116- - ' 111111.11MMOINIIIIMI ,, ' MI 11111 ME NI 7" Casing Minimum I.D. I I 2.5 inches 3.5 Maximum I.D. I i 2.5 inches 3.5 Comments Depth Maximum Penetration Nominal ID. 3-D Log Image Map I 1.--- ,. . .f IIMIIINC---IMIZEL 1ft.120ft 0 °/0 100 2.5 inches 3.5 00 0° 90° 180° 270° 0° • • Minimum Diameter Profile 144S. Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters(in.) 1.75 2 2.25 2.5 2.75 12,020 383 - ���.�� 12,042 384 ��.�.•11MMI 12,073 385 12,104 386 12,136 387 i MIIIIa�III• 12,167 388 12,198 389 C_ 12,230 390 12,260 390.1 Imminnimmine 12,266 cP 390.2 12,267 Q Z 390.3 ��IMINIME 12,274 s O 390.4 v 12,282 390.5 - 1f 12,293 390.6 12,296 390.7 12,301 390.8 :III 12,302 390.9 12,303 391.1 12,313 391.2 12,314 3913 12,325 391.4 I 1 • • PDS Report Overview dilS. Body Region Analysis Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pi 9e 3.5 in. 9.3 ..f L-80 8RD Anal st: C.Waldro. Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD 2.992 in. 12,020 ft. 12,325 ft. Penetration(%wall) Damage Profile(%wall) 10 Ilmil Penetration body InNI Metal loss body 0 50 100 383 ■ 8 ima 6 - 4M I 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total= 13) 388E ligi 10 1 2 0 I ■ Damage Configuration(body) ■ 10 8 6 390.3 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=4) 4 0 0 0 0 Bottom of Survey=391.4 • • PDS Report Joint Tabulation Sheet Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD Tubing 2.992 in. 0.254 in. 12,020 ft. 12,325 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 383 12020 0.04 0.03 10 0 2.73 Deposits. 384 12042 0 0,05 19 0 2.72 Shallow Pitting. Deposits. 385 12073 0.04 0.01 5 0 2.73 Deposits. 386 12104 0.05 0,10 39 2 2.72 Isolated Pitting. Deposits. NEM 387 12136 0 0.01 5 0 2.74 Deposits. 1 388 12167 0.13 0.11 44 3 2.73 Isolated Pitting. Deposits. rim 389 12198 0 0.03 12 0 2.76 Deposits. 390 12230 0 0.03 10 0 2.73 Deposits. 390.1 12260 0 0 0 0 2.77 Pup Deposits. 390.2 12266 0 0 0 0 2.70 CAMCO DS NIPPLE 390,3 12267 0 0 0 0 2.80 Pup Deposits. 390.4 122 74 0 0 0 0 2.77 Pup Deposits. 390.5 12282 0 0 0 0 2.81 BAKER GBH-22 SEAL ASSEMBLY 390.6 12293 0 0 0 0 2.98 BAKER PBR 390.7 12296 0 0 0 0 2.86 BAKER KBH-22 ANCHOR SEAL ASSEMBLY 390.8 12301 0 0 0 0 3.13 BAKER SAB-3 PERMANENT PACKER 390.9 12302 0 0 0 0 2.85 4.5"X 3.5"CROSS-OVER 391.1 12303 0 0.14 54 2 2.80 Pup Isolated Pitting. Deposits. 391.2 12313 0 0 0 0 2.79 CAMCO D NIPPLE(MILLED TO 2.80) 391.3 12314 0 0 0 0 2,74 Pup Deposits. 391.4 12325 0 0 0 0 3.09 BAKER SOS WLEG IPenetration Body Metal Loss Body Page 1 • PDS Report Cross Sections +4-So Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD Analyst: C.Waldrop Cross Section for Joint 391.1 at depth 12,309.800 ft. Tool speed=45 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=98% Tool deviation=43° 1 Finger=20 Penetration=0.138 in. Isolated Pitting 0.14 in.=54%Wall Penetration HIGH SIDE= UP • • IRS. PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD Analyst: C.Waldrop Cross Section for Joint 388 at depth 12,167.330 ft. Tool speed=44 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=97% eI-----,, Tool deviation=44° I -------------- Finger= 11 Penetration=0.111 in. Isolated Pitting 0.11 in.=44%Wall Penetration HIGH SIDE= UP • PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD Analyst: C.Waldrop Cross Section for Joint 390.2 at depth 12,266.840 Tool speed= 45 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=42° 1 I 1 1 Minimum I.D.=2.698 in. Deposits on DS Nipple Minimum I.D.=2.70 in. HIGH SIDE=UP • • PDS Report Cross Sections Well: 3M-23 Survey Date: March 27,2018 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.218183 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD Analyst: C.Waldrop Cross Section for Joint 386 at depth 12,108.180 ft. Tool speed=45 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% ~� ‘1111 Tool deviation=44° \\\ -, \\N-.. ..--' , Minimum I.D.=2.717 in. Deposits Minimum I.D.=2.72 in. HIGH SIDE=UP 1 KUP PROD Ill 3M-23 ConocoPhillips 4 ---- Well Attributes Max Angle&MD TD Alaska.Inc. Wenbore API/UwI Field Name Wellbore Status ncl(") MD IftKB) Act Btm(ftKB) CnncrriRliaips 500292242600 KUPARUK RIVER UNIT PROD 70.34 11,019.39 12,750.0 ••• Comment 142$(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3M-23,9/3020135;1623 AM SSSV:NIPPLE Last WO: 9/1/2013 41.00 12/29/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,3980 5/31/2013 Rev Reason:PULL PLUG/CATCHER,GLV C/O hipshkf 9/28/2013 HANGER;31.3 Ii l I Casing Strings Casing Description OD(in) 11)(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread ' ' " " SURFACE 95/8 8.535 41.9 5,437,2 3,306.7 53.50 L-80 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) '•Set Depth(TVD)...Wdlen(/...Grade Top Thread PRODUCTION 7 6.276 36.6 12,721.6 6,374.0 26.00 L-80 BTCMODR3 Tubing Strings Tubing Description String Ma...ID tin) Top(ftKB) Set Depth(h..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection j� t -,-TUBING WO 2013 1 31/21 2.9921 31.31 7,536.4] 4,070.01 9.301 L-80 18rd Completion Details CONDUCTOR;43.0-121.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(") Item Des Com (In) I31.3 31.3 0.54 HANGER FMC TUBING HANGER 2.992 516.5 516.5 0.09 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 NIPPLE;515.5 4 7,532.7 4,068.6 68,43 LOCATOR BAKER SEAL ASSEMBLY LOCATOR 2.992 7,5339 4,069.1 68.43'SEAL ASSY BAKER 80-40 SEAL ASSEMBLY(OAL=16.46) 3.000 H. I Tubing Description 'String Ma...'10lin) 'Top(ftKB) Set Depth(ft.. 'sat Depth(TVD)I...Wt(Ibxq Grade 'Top Connection STRADDLE PKR 3 1/2 2.992 7,522.4 12,294.0 6,067.7 9.30 L-80 8RD EUE Mod I 1 ASSY Completion Details GAS LIFT:3.455.8 Nominal ID Top(ftKB) Top(TVD)(ftKB),Top Incl(1) Item Des Com (in) 7,522.4 4,064.8 68.43 SLEEVE HR LINER SETTING SLEEVE 5.250 7,536.4 4,070.0. 68.43 NIPPLE RS PACKOFF SEAL NIPPLE 4.250 7,538.9 4,070.9• 68.42 PBR BAKER 80-40 PER 4.000 7,551.3 4,075.5, 68.39 PACKER BAKER FHL PACKER 2.992 12,267.2 6,048.8 45.02 NIPPLE CAMCO DS NIPPLE 2.81"PROFILE 2.812 SURFACE;41,93,437.2--J 12,282.3 6,059.5 44.94 LOCATOR BAKER LOCATOR 2.992 12,282.5 6,059.6' 44.94 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.000 I: Tubing Description 'String Ma...1 ID(In) 1 Top(ftKB) /Set Depth(ft..1 Set Depth(TVD)I...1 Wt lib/ft) 'Grade 'Top Connection GAS LIFT;7477.3 TUBING Original 5 7/8 4.000 12,283.5 12,325.4 6,090 0 Completion Details Nominal ID Top(ftKB) Top(TVD)(1IKB) Top Incl(1 Item Des Com (in) 12,283.5 6,060.3 44.94 PER BAKER PBR 4.000 I SLEEVE;7,5221 12,296.5 6,069.5 44.88 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 12,297.4 6,070.2 44.87 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 LOCATOR;7,5327 12,302.3 6,073.6 44.85 XO Reducing Cross Over 4.5 x 3.5 2092 SEAL ASSY;7,533.9 IIa---.'I 12,313.4 6,081.5 44.80 NIPPLE CAMCO D'NIPPLE 2.75"PROFILE 2.750 NIPPLE;7,536.4 sm.. 12,324.5 6,089.4 44.76 WLEG BAKER SOS WIRELINE GUIDE 2.992 Perforations&Slots PBR;7.535.8 . Shot Dens Top(TVD) • Btm(TVD) (shofs/f PACKER;7,561.3 Top(ftKB) Btm(ftKB) ..... KB) (ftKB) Zone Date t) Type Co 12,423.0 12,443.0 6,159.8 6,174.2 C-4,3M-23 9/12/2001 4.0 APERF 2 1/8"Enerjet w/PJ chgs, 0 deg ph,+/-90 deg orient 12,450.0 12,466.0 6,179.2 6,190.7 A-2,3M-23 9/7/2001 4.0 APERF 21/8"Enerjetw/PJ chgs, 0 deg ph,+/-90 deg NIPPLE;12,267.2 orient 12,474.0 12,484.0 6,196.5 6,203.7 A-1,3M-23 9/6/2001 4.0 APERF 21/8"Enerjetw/PJ chgs, 0 deg ph,+/-90 deg LOCATOR;12,262,3 -1orient 12,484.0 12,502.0 6,203.7 6,216.6 A-1,3M-23 '4/23/1994 4.0 IPERF 4.5"BH Ultrapak 180 SEAL ASSY;12,252.51 deg ph PER;12,263,5 12,484.0 12,494.0 6,203.7 6,210.9 A-1,3M-23 9/12/2001 4.0 RPERF 2 1/8"Enerjet w/PJ chgs, O deg ph,+/-90 deg SEAL ASSY;12,296.5 !,.1. 1, orient PACKER;12,297.4- ..0,ie'-, Mandrel Details St I all C on Top(TVD) Valve Latch Port Sloe TRO Run o NoTop(ftKB) (10KB) Make Model OD(in) Sere Type Type (In) (psi) Run Date m NIPPLE;12313.4 1 .? 3,485.5 2,596.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,256.0 9/26/2013 2 7,477.3 4,048.3 Camco KBMG 1 GAS LIFT OV BK 0.250 00 9/26/2013 WLEG;12,324.5- li Notes:General&Safety End Date Annotation 7/16/2006 NOTE:WORKOVER-Straddle Packer set to repair casing holes with drill pipe 5/12/2007 NOTE:WORKOVER 11/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 APERF;12,423.0-12,4430- - APERF;12,450.0-12,486.0-4 APERF:12474.0.12,484.0--- ► RPERF;12,484.0.12,494.01-" IPERF;12484.0.12,502.O--..,. .-_. PRODUCTION;36.6-12.721.6 tiOF Ty • Iv ,�� THE STATE• Alaska Oil and Gas ofA LA SKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '' Main: 907.279.1433 OFALAS Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer SCANNED ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field,Kuparuk Oil Pool,KRU 3M-23 Permit to Drill Number: 193-187 Sundry Number: 318-098 Dear Mr. Ohlinger: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of March,2018. gBDMS MAR 212018 RECEIVED • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 9 2018 APPLICATION FOR SUNDRY APPROVALS 3/•? /)g' 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations 0 • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Q , Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q. 193-187 ` 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO Box 100360,Anchorage,AK 99510-0360 50-029-22426-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-23 . Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25524 . Kuparuk River Field/Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 12750' . 6394' , 12635' . 6312' 3229 t� None None Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 121' 121' 1640 670 Surface 5395' 9-5/8" 5437' 3307' 7930 6620 Intermediate Production 12685' 7" 12722' 6374' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12423'-12443' ' 6160'-6174' 12450'-12466' 6179'-6191' 3-1/2" L-80 12325' 12474'-12502' - 6197'-6217' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD(ft)and TVD(ft): . 7551'/4076' Baker SAB-3 Permanent Packer . 12297'/6070' 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 22-Mar-18 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Keith Herring 3/$//$ Authorized Title: Staff CTD Engineer Contact Email: Keith.E.He in ,cop.com 3/`� Contact Phone: 907-263-4321 Authorized Signature: ��� Date: fj COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 093 Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ Other: Tal'P rt.-6I- to 4 l"Go /7 5 t ct ii-vl n vl a r 1—r W T yr -hr k-- -f6 ttrJ 2 D D e 5-1- ,ii lfierncc-ic• p I v 9 dp1cr� r-�t �ppi---e, 1--. vAA- c 25, ; > zCL\ Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: /lj` s 4 Q APPROVED BY Approved by: (C4:2cr— ----�a gg COMMISSIONER/ THE COMMISSION Date: 3 R-t ll� §,D TN3 3/abce Ates 1/77 3/l�Y ( �+}tr ,:ii;Form and 4\1( �N- Form 10-403 Revised 4/2017 Approved applicatlor�iril�siNtAtthe date oariDNIS ch - Duplicate .v • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 06, 2018 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to plug the KRU 3M-23 (PTD# 193-187) by cementing up the perforation to allow CTD operations to drill a quad-lateral out of the KRU 3M-23 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the KRU 3M-23 perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the NC-sand perforations in this manner. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 3M-23 - Operations Summary in support of the 10-403 Sundry Application - Proposed CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 3M-23 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 3M-23 is a Kuparuk A-sand and C-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the A and C sands to the south and west of 3M-23. The laterals will increase throughput and recovery from a potentially sheltered corner of a large up-thrown fault block. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 12309' MD and the "D" nipple at 12313' MD will be milled out to a 2.80" ID. The existing A-sand and C- sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 12470' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 12440' MD. The four laterals will be completed with 2-3/8" slotted liner from TD with the final liner top located inside the 3-1/2" tubing tail. Using the maximum formation pressure in the area of 3837 psi in 3M-23, the maximum potential surface pressure in 3M-23, assuming a gas gradient of 0.1 psi/ft, would be 3229 psi. BOP Test Pressure = 4000 psi 4--- CTD Drill and Complete 3M-23 Laterals: April 2018 Pre-CTD Work 1. RU Slickline: Obtain SBHP, install new GLV design, and pressure test. 2. RU E-line: Punch 2' of holes in the 3W tubing tail at 12309' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M-23A Sidetrack (Al sand - South) a. Drill 2.80" high-side pilot hole through cement to 12470' MD b. Caliper pilot hole c. Set top of whipstock at 12440' MD d. Mill 2.80" window at 12440' MD. e. Drill 3" bi-center lateral to TD of 15925' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 13100' MD. 3. 3M-23AL1 Lateral (Al sand - South) a. Kick off of the aluminum billet at 13100' MD. b. Drill 3" bi-center lateral to TD of 15960' MD. cd �y ,'s'V ccvtiff• Tot frw4Wled f.,-erg%f 44-,71 !? �AIP/r!`td tyi'Tl1 Jot 4.1sC7 7% Pie eferin well bore opo/ r44 .2 cl9"/' oo fee.o er,:y fell /eievv IA 74 C- Page 1 of 2 3/6/2018 c. Run 2•slotted liner with aluminum billet from, up to 12950' MD. 4. 3M-27AL2 Lateral (C4 sand - South) a. Kick off of the aluminum billet at 12950' MD. b. Drill 3" bi-center lateral to TD of 16000' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 12820' MD. 5. 3M-27AL3 Lateral (A1/C4 sand - West) a. Kick off of the aluminum billet at 12820' MD. b. Drill 3" bi-center lateral to TD of 16700' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 12310' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Return to production Page 2 of 2 3/6/2018 f KUP PROD • 3M-23 ConocoPhillips o Well Attributes Max Angle&MD TD AIH51(3 incWellbore API/UWI Field Name Wellbore Status ncl(1) MD(ftKB) Act Btm(ftKB) G....Sf 500292242600 KUPARUK RIVER UNIT PROD ' 7034 11,019.39 12.750.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-23.9/30120135.16x23 AM SSSV:NIPPLE Last 1M0: 9/1/2013 41.00 12129/1993 Venial schematic tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,398.0 5/31/2013 Rev Reason:PULL PLUG/CATCHER,GLV C/O hipshkt 9/282013 HANGER;31 3 . Casing Strings j__j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft)(B) Set Depth(ND)... WELen(I...Grade Top Thread j CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread '"""aaaaa.SURFACE 9 5/8 8.535 41.9 5,437.2 3,306.7 53.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1.1 PRODUCTION 7 6.276 36.6 12,721.6 6,374.0 26.00 L-80 BTCMODR3 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection .. ✓---.TUBING WO 2013 3 1/2 2.992 31.3 7,536.4 4,070.0 9.30 L-80 8rd Completion Details CONDUCTOR:43.0-1210 J. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) - 31.3 31.3 0.54 HANGER FMC TUBING HANGER 2.992 NIPPLE,516.5 516.5 516.5 0.09 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 7,532.7 4,068.6 68.43 LOCATOR BAKER SEAL ASSEMBLY LOCATOR 2.992 7,533.9 4,069.1 68.43 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY(OAL=16.46') 3.000 Tubing Description String Me...ID(in) Top(ftKB) 'Set Depth(ft..Set Depth(ND)(...Wt(I0/ft) Grade Top Connection STRADDLE PKR 31/2 2.992 7,522.4 12,294.0 6,067.7 9.30 L-80 8RD EUE Mod ASSY Completion Details GAS LIF/3.4855 • • Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 7,522.4 4,064.8 68.43 SLEEVE HR LINER SETTING SLEEVE 5.250 7,536.4 4,070.0 68.43 NIPPLE RS PACKOFF SEAL NIPPLE 4.250 1 7,538.9 4,070.9 68.42 PBR BAKER 80-40 PBR 4.000 f I L 7.551.3 4,075.5 68.39 PACKER BAKER FHL PACKER ' 2.992 12,267.2 6,048.8 45.02 NIPPLE CAMCO DS NIPPLE 2.81"PROFILE 2.812 SURFACE 41.9-5.437,2-� 12,282.3' 6,059.5 44.94 LOCATOR BAKER LOCATOR 2.992 • 12,282.5 6,059.6 44.94 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) "Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibfft) Grade Top Connection GAS LIFT.7,477.3 ,y TUBING Original 57/8 4.000 12,283.5 12,325.4 6,090.0 . 'Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 12,283.5 6,060.3 44.94 PBR BAKER PBR 4.000 SLEEVE;7,522.4 I 1- I 12,296.5 6,069.5 44.88 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 12,297.4 6,070.2 44.87 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 LOCATOR,7.532.712,302.3 6,073.6 44.85 XO Reducing Cross Over 4.5 x 3.5 2.992 SEAL ASSY;7,533.9 12,313.4 6,081.5 44.80 NIPPLE CAMCO'D'NIPPLE 2.75"PROFILE 2.750 NIPPLE;7,536.44_ j 12,324.5 6,089.4 44.76 WLEG BAKER SOS WIRELINE GUIDE 2.992 Perforations&Slots PBR:7.538.9 _.. Shot Dens Top(ND) Btm(ND) (shots/f PACKER;7,551.3 41.14 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t( Type Com 12423.0 12,443.0 6,159.8 6,174.2 C-4,3M-23 9/12/2001 4.0 APERF 21/8"Enerjetw/PJchgs, _ Odeg ph,+/-90 deg orient ' 12.450.0 12,466.0 6,179.2 6,190.7 A-2,3M-23 '9/7/2001 4.0 APERF 2 1/8"Enerjet w/PJ chgs, ;_' 0 deg ph,+/-90 deg NIPPLE;12,267.2 orient j 12,474.0 12,484.0 6,196.5 6,203.7 A-1,3M-23 9/6/2001 ' 4.0 APERF 2 1/8"Enerjet w/PJ chgs. O deg ph,+/-90 deg LOCATOR;12.282.3 _ orient -1 12,484.0' 12,502.0 6,203.7 6,216.6 A-1,3M-23 4/23/1994 4.0 (PERF 4.5"BH URrapak 180 SEAL ASSY;12.282.5- F --,. de ph PBR;12.283.5 9 ,.,`,:.1 -71-j, �> 12,484.0 12,494.0 6,203.7 6,210.9 A-1,3M-23 9/12/2001 4.0 RPERF 2 1/8"Enerjet w/PJ chgs, 0 deg ph,+1-90 deg SEAL ASSY;12,296.5il_ orient PACKER:12.297.4- Mandrel Details St ati C on Top(ND) Valve Latch Port Size TRO Run No Top(8613) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m NIPPLE;12.313.4 1 3,485.5 2.596.5 Camco KBMG 1 GAS LIFT 'GLV BK 0.188' 1,256.0 9/26/2013 FF 2 7,477.3 4,048.3 Camco KBMG 1'GAS LIFT OV BK 0.250 0.0 9/26/2013 WLEG;12,324.5 ' A Notes:General&Safety End Date Annotation 7/16/2006 NOTE:WORKOVER-Straddle Packer set to repair casing holes with drill pipe 5/12/2007 NOTE WORKOVER 11)27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 - APERF,12,423.0.12.443.0- APERF,12,450.0.12.466.0- APERF;12,474.0.12,484.0 RPERF;12.484.0-12.494.0,- IPERF.12.484.0612,502.0 ._ PRODUCTION;36.6.12721.6 • • 0 O 2 0 2 a b ONm o ( Orn 2 m� O 22 N NOG Nib.-,, 3 m� -1(0 N > . J T N Npp,, (.aj�m Nq�m C)Vm Gca ' mOOBOO MONO , ,0 ,,,,-,- 1042 F-F- 1N2 1Oao 13onM N a J MOI 6 a , E c N E 0 C_ E N- a-'E N- -N _ Lc) C KS N - 0 in- M N O L� N N N i �� . m @ 2� a� � N S.Z N Q O �@1 3 d Lo�t`\ _Q <I cs4b -a Q cL O V MLs, m C',..-„0, m N i N � C M � _ /�� coW Q Q > C ( t`� a lJ N Q W N O �,` C V CV C• W CO �o a) u) v `—�— x O o a C- m 0 m oTo u w d �`Q co CU J CU N m O n. CU VM OC m E c t s,', \\lk m a m stn ..a-_J m mm 0 3 U ai U 1=L U W Cn U N N N N J N N $U N N N N N r W m m CO m "— M M M 2A mCo M moo MM a w a m z 0 cn o i )1 0 I.I „:::''' r, 1 1,, .ii 0 c CI I 2 O I I cv v o ©O M - 2 �` co V y I@ co d 'C N N c0 0 m a N ( N1m 0 V N #2 '6M Q CON �O _ as co�ti - l'-' V' - a S 'OO� U . N N t• Q Ng m© co_ 0 N • 410 Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist t i61e in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial i iit on both copies of the Form 10-403 (AOGCC's and operator's copies). then Instead, check the "Suspended"box and initial that change. Drilling The drilling engineers will serve as quality control for steps 1 and 2. (QEnCineer C) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, they will enter the Typ_Work code "IPBRD"into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. not see the "Intent: Plug for Redrill"comment or code,Sthey will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ,. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] . Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy TO RE-SCAN ncent Nathan Lowell Date: '("¢-~'~ Is~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si RECEIVED • - AA"OIL AND GSTATE OF AS CON ERV TION COM ION REPORT OF SUNDRY WELL OPERATIONS k F: 2 6 2013 1.Operations Performed: Abandon r Repair w ell F.7 Plug Perforations r Perforate r Oth r Alter Casing E Rill Tubing Stimulate-Frac r Waiver r Time ExterC Change Approved Program rOperat. Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fri Exploratory r 193-187 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22426-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25524 • 3M-23 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 12750 feet Plugs(measured) 12313 true vertical 6394 feet Junk(measured) None Effective Depth measured 12491 feet Packer(measured) 7551, 12297 true vertical 6210 feet (true vertical) 4076,6070 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121 121 SURFACE 5395 9.625 5437 3307 PRODUCTION 12685 7 12722 6374 Perforation depth: Measured depth: 12423-12443, 12450-12466, 12474-12502 NED V E 2 M 2 0 I V True Vertical Depth: 6160-6174,6179-6191,6197-6217 Tubing(size,grade,MD,and ND) 3.5, L-80, 12325 MD,6090 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7551 MD and 4076 ND PACKER-BAKER SAB-3 PERMANENT PACKER @ 12297 MD and 6070 ND NIPPLE-CAMCO DS NIPPLE @ 517 MD and 517 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 209 1189 1612 -- 225 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17- Service r Stratigraphic r 16.Well Status after work: Oil 17- Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey ra'a 263-4773 Email Ian.A.Toomeyconocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature - - Phone:263-4773 Date q .1 s-_ J/? LF /o �� 5 l RBDMS OCT 11 2.� 7/30Rl L" '4'GINA Form 10-404 Revised 10/2012 Submit Original Only i KUP 3M-23 ConocoPhillips S Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status !nei(°) MD(ftKB) Act Btm(ftKB) caoecO/I+sips 500292242600 KUPARUK RIVER UNIT PROD 70.34 11,019.39 12,750.0 ' Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -SSSV:NIPPLE 175 10/12/2011 Last WO: 9/1/2013 41.00 12/29/1993 Well Cantu 3M-23,9/620136.24.13AM __ -- schematic-Actual _- _- --Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,398.0 5/31/2013 Rev Reason:WORKOVER osborl 9/6/2013 HANGER,31 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED ----1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.535 41.9 5,437.2 3,306.6 53.50 L-80 BTC "AIMINIMMM Casing Description String 0... String ID...Top(ftKB) Set Depth(5...Set Depth(ND)...String Wt...String... String Top Thrd 9I PRODUCTION 7 6.276 36.6 12,721.6 6,374.0 26.00 L-80 BTCMODR3 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING WO 2013 31/2 2.992 31.3 7,536.4 4,070.2 9.30 L-80 8rd Completion Details Top Depth CONDUCTOR, (ND) Top Intl Nomi... 43.121 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 31.3 31.3 0.84 HANGER FMC TUBING HANGER 2.992 516.5 516.5 -0.01 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 NIPPLE,516 7,533.9 4,068.6 68.43 LOCATOR BAKER SEAL ASSEMBLY LOCATOR 3.000 Si g P String SEAL ASSY BAKER 80-40 SEAL ASSEMBLY(OAL=16.46') 2.992 Tubing Description 4,068.6 String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd STRADDLE PKR 3 1/2 2.992 7,522.4 12,294.0 6,067.7 9.30 L-80 8RD EUE Mod ASSY casuFT, Completion Details 3485 Top Depth' (ND) Top not Noed... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 7,522.4 4,064.8 68.43'SLEEVE HR LINER SETTING SLEEVE 5.250 Ill 7,536.4 4,070.2 68.78'NIPPLE RS PACKOFF SEAL NIPPLE 4.250 7,538.9 4,071.0 68.74 PBR BAKER 80-40 PBR 4.000 7,551.3 4,075.5 68.54 PACKER BAKER FHL PACKER 2.992 12,267.2 6,048.8 45.00 NIPPLE CAMCO DS NIPPLE 2.81"PROFILE 2.812 S azFt* 12,282.3 6,059.5 44.94 LOCATOR BAKER LOCATOR 2.992 12,282.5 6,059.6 44.94 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.000 GAS LIFT, ___ Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...'Set Depth(ND)...String Wt...String... String Top Thrd Zan `- TUBING Original 57/8 4.000 12,283.5 12,325.4 6,090.0 Completion Details =- Top Depth (ND) Top Inc! Nomi... Top(ftKB) (ftKB) ("1 Item Description Comment ID(in) SLEEVE.7,522 - I 12,283.5 6,060.3 44.93 PBR BAKER PBR 4.000 11111 ■ LOCATOR, tr 12,296.5 6,069.5 44.88 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 1533 __ 12,297.4 6,070.2 44.87 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 ' SEAL ASSY, 7,634 _ 12,302.3 6,073.6 44.85 XO Reducing Cross Over 4.5 x 3.5 2.992 NIPPLE,7,536 - 12,313.4 6,081.5 44.80 NIPPLE CAMCO'D'NIPPLE 2.75"PROFILE 2.750 12,324.5 6,089.4 44.76 WLEG BAKER SOS WIRELINE GUIDE 2.992 PBR'TS3s Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth ° ' (ND) Top Inc! PACKER,7,551 4....Bell Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 12,309.0 6,078.4 44.82 CATCHER 2.72"x 124"CATCHER 7/26/2013 0.000 12,313.4 6,081.5 44.80 PLUG 2.75 CA-2 PLUG 5/31/2013 0.000 11 Perforations&Slots Shot NIPPLE,12,267 I Top(ND) Btm(TVD) Dens Oh-e Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date ( Type Comment LOCATOR, 12,423.0 12,443.0 6,159.8 6,174.2 C-4,3M-23 9/12/2001 4.0 APERF 2 1/8"Enerjetw/PJ chgs,0 deg ph, 1 12,282 +/-90 deg orient SEAL ASSY, 12,450.0 12,466.0 6,179.2 6,190.7 A-2,3M-23 9/7/2001 4.0 APERF 2 1/8"Enerjetw/PJ chgs,0 deg ph, 12,282 PBR,12,283 +/-90 deg orient 12,474.0 12,484.0 6,196.5 6,203.7 A-1,3M-23 9/6/2001 4.0 APERF 21/8"Enerjetw/PJ chgs,0 deg ph, SEAL ASSY, •I'. I +/-90 deg orient 12,296 PACKER, - - 12,484.0' 12,502.0 6,203.7 6,216.6 A-1,3M-23 4/23/1994 4.0 IPERF 4.5"BH Ultrapak 180 deg ph 12,297 12,484.0 12,494.0 6,203.7 6,210.9 A-1,3M-23 9/12/2001 4.0 RPERF 21/8"Enerjet w/PJ chgs,0 deg ph, +/-90 deg orient CATCHER,_ Notes:General&Safety 12,309 End Date Annotation NIPPLE,12,313 'J` - 7/16/2006 NOTE:WORKOVER-Straddle Packer set to repair casing holes with drill pipe PLUG,12,313 - 5/12/2007 NOTE:WORKOVER WLEG,12,325 I It 11m2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 APERF, 12,42312,443 APERF, _-__ 12,450-12.466 Ili APERF, ....-. _-_ 12,474-12.484 RPERF, T °° „,: •3M-23 Pre-Rig Well Work Summary • DATE SUMMARY 5/13/2013 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, FUNCTION TESTED T LDS, CMIT-TXIA PASSED TO 2500 PSI, DDT-TXIA PASSED. 5/29/2013 BAIL 13' OF SCALE OFF TOP OF CA-2 PLUG @ 12,313' RKB. IN PROGRESS 5/30/2013 BAIL SCALE AND PULL CA-2 PLUG @ 12313' RKB. IN PROGRESS. 5/31/2013 TAGGED BTM @ 12,398'SLM(EST.75' OF FILL); MEASURE SBHP (3847 psi)@ 12,418' RKB; SET 2.75" CA-2 PLUG IN D-NIPPLE @ 12,313' RKB (GOOD DRAW DOWN TEST). COMPLETE. 7/24/2013 (PRE RWO)MITOA PASSED TO 1800 PSI. 7/26/2013 SET 2.72"x 124" CATCHER ON CA-2 PLUG @ 12,313' RKB. IN PROGRESS. 7/27/2013 PULLED GLV @ 4208' RKB & REPLACED WITH DV; PULLED DV& LEFT POCKET OPEN @ 7478' RKB. (TURN OVER TO DHD FOR CMIT) IN PROGRESS. 8/3/2013 (PRE RWO)CMIT TXIA PASSED TO 3000 PSI. CDDT TXIA PASSED. • Q ConocoPhillips Time Log & Summary We!Adew Web Reporting Report Well Name: 3M-23 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/28/2013 5:30:00 PM Rig Release: 9/1/2013 7:30:00 PM Bate r Torn To =m Dur =.: S. Depth E "f3eoth Phase Code �u code T omrhent to �"kk�, s 08/18/2013 24 hr Summary Move Nordic 3 from 3N to 3M pad on malts 16:30 00:00 7.50 MIRU MOVE MOB P Move Nordic 3 from 3N-08A to 3M pad on malts. Rig move=.5 miles from N pad currently 38/19/2013 Moved rig from 3N pad to Oliktok Y.load and move matting to CPF3 unload and set mats. 00:00 17:00 17.00 MIRU MOVE MOB P continue to move Nordic 3 to Oliktok Road. 17:00 00:00 7.00 MIRU MOVE OTHR P Load and Truck rig mats from 3N-Access to CPF-3. While the rig sits on standby.02:00 hrs began move to CPF 3 38/20/2013 Move rig to Oliktok road. Momentarily detained due to insufficient road structure. Continue to move rig after back on mats. 00:00 03:00 3.00 MIRU MOVE MOB P Continue to move rig down Oliktok road.to CPF-3. 03:00 09:00 6.00 MIRU MOVE OTHR T Roadway gave out 1 mile from 3N turn off. Wait on matting. Attempt to solidify road with dunnage to support matting material. Operation failed due to soft foundation. 09:00 13:00 4.00 MIRU MOVE OTHR T Call out dozer @ 09:00 hrs, on location @ 11:30-rig up on mats @ 13:00 hrs. Rig down dozer and release. 13:00 20:00 7.00 MIRU MOVE OTHR P Lay mats in front of rig to the 3C pad access 20:00 21:00 1.00 MIRU MOVE MOB P Road rig to within 3/10's of a mile from 3C Pad entrance. 21:00 00:00 3.00 MIRU MOVE OTHR P Shuffle mats in front of rig and lay to 3C Pad entrance 38/21/2013 Continue to lay mats to 3C pad access. Road rig to 3C access.Allow traffic to pass and continue to shuffle mats. Road rig to CPF 3.Shuffle mats again. 00:00 00:30 0.50 MIRU MOVE OTHR P Continue to shuffle mats to 3C pad access. 00:30 01:30 1.00 MIRU MOVE MOB P Road rig to 3C access road. 01:30 02:30 1.00 MIRU MOVE OTHR P Spot transition mats and allow traffic to pass. 02:30 11:00 8.50 MIRU MOVE OTHR P Shuffle mats down the road 11:00 12:00 1.00 MIRU MOVE MOB P Road rig down the road on mats.5 miles from CPF3 12:00 16:00 4.00 MIRU MOVE OTHR P Shuffle mats to CPF3 16:00 18:00 2.00 MIRU MOVE MOB P Road rig down road to CPF3 intersection on mats. Page 1 of;8 466'6 3bilf:' 411" OPPL,t -111111110' Date , From , To 1h Pi°6 Dtir S.;Deotli :E Depth Phase Code Sobcode'rll'IT Comment ,J1011111'19 18:00 19:00 1.00 MIRU MOVE OTHR P Allow traffic to pass at CPF3 intersection. 19:00 22:30 3.50 MIRU MOVE OTHR P Shuffle mats past CPF3 intersection 22:30 23:00 0.50 MIRU MOVE MOB P Move rig past CPF3 23:00 00:00 1.00 MIRU MOVE OTHR P Begin to shuffle mats down to 3B intersection 08/22/2013 Continue to shuffle mats and move rig towards 3M pad 00:00 04:00 4.00 MIRU MOVE OTHR P Continue to shuffle mats to the 3B intersection 04:00 05:00 1.00 MIRU MOVE MOB P Move rig on mats from CPF3 to 3B intersection 05:00 10:30 5.50 MIRU MOVE OTHR P Shuffle mats from the 3B intersection down road towards 3M 10:30 11:00 0.50 MIRU MOVE MOB P Road rig 3B access to Caibou crossing+.1 mile 11:00 13:00 2.00 MIRU MOVE OTHR P Shuffle Mats to caribou crossing 13:00 13:30 0.50 MIRU MOVE MOB P Back up.1 mile to caibou crossing 13:30 16:30 3.00 MIRU MOVE OTHR P Shuffle Mats around to front of rig 16:30 17:30 1.00 MIRU MOVE MOB P Move rig on mats to 31 access 17:30 22:00 4.50 MIRU MOVE OTHR P Shuffle rig mats 22:00 22:30 0.50 MIRU MOVE MOB P Move rig on mats forward to be able to double stack 22:30 00:00 1.50 MIRU MOVE OTHR P Double stack mats behind rig then back up over them 38/23/2013 Continue to shuffle mats and move rig towards 3M pad, Safety stand down with Toolhouse. 00:00 05:00 5.00 MIRU MOVE OTHR P Unstack mats and lay in front of rig 05:00 05:30 0.50 MIRU MOVE MOB P Road rig 8/10ths of a mile from 31 access 05:30 17:00 11.50 MIRU MOVE OTHR P Shuffle mats and back up on triples 17:00 20:30 3.50 MIRU MOVE SFTY P Safety stand down with drilling tool house. 20:30 21:30 1.00 MIRU MOVE OTHR P Shuffle rig mats to triples 21:30 23:00 1.50 MIRU MOVE MOB P Move rig backwards on mats 23:00 00:00 1.00 MIRU MOVE OTHR P Shuffle mats in front of rig 08/24/2013 Continue to shuffle mats and move rig towards 3M pad on the 3I/3M pad access. 00:00 00:30 0.50 MIRU MOVE OTHR P Cont. lay mats in front of rig 00:30 01:00 0.50 MIRU MOVE MOB P Move rig forward on mats 01:00 05:30 4.50 MIRU MOVE OTHR P Shuffle mats triple stacking 05:30 06:00 0.50 MIRU MOVE MOB P Move rig back over mats 06:00 09:00 3.00 MIRU MOVE OTHR P Move mats in front of rig towards 3M 09:00 09:30 0.50 MIRU MOVE MOB P Move rig on mats towards 3M/31 09:30 12:00 2.50 MIRU MOVE OTHR P Shuffle mats behind rig triple stacking Page2of8 Tfine Logs Date;. 11l11!i0 =x From' o DurRom S Depth ,,E Depth Phase Code Subcode t1t Comment.. °j llhi 12:00 13:00 1.00 MIRU MOVE MOB P Move rig back and shuffle mats in front 13:00 13:30 0.50 MIRU MOVE MOB Move rig to 3M/3I access road and set down 13:30 19:00 5.50 MIRU MOVE OTHR P Move mats around rig and place on 3M/31 access road 19:00 20:00 1.00 MIRU MOVE MOB P Move rig down 31 access road toward 3M on mats 20:00 23:00 3.00 MIRU MOVE OTHR P Triple stack mats behind the rig 23:00 00:00 1.00 MIRU MOVE MOB P Move rig back over triple stacked mats while shuffling. 08/25/2013 00:00 01:30 1.50 MIRU MOVE MOB P Cont. Back rig up on triple stacked mats. 01:30 05:00 3.50 MIRU MOVE OTHR P Shuffle and lay mats in front of rig on 31 access pad to 3M 05:00 05:30 0.50 MIRU MOVE MOB P Move rig down 31 access pad on mats 05:30 11:30 6.00 MIRU MOVE OTHR P Shuffle mats stacking triple behind rig, move rig back and shuffle mats in front. 11:30 12:00 0.50 MIRU MOVE MOB P Move rig forward down 3I access pad 12:00 17:00 5.00 MIRU MOVE OTHR P Shuffle mats behind rig, move rig back,shuffle mats in front 17:00 17:30 0.50 MIRU MOVE MOB P Move rig forward on 31 access road 17:30 20:00 2.50 MIRU MOVE OTHR P Shuffle mats behind rig 20:00 21:00 1.00 MIRU MOVE MOB P Move rig back on triple stacked mats 21:00 23:00 2.00 MIRU MOVE OTHR P Shuffle mats in front of rig 23:00 23:30 0.50 MIRU MOVE MOB P Move rig forward on 31 access pad 23:30 00:00 0.50 MIRU MOVE OTHR P Shuffle mats behind rig X8/26/2013 Continue to shuffle mats and move rig towards 3M pad on the 3M pad access road. 00:00 01:00 1.00 MIRU MOVE OTHR P Continue to shuffle mats behind the rig and back up 01:00 02:00 1.00 MIRU MOVE OTHR P Shuffle mats in front of rig to 31 pad 02:00 02:30 0.50 MIRU MOVE MOB P Move rig onto 31 pad 02:30 07:30 5.00 MIRU MOVE OTHR P Shuffle mats to 3M pad access from 31 07:30 08:00 0.50 MIRU MOVE MOB P Move rig ahead on 3M access road 08:00 15:00 7.00 MIRU MOVE OTHR P Shuffle mats behind rig, back up and shuffle mats infront of rig 15:00 15:30 0.50 MIRU MOVE MOB P Move rig forward toward 3M 15:30 18:00 2.50 MIRU MOVE OTHR P Shuffle mats behind rig and move back 18:00 20:00 2.00 MIRU MOVE OTHR P Shuffle mats in front of rig 20:00 21:00 1.00 MIRU MOVE MOB P Move rig forward to 3M 21:00 00:00 3.00 MIRU MOVE OTHR P Shuffle mats behind rig Page of!$ 144.--Logs •, 4: ,:,a • • 1 ' �p�r � ikki ��� �� �" i; z Date . from''°To Dur «S.Depth E.Depth Phase Code '` Subcbde hT Comment 08/27/2013 24 hr Summary Shuffle mats in front of rig on the 3M access pad,double matting in the low areas. 00:00 02:00 2.00 MIRU MOVE OTHR P Continue to shuffle mats behind the rig 02:00 03:00 1.00 MIRU MOVE MOB P Back rig over mats and begin lay out in front 03:00 05:30 2.50 MIRU MOVE OTHR P Lay mats out in front of the rig 05:30 06:00 0.50 MIRU MOVE MOB P Continue to move rg on mats down 3 M access road 06:00 11:30 5.50 MIRU MOVE OTHR P Shuffle mats behind rig moved rig back shuffle mats in front of rig 11:30 12:00 0.50 MIRU MOVE MOB P continue rig move to 3M on mats 12:00 15:00 3.00 MIRU MOVE OTHR P Shuffle mats behind rig, move rig back shuffle mats out front 15:00 15:30 0.50 MIRU MOVE MOB P Move rig forward on double mats toward 3M 15:30 17:30 2.00 MIRU MOVE OTHR P Shuffle mats behind rig, move rig back 17:30 20:00 2.50 MIRU MOVE OTHR P Shuffle mats in front of rig,check tires 20:00 20:30 0.50 MIRU MOVE MOB P Move rig forward on double mats 20:30 22:00 1.50 MIRU MOVE OTHR P Shuffle mats behind the rig 22:00 22:30 0.50 MIRU MOVE MOB P Move rig back 22:30 00:00 1.50 MIRU MOVE OTHR P Shuffle mats in front of the rig 08/28/2013 Shuffle mats in front of rig on the 3M access pad and to the front of the well,double matting in the low areas. Lay mats around the cellar and herculite.Spot rig and accept at 17:30 hrs. Berm up rig and conduct pre-spud meeting.Take on fluid to the pits. 00:00 01:00 1.00 MIRU MOVE OTHR P Shuffle mats behind the rig triple stacking 01:00 02:00 1.00 MIRU MOVE MOB P Move rig back over triple stacked mats 02:00 03:30 1.50 MIRU MOVE OTHR P Move mats in front of rig 03:30 04:00 0.50 MIRU MOVE MOB P Move rig down the road on double mats towards 3M pad 04:00 06:00 2.00 MIRU MOVE OTHR P Shuffle mats triple stacking behind the rig 06:00 09:30 3.50 MIRU MOVE OTHR P moved rig back and shuffled mats forwrd 09:30 10:00 0.50 MIRU MOVE MOB P moved rig towrds 3M pad on mats 10:00 12:00 2.00 MIRU MOVE OTHR P shuffle mats behind rig, back up rig, shuffle mats forwrd 12:00 12:30 0.50 MIRU MOVE MOB P Move rig onto 3M pad 12:30 14:30 2.00 MIRU MOVE OTHR P Shuffle mats in front of rig to well 14:30 16:00 1.50 MIRU MOVE MOB P Lay out Herculite set T mats berm cellar MIRU, hang tree in cellar 16:00 16:30 0.50 MIRU MOVE OTHR P Lay mats in front of rig to well 16:30 17:30 1.00 MIRU MOVE MOB P Move rig over well,spot and level,set rig down.Accept rig on 3M-23. 17:30 21:00 3.50 MIRU MOVE RURD P Spot support equipment and rig up hoses in the cellar. Paw 4 of t3 Date 3= From T.o Dur ©ath E.DePth Phase Code Subcode Comment ,P Ali 11H'.I �. 21:00 22:30 1.50 MIRU MOVE RURD P Spot cuttings tank and berm up. 22:30 23:00 0.50 MIRU RPCOM SFTY P Pre-spud meeting 23:00 00:00 1.00 MIRU RPCOM KLWL P Load Pits with 9.6#Brine 08/29/2013 Pull BPV. Rig up hard line.Test Lines. Kill well with 9.6ppg brine. 30min flow check good. Set BPV. N/D tree. Install blanking plug. N/U BOP. Shell test. Notify AOGCC representative,waived witness. Begin Test BOP. 00:00 02:30 2.50 7,539 7,539 COMPZ WHDBO MPSP P PJSM, pick up lubricator and test to 1,000psi. Pull FMC ISA BPV. 100psi on tubing 100psi on IA 200psi on OA Lay down lubricator 02:30 06:00 3.50 7,539 7,539 COMPZ WELLPF KLWL P Rig up berming and liner for kill tank. Pressure test rig surface lines to 3,000psi Spot kill tank. Rig up hard line. Dress fluid in pits to 9.6ppg. 06:00 09:30 3.50 7,539 7,539 COMPZ WELLPF KLWL P Continue to hook up steel line to kill tank PT w/air. PJSM&review pre spud. PT(Kill line to 250/3000. 09:30 11:00 1.50 7,539 7,539 COMPZ WELCTL CIRC P SIP Tubing=40 psi, IA=80 psi. SPR=70 psi @ 1 BPM, 150 psi @ 2 BPM. ICP=400 psi @ 4 BPM FCP=550 PSI. Pumped 312 BBLS of 9.6#brine 11:00 13:30 2.50 7,539 7,539 COMPZ WELCTL OWFF P Monitor well for flow 30 min's small flow SWI monitor for 15 min's small flow up IA flow stoped tbg began small flow. let well equalize out. 13:30 14:00 0.50 7,539 7,539 COMPZ WHDBO MPSP P Set BPV drain tree.and lines. BD kill line 14:00 15:00 1.00 7,539 7,539 COMPZ WHDBO NUND P ND tree,verify hanger threads OK. Install blanking plug. 15:00 19:00 4.00 7,539 7,539 COMPZ WHDBO NUND P NU BOPE and install lines. Function test rams,annular&HCR. Page 5of8 'Time Logs 1111 '; � 'Date!it''th' ",,Fromt To Dur+ ` ° S.Death E Death Phase Code ibcode T Comment .iill' 19:00 21:30 2.50 7,539 7,539 COMPZ WHDBO PRTS P Fill stack and purger air from choke manifold. Atttempt to perform shell test on BOP stack. Choke line leak on Graylok connection. Change out clamp and re-test,still leaking. Blow down line and change out gasket. Found 1/2"NPT port on blind flange with a plug on spacer spool below Lower Pipe Rams above the DSA. Change out for non ported blind flange. Fill stack and purge air from choke manifold. Solid test at 250/3000psi. Notify State Rep.John Crisp.Waived State right to witness @21:30hrs. 21:30 00:00 2.50 7,539 7,539 COMPZ WHDBO BOPE P Test BOP as follow; 1-Blind Rams, Kill line, UKV, Dart Valve,Choke valves 4,11,12- 250/3000Pass 2-LKV, FOSV, Choke valves, 3,7,9,10-250/3000 Pass 3-3 1/2"EUE FOSV, Choke valves 2,5,8-250/3000 Pass 4-Lower Pipe Rams 2 7/8"x5"with 3 1/2"joint 250/3000 Pass 38/30/2013 Continue to test BOP. Change out choke and kill HCR. Complete BOP test. Pull blanking plug and BPV. M/U landing joint and pull hanger to floor. Reverse circulate 2 tubing volumes. Flow check. Lay down hanger and lay down tubing. 00:00 03:00 3.00 7,539 7,539 COMPZ WHDBO BOPE P Continue to test BOP. 5-*Upper pipe rams 2 7/8"x 5"with 3 1/2"joint, manual kill, Choke HCR- Fail(Choke HCR)* 6-Upper pipe rams 2 7/8"x 5"with 3 1/2"joint, manual kill, manual choke- 250/3000 Pass 7-*Upper pipe rams 2 7/8"x 5"with 3 1/2"joint, HCR kill, manual choke- Fail(Kill HCR)* *Rig on Zero Rate at 03:00 for going over 12 hrs. allotted for N/U and testing BOP.* 03:00 04:30 1.50 7,539 7,539 COMPZ WHDBO BOPE P 8-Annular w/3 1/2"Test Joint, Manual Kill,choke valves 2,5,6. -250/3000 Pass 9-Choke valve#1 -250/3000 Pass *Rig on Zero Rate at 03:00 for going over 12 hrs.allotted for N/U and testing BOP.* Page of 8 Time Logs �' I, IDate From To Dur S. Der fh``£.i epth P1-iase ` Code ° Subcode T x Comment.. �1 r9liM glliGim 04:30 13:30 9.00 7,539 7,539 COMPZ WHDBO OTHR T JSA-Change out Kill HCR and rebuild Choke HCR. *Rig on Zero Rate at 03:00 for going over 12 hrs.allotted for N/U and testing BOP.* Continue to work on HCR valves Test Choke&kill HCR 250/3000 Psi Passed . Complet accumulator draw down. In. Psi 2950.final 1800 psi . 11 sec.200 psi drop.full closure 85 seconds. Nitogen X 4 1950 psi. 13:30 16:00 2.50 7,539 COMPZ WHDBO MPSP P PJSM pump out BOP pull blanking plug checked for traped pressure under BPV 16:00 17:00 1.00 COMPZ WELLPF PACK P Install lifting jt. PJSM BOLDS pick up on production tubing. UP WT= 83K seal free. 17:00 17:30 0.50 7,500 7,530 COMPZ WELLPF CIRC P Reverse circulated 150 BBLs of 9.6 Brine @ 5 BPM @ 530 psi 17:30 18:00 0.50 7,500 COMPZ WELLPF OWFF P Monitor well for flow. 30 min's 18:00 19:00 1.00 7,547 7,547 COMPZ WELLPF PULD P Laid down hanger, Prep pipe shed for laying down 19:00 00:00 5.00 7,547 2,340 COMPZ RPCOM PULD P Lay down 3 1/2"tubing string. Monitor hole displacement on the trip tank. Watching condition of pipe for corrosion. 38/31/2013 Continue to lay down tubing. Pick up and rack back pipe while waiting on longer seal assembly. Make up 3 1/2"completion assembly and trip in hole. Locate PBR and space out. Circulate corrosion inhibitor around. 00:00 03:00 3.00 2,340 0 COMPZ RPCOM PULD P Continue to lay down 3 1/2" completion. Monitor displacement on the trip tank. Slight corrosion on collars of pipe at 7126'to 7406' Slight corrosion on collars and tubes 7406'to 7529' 03:00 04:30 1.50 0 0 COMPZ RPCOM OTHR P Clean rig floor,empty pipe shed. Bring completion equipment in shed. 04:30 07:00 2.50 0 0 COMPZ RPCOM PUTB P Pick up tubing and rack back in derrick while waiting on longer seal assembly. 07:00 10:00 3.00 0 0 COMPZ RPCOM OTHR T Wait on corrected length seal assembly from Baker 10:00 21:00 11.00 0 7,536 COMPZ RPCOM PUTB P Made up Seal assembly and RIH with 3 1/2"completion equipment. Page 7 of " F Time„Lio g Q ao r�ioa f Date 7 aFromm ToP I'"SID°ur` ;ii S.Deofii E.Depth Phase Code Subcode T Comment s , 21:00 22:30 1.50 7,536 7,552 COMPZ RPCOM HOSO P Engage charge pump,slack of and pressure up at 7539'mule shoe depth. Open bleeder and slack off no go out 7552.86'mule shoe depth(7536.4 No Go locator depth). Pick up and slack back off with bleeder open,set 10k and verify. Verify length needed for space out pups at 12.12'for 3'space out on seals. Lay down joints 241,240,239. Pick up 2-pups 8.12,4.05 joint 239, hanger&landing joint. 22:30 00:00 1.50 7,532 7,532 COMPZ RPCOM CRIH P Reverse circulate 30bbls of 9.6 brine. 180bbls of 9.6 brine with 1%by volume of Baker Petrolite CRW-132. Chase with 30bbls of 9.6 brine 09/01/2013 Drain stack and land hanger 00:00 01:00 1.00 7,548 7,548 COMPZ RPCOM THGR P Drain stack and land tubing hanger. Up weight 85k Dn weight 60k Block weight 35k RILDS 01:00 02:30 1.50 7,548 7,548 COMPZ RPCOM PRTS P Rig up to test tubing and IA. Attach kill line to IA. Rig up isolation valves on tubing. 02:30 04:00 1.50 7,548 7,548 COMPZ RPCOM PRTS P Pressure test Tubing to 3000psi 30 min-Good Bleed Tubing to 2000psi Pressure test IA 2500psi(Monitor OA during test)-Good Bleed off IA then Tubing. Pressure up on IA and shear SOV @ 1650psi. 04:00 04:30 0.50 7,548 7,548 COMPZ WHDBO MPSP P Set BPV and test from below to 1000psi for 10min 04:30 08:00 3.50 7,548 7,548 COMPZ WHDBO NUND P JSA-Nipple down BOP 08:00 10:00 2.00 7,548 7,548 COMPZ WHDBO NUND P NU up companion flange and tree 10:00 13:00 3.00 7,548 7,548 COMPZ WHDBO PRTS P Pull BPV and install test plug. Pressure test adaptor and tree to 250/5000 psi good test. 13:00 13:30 0.50 7,548 7,548 COMPZ WHDBO MPSP P pull tree test plug. 13:30 17:30 4.00 7,548 7,548 COMPZ WHDBO FRZP P PJSM RU LRS to pump 70 bbls of diesel down IA and let equalize with tubing. 17:30 19:30 2.00 7,548 7,548 COMPZ WHDBO PLUG P Set PBV and clean cellar area. Secure tree and well head. Release rig from 3M-23 at 19:30 hrs 9/1/2013. Move to 3M-22 Page 8of t JUN 1 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONgAlaska Oil & Gas Cons. Commission STATE OF ALASKA . RECEIVED . . 1. Operations Performed: Abandon D Repair Well 0 " Plug Perforations D Stimulate D Other -D" -g' Alter Casing D Pull Tubing 0· Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0' Exploratory D 193-1871 , 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22426-00 , 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' -' 3M-23 , 8. Property Designati.on: 10. Field/Pool(s): ADL 25524, ALK 2655 Kuparuk River Field 1 Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 12750' -" feet true vertical 6394' ð feet Plugs (measured) Effective Depth measured 12491 ' feet Junk (measured) true vertical 6210' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5405' 9-5/8" 5437' 3307' PRODUCTION 12690' 7" 12721' 6374' - Perforation depth: Measured depth: 12423'-12443', 12450'-12466', 12474'-12502' i~NED JU~~ 2 6 lfJPl true vertical depth: 6160'-6174',6179'-6191',6197'-6217' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12325' MD. Packers & SSSV (type & measured depth) pkr= Baker 7" retriev. Pkr, BAKER SAB-3 PACKER pkr= 7551', 12297' Nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: RBDMS 8FL JUN I 9 2D07 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation SI . Subsequent to operation 158 / 97 3017 -" -- 139 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development 0' Service D Daily Report of Well Operations _X 16. Well Status after work: Oil0 . GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Jill Long @ 265-1102 Printed Name Jill Long Title Wells Group Engineer / Signature C)¡J J, (/) óYl1JL Phone :¿~5..-JJO:t Date Oft? /2/07 PreDared bv Sharon AI/<un-Drake 263-4612 U ~a IJ Form 10-404 Revised 04/2006 0 R \ G \ N A L 11"~{tN. s&i~17 ~O &._/'-07 ConoccrPhiiii ps Time Log Summary WelMew Weó Reporting Well Name: 3M-23 Job Type: RECOMPLETION 05/08/2007 13:00 00:00 11.00 MIRU MOVE DMOB PJSM, commence move Nordic rig 3 off 1D-131. wait on charter jets to complete land 1 takeoff, resume move to 3M-23. 05/09/2007 00:00 06:30 6.50 MIRU MOVE MOB P Cont. move Nordic 3 (1 D-131 to 3M-23). 06:30 09:00 2.50 MIRU MOVE PSIT P Spot rig over well, center 1 level. RU, prep for workover. Accept Nordic Rig 3, this date 5/9/07, 0630 hrs. 09:00 10:30 1.50 COMPZr RPCOII. RURD P Make top drive connections, lay hardlines. 10:30 12:00 1.50 COMPZr RPCOII. OTHR P PJSM, MU lubricator, pull BPV. 20 psi tbg 110 psi csg. 12:00 14:30 2.50 COMPZr RPCOII. RURD P PJSM, RU kill manifold 1 test same 5000 psi. 14:30 16:00 1.50 COMPZr RIGMN SVRG P PJSM, slip ¡cut drlg line. 16:00 18:30 2.50 COMPZr WELCT COND P PJSM, take WO fluids to pits, condition same. 18:30 20:30 2.00 COMPZI WELCT CIRC P Pump down annulus 35 bbls. (Retrieve diesel out of tbg.)Circ. down tbg. & clean diesel out of annulus-circ. well clean. 20:30 21:00 0.50 COMPZI WELCT OTHR P Monitor well. Set BPV. 21:00 22:00 1.00 COMPZI WELCT NUND P Nipple down tree & inspect hanger threads. 22:00 00:00 2.00 COMPZI WELCT NUND P Nipple up BOPE 11" 5k. 05/10/2007 00:00 01:00 1.00 COMPZI WELCT NUND P Cont NU BOPE. 01:00 05:00 4.00 COMPZr WELCT BOPE P PJSM, test BOPE, all components, floor 1 top drive equip 250 14000 psi. All tests successful, no re-tests Witness waived Mr Bob Noble AOGCC. 05:00 06:30 1.50 COMPZ~ WELCT BOPE P RD test equip, pull plug ¡ BPV, clear floor. 06:30 07:00 0.50 COMPZ~ RPCOII. CIRC P PJSM, MU Idg jt, pull tbg hgr to floor. 95K to pull. No drag. No indication seals pull free. 07:00 08:00 1.00 COMPZ~ RPCOII. PULD P Flow check, circ wellbore clean. No (:Jain 1 loss 1 gas. 08:00 08:30 0.50 COMPZ~ WELCT OWFF P Flow check, monitor well. Well static. . 05/10/200708:30 21:00 12.50 COMPZr RPCOII. PULD P PJSM, commence POH laying dn 3-1/2 tbg. Strap, inspect, record all abnormal conditions, scale 1 pits 1 holes. Note hole jt #285 (3300 ft) approx 1/2" in diameter. Abnormal scaling O.D. tube. 1000 ft before 1 after this depth. Remainder good condition. 21:00 21:30 0.50 COMPZI RPCOII. OTHR P Clean rig floor. 21:30 23:00 1.50 COMPZ RPCOII. OTHR P Rack & Tally 140 jts. 3.5" Tbg. 23:00 00:00 1.00 COMPZ~ RPCOII. RCST P PJSM=Topic-Running tbg. Make up Seal assemblv. 05/11/2007 00:00 04:00 4.00 COMPZt RPCOII. PULD P RIH 3-1/2 tbg from mast 1 GLMs to 3300 ft. 04:00 07:00 3.00 COMPZt RPCm PULD P Begin PU 3-1/2 in singles from pipe shed to 7014 ft. 07:00 09:00 2.00 COMPZt WELCT EQRP P MU Baker storm pkr 1 RIH same to 100 ft. 7000 ft 3-1/2 tbg below pkr. Set pkr 1 test 2000 psi 115 min. Test successful, no re-tests. 09:00 11:00 2.00 COMPZ WELCl EQRP P Commence ND BOPE 1 tbg hd for ! packoff repairs. Remove tbg head. 11:00 14:00 3.00 COMPZ WELCT EQRP P Repair tbg hd. Install new packoffs. Re-install tba hd, test same. 14:00 17:00 3.00 COMPZr WELCT EQRP P PJSM, NU BOPE 17:00 18:00 1.00 COMPZr WELCT EQRP P PJSM, test BOPE following NU, 2501 4000 psi. 18:00 19:30 1.50 COMPZr WELCT EQRP P PJSM, release storm pkr, pull to surface, LD same. 19:30 20:00 0.50 COMPZr RPCOII. RCST P RIH wI 3.5" tbg. from 7014' to 7514'. 20:00 21:30 1.50 COMPZr RPCOII. OTHR P Locate seals & space out. 21:30 22:30 1.00 COMPZI RPCOII. OTHR P Make up hanger & landing jt. rig up hoses to pump seawater. 22:30 00:00 1.50 COMPZ RPCOII. CIRC P Pump 66 bbls seawater down annulus @ 3 bpm. followed wI 200 bbls. corrosion inhibited seawater. 05/12/2007 00:00 02:30 2.50 COMPZ~ RPCOI\ HOSO P Land hanger-RILDS-PT Tbg. 2500 15 mins. chart same. Bled tbg. to 1500-PT annulus 2500 30 mins. OK. Shear out valve. 02:30 03:30 1.00 COMPZr RPCOII. OTHR P Rig down test lines & set BPV. 03:30 05:30 2.00 COMPZt RPCOII. NUND P Nipple down BOPE. 05:30 06:30 1.00 COMPZ RPCOII. NUND P Nipple up Tree. 06:30 08:00 1.50 COMPZI RPCOII. SFEQ P PJSM, test prod tree, all tree adapter 1 hgr seals 250/5000 psi 115 min. All tests successful. No re-tests. 08:00 11:30 3.50 COMPZr RPCOII. FRZP P PJSM, freeze protect well to 3222 ft. FCP = 1400 psi at 2 bpm. Allow"U" tube to balance. Monitor well. 05/12/200711:30 12:00 0.50 DEMOB MOVE DMOB P PJSM, Rig dn, move off 3M-23. NORDIC RIG 3 RELEASED THIS DATE 5/12/07 1200 HRS. . . ConocoPhillipS Alaska, ¡Inc. KRU 3M-23 API: 500292242600 Well Tvpe: PROD Anole (cj) TS: 44 deo (cj) 12409 TUBING SSSV Type: NIPPLE Orig 12/29/1993 Angle @ TD: 44 deg @ 12750 (0-12283, 00:3.500, Completion: 10:2.992) Annular Fluid: Last W/O: 5/12/2007 Rev Reason: WORKOVER Reference Log: Ref Loo Date: Last Update: 6/9/20Œ Last Tao: 12491' RKB TD: 12750 ftKB LastTaa Date: 4/4/2000 Max Hole Anole: 70 deo (cj) 11019 ¡11ì-:.~Îr:I¡llrl¡II!!I.S'iií····' Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE 9.625 0 3306 2530 53.50 J-55 BTC PRODUCTION 7.000 0 12721 6374 26.00 L-80 BTC-MOD SURFACE 9.625 3306 5265 3246 36.00 J-55 BTC SURFACE 9.625 5265 5349 3276 53.50 L-80 BTC-MOD SURFACE 9.625 5349 5437 3307 36.00 J-55 BTC LEAK 7.000 7695 7728 4141 26.00 L-80 BTC-MOD LEAK 7.000 9214 9275 4710 26.00 L-80 BTC-MOD JØlin/' Size Top I Bottom I TVD Wt I Grade I Thread 3.500 0 I 12283 I 6060 9.30 I L-80 I EUE 8RD I 3.500 12283 I - I 6090 9.30 I L-80 EUE 8RD I - IIIQII";' :.. Interval TVD Zone Status Ft SPI Date Type 12423 - 12443 6160 - 6174 C-4 20 4 9/12/200 1 APERF 21/8" Enerjetw/PJ chgs, 0 dea ph, +1- 90 dea oriert ~ U 12450 - 12466 6179- 6191 A-2 16 4 9/7/2001 APERF 2 1/8" Enerjet w/P J chgs, 0 deo ph, +/- 90 dea oriert 12474 - 12484 6197 - 6204 A-1 10 4 9/6/2001 APERF 2 1/8" Enerjet w/PJ chgs, 0 deo ph, +/- 90 deo oriert 12484 - 12494 6204 - 6211 A-1 10 8 9/12/200 1 RPERF 2 1/8" Enerjet w/PJ chgs, 0 deo ph, +/- 90 deo oriert 12494 - 12502 6211 - 6217 A-1 8 4 4/23/1934 IPERF 4.5" BH Ultrapak 180 deg I":, ph ,,-o- II ._1'111111' 51 MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt I 1 4208 2860 CAMCO KBUG GLV 1.0 BK 0.250 1340 5/16/2007 2 7478 4049 CAMCO KBUG OV 1.0 BK 0.250 0 5/16/2007 Depth TVD Tvpe Description ID iIII 31 31 HANGER GEN IV TUBING HANGER 3.500 ~ 512 512 NIP 2.875 7531 4068 LOCATOR BAKER LOCATOR wINO GO RING ON THE BOTTOM 2.990 7533 4069 SEAL BAKER 80-40 SEAL ASSEM BL Y 2.990 : iIII 12267 6049 NIP CAMCO DS NIPPLE 2.812 12282 6059 LOCATOR BAKER LOCATOR 3.000 12283 6060 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 ¡.~l!iíril~¡¡II. Depth TVD Tvpe Description ID 7522 4065 SLEEVE HR LINER SETTING SLEEVEw/NO GO OD 5.79", ID 4.42" 4.420 7536 4070 NIP BAKER RS PACK-OFF SEAL NIPPLE 4.250 7539 4071 PBR BAKER 80-40 PBR 4.250 LOCATOR 7551 4075 PACKER BAKER 7" RETRIEVABLE 2.930 12282-12283, g.BI :RIØøli¡¡I.li.lè~ø~¡~¡¡IIi'.ItII~.....I;' 00:4.250) Depth TVD Type Description ID TUBING 12282 6059 PBR BAKER 80-40 2.992 12283-12325, 12283 6060 ANCHOR BAKER KBH-22 K-ANCHOR 3.000 00:3.500, 12297 6070 PKR BAKER SAB-3 PACKER 3.250 10:2.992) 12313 6081 NIP CAMCO D NIPPLE. 9/14/99 2.750 12325 6090 SOS BAKER SHEAR OUT SUB 2.992 Perf .... -- 12474-12484) - - Perf - - 12484-12494) - - Perf 12484-12502) - - 'ROOUCTION - (0-12721, -.-..... - 00:7.000, - - Wt:26.00) - - m..._... ..-.... . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTI) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road SuiteC SCANNED APR 252007 Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7] 1 Report / EDE3M - 23 Caliper Report 13-Apr'{)7 I ~3 - 175 '7 tt lsOt.o3 RECE\VED Signed: 0, i&-- APR 2 5 l007 Date: ' ,,,¡asks Oil 8< Gasl.~· w~ A¡¡c~ Print Name: b rt~)'M\A (2 (\1c.1AJAIL€l- PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: \l\IWW.MEMORYLOG.COM D:lMaster _Copy _00_ PDSANC-20xxlZ _ W ord\DistributionITransmittal_ SheetslTransmit_ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. April 13, 2007 7644 3 3.5" 9.3 lb. L-80 EUE 8rd Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 3M-23 Kuparuk Alaska 50-029-22426-00 Surface 12,308 Ft. (MD) Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This caliper data is tied into <iDS" Nipple @ 12,267' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The recordings indicate the 3.5" tubing is in good to poor condition with respect to corrosive damage. A probable is recorded in joint 105 at 3,302'. Penetrations ranging from 20% to 91% are recorded in 50 of the 401 joints logged. The damage appears in the forms of lines of corrosion and pits, and isolated pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded in the 3.5" tubing logged. The recordings indicate corrosive damage measuring 0.08" in the seal assembly located at 7,523'. This is the second time a PDS caliper has been run in this well. A comparison between the current and previous log (March 31, 2007) for the top 7,556' indicates no increase in corrosive damage. A comparison plot illustrating the difference in maximum - recorded penetrations between logs on a joint by joint basis is included in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Probable Hole ( 91%) Jt. 105 @ 3,302 Ft. (MD) Line Corrosion ( 78%) Jt. 71 @ 2,236 Ft. (MD) Line Corrosion ( 72%) Jt. 66 @ 2,093 Ft. (MD) Line Corrosion ( 69%) Jt. 70 @ 2,197 Ft. (MD) Line Corrosion ( 69%) Jt. 81 @ 2,551 Ft. (MD) Hole (03-31-07 Log) ( 1000ÁJ) Jt 105 @ 3,308 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>12%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: J. Halvorsen Analyst: M. Tahtouh Witness: T. Senden I Pro¡\ctlve Diagnostic Services! 11'1(, P.O. Box 1369, Stafford! TX 77497 REC· EIVED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryíog.com Prudhoe Bay field Office Phone: 659-2307 Fax: (907) 659-2314 103 -/~? tt: 1 ~tx..:,3 APR 2 5 Z007 Alaska Oil & Gas Cons. c;ommissíon Anchorage I I I Well: Field: Company: Country: 3M-23 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Nom.GD 3.5 ins Weight 9.3 f Grade & Thread L-30 WE 3rd I I Penetration and Metal Loss (% wall) penetration body metal loss body I 400 300 200 100 0 o to 1% 10 to 20 to 40 to over 20% 400;" 35% 85% I 1 to 10% I 1 o I I Damage Configuration ( body ) 150 I 100 I 50 o I isolated general line ring hole / poss pitting corrosion corrosion corrosion ¡ble hole I I I DS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins April 13, 2007 MFC UW 24 No. 214320 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 6.0 ins Lower len. 6.0 ins Damage Profile (% wall) penetration body o o GLM 1 GLM2 metal loss body 50 100 Bottom of Survey = 339.7 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 3.5 in (16.4' - 12308.4') GlM 1 (¡¡ 200 ..Q E ::J Z ...., GlM 2 c 0 250 389.7 o I Bottom of Survey = 389.7 I I Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Ine. USA April 13, 2007 Approx. Tool Deviation Approx. Borehole Profile 50 100 150 300 350 50 Damage Profile (% wall) I Tool Deviation (degrees) 19 1563 3129 4716 0 ::E 6277 ...., u.. ,;:: ..c ã.. ( ) 0 7898 9455 11016 12308 100 I I Maximum Recorded Penetration Comparison To Previous 127 134 144 154 164 174 184 194 204 20¿b" I I Well: Field: Company: Country: 3M-23 Kuparuk ConocoPhilllps Alaska, Inc. USA I Overlay Max. Re<:. Pen. (mils) I 0 0.1 8 17 27 37 47 57 67 77 87 97 100 200 I I I I .. '" ..Q E " Z 107 c: ]. 117 "- III ..Q E ::J Z .... c: ]. I I I I I I I I I Survey Date: Prevo Date: Tool: Tubing: April 13, 2007 March 31, 2007 MFC UW 24 No. 214320 3.5" 9.3 Ib L-80 EUE 8rd Difference Diff. in Max. Pen. (mils) -100 -50 o 50 100 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Ine. USA Apríl 13, 2007 Joínt J1. Depth Pel I. Pen. PelL I :Vletal Min. Damage P rofile No. (F1.) Body LD. Comments (%wall) ( ) (Ins.) (Ins.) 0 50 100 .1 16 0 0.01 ') j 2.90 PUP 1 19 0.03 11 5 2.94 Isolated light deDosíts in bodv. 1.1 49 I o~ 15 S 2.90 PUP Shallow níttíng. 1.2 58 I 0.02 ( 9 2.93 PUP 2 66 ( ~ I I 2.90 ~ 3 97 I 2 2.93 Shallow nittinp. 4 128 I 0.03 1 1 2.92 Shallow níttinQ. 5 159 t 0.02 ,} 2.91 6 191 0 0.03 10 1 2.91 7 222 ( 0.03 1\ 7 2.92 Shallow níttina. 8 254 ( 0.03 ¡ II 2.93 Shallow nittinp. 9 284 ( 0.02 2 2.91 10 315 ( 0.03 2 (; 2.91 11 347 ( 0.03 1 2.93 12 378 0.02 ¡=¡ 2.93 13 410 0 0.03 il 2.92 Shallow nittínQ. 14 440 0 0.03 n i 2.91 Shallow DittinQ. 15 470 0 0.03 10 . 2.90 15.1 502 0 0 2.88 DS NIPPLE 16 503 0.03 .1 2.91 17 535 0.03 II 2.90 18 566 0.03 I 2.91 19 597 0.03 1 2.91 20 628 0 0.03 1) 2.91 Shallow nitting. 21 659 () 0.03 1 2.91 Shallow nittinQ. Lt. Denosits. 22 691 0 0.04 1 ( 2.93 Shallow corrosion. 23 720 I 0.03 2.92 24 750 ( 0.04 3 2.93 Shallow Ditting. 25 782 ( 0.03 3 2.92 26 812 ( 0.03 2 2.92 Shallow corrosion. 27 843 r 0.03 2.92 Shallow nittinp. 28 874 {) 0.04 ;:¡ 2.92 Shallow corrosion. 29 90S ( 0.04 1 : 2.93 Shallow corrosion. 30 937 0.01 2.94 Shallow oitting. 31 968 r 0.01 I 2.90 Shallow oitting. 32 1000 ( 0.03 'ì 2 2.90 Shallow oittim~. 33 1031 ( 0.03 6 2.92 Shallow nittinp. 34 1063 ( 0.04 ( 2.92 Shallow corrosion. Lt. Denosits. 35 1093 I 0.04 I ( 2.91 Shallow corrosion. 36 1124 0 0.05 );1 2.93 Shallow nittinQ. 37 1155 if 0.03 1 2.92 38 1187 {) 0.03 I 2.92 Shallow oitting. 39 1218 {) 0.03 2.92 Shallow nitti!1\!:. 40 1250 0 0.02 3 2.91 41 1281 0 0.02 2.91 42 1313 0 0.02 2.92 It1 43 1344 0 0.04 1') 2.93 Shallow corrosion. 44 1375 {) 0.03 If 2.90 45 1407 0 0.08 \ 2.92 Isolated nitting. 46 1438 () 0.03 10 2.92 Body Metal loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 13, 2007 Joint Jt. Depth Pel Pen. PelL i ,'yleldl Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 47 1469 0 0.04 14 6 2.90 Shallow nittím2. 48 1501 () 0.02 7 4 2.92 49 1532 0 0.10 ¡t.) 4 2.91 Isolated oittim2. 50 1563 () 0.04 3 2.95 Shallow nittim2. 51 1595 () 0.07 2.91 Isolated nitlinQ. Lt. Deposits. 52 1626 () 0.03 2.91 53 1657 0 0.03 2.92 54 1689 0.03 2.91 Shallow corrosion. 55 1720 ( 0.09 35 2.94 Isolated nittim2. 56 1752 ( 0.03 2.94 Shallow nittin12:. 57 1783 0.07 4 2.91 Isolated nittim<.. 58 1815 ( 0.14 6 2.89 Isolated nittim2. 59 1846 0 0.11 (, 2.93 Isolated nittinQ. 60 1878 0 0.12 2.91 Isolated nitling. 61 1909 0.13 2.93 Line of nits. 62 1941 0.07 2.93 Line of nits. 63 1972 0 0.09 3 2.93 Isolated nittirml. Lt. Deoosits. 64 2003 0 0.13 ;2 2.91 Line corrosion. 65 2034 0 0.13 12 2.93 Line corrosion. 66 2065 0 0.18 'J 6 2.91 Line corrosion. 67 2096 0 0.17 n 6 2.92 Line corrosion. 68 2126 0 0.02 2.90 69 2158 0 0.17 h 2.92 Line corrosion. Lt. Deposits. 70 2189 D 0.18 9 2.91 Line cDrrosion. 71 2221 0.20 B 2.91 Line corrosion. 72 2252 0.04 14 4 2.90 Shallow oittim<.. 73 2284 0.03 10 4 2.89 74 2315 0.16 ,1 ß 2.93 Line corrosion. Lt. Deposits. 75 2347 ( 0.01 2 2.91 76 2378 0 0.12 (, 2.94 Isolated pitting. 77 2410 0 0.16 ¡ ¡ ~ì 2.89 Line corrosion. 78 2441 0 0.D3 2.91 Shallow nittinQ. 79 2473 0 0.03 1 2.92 80 2504 0 0.03 12 2.92 81 2535 0 0.18 (,9 2.90 Line corrosion. 82 2566 0 0.D3 2 2 2.90 83 2597 0 0.06 ,) 2.91 Isolated nitting. 84 2629 0 0.02 2.93 85 2660 ( 0.03 ') 2.94 86 2691 () 0.14 2.93 Line corrosion. 87 2723 n 0.02 2.90 88 2754 n 0.02 a 2.90 89 2786 ( 0.12 45 2.90 Li ne of oi ts. 90 2817 ( 0.09 37 2 2.92 Line corrosion. 91 2848 ( 0.02 (, 2.92 92 2880 ( 0.02 " 2.94 93 2911 ( 0.02 2.92 94 2943 0 0.02 2.89 U. Denosi ts. 95 2974 n 0.03 2.87 96 3005 0 0.03 13 2.91 Shallow nittim<.. Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: field: Company: Coun try: Survey Date: 3M-23 Kuparuk ConocoPhimps Alaska, Ine. USA April 13, 2007 Joint JI. Depth F'e Pen. Pe !'vll'lal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wa!l) (Ins.) (Ins.) 0 50 100 97 3036 n 0.03 u ) 2.91 Shallow niUinº,. ~ 98 3066 I) 0.04 I '; 2.91 Shallow corrosion. 99 3098 I) 0.03 11 2.93 I 100 3129 0 0.04 I ¿ 2.92 Shallow nittinº,. 101 3161 0.03 2.90 102 3192 0.14 2.91 Line corrosion. 103 3224 ( 0.16 7 2.91 Line corrosion. 104 3255 I 0.08 j1 4 2.90 Line corrosion. ~II 105 3286 I 0.23 J: ¡) 2.90 PROBABLE HOLE! 106 3318 ! 0.03 II 2.91 107 3348 1)11)- 0.12 ¡Ú, 2.91 Line corrosion. 108 3379 h- 0.03 1 2.91 109 3411 0 0.05 ;II 2.91 Line corrosion. 110 3442 I 0.03 2.93 111 3473 0.10 (, 2.92 Line corrosion. 112 3505 0.09 3 2.91 Line cDrrosion. 113 3536 0.D3 2 2.89 114 3568 0.10 2.91 line corrosion. 115 3599 0.10 2.93 Line corrosion. 116 3629 II 0.03 15 2.88 117 3661 I) 0.D3 Ii) I 2.91 118 3693 I) 0.03 '1 2.90 Shallow corrosion. 11'- 119 3724 ( 0.08 2.93 Line of nits. 120 3755 0.02 2 2.92 121 3785 0.03 ,'I 2.93 122 3816 0.02 >, 2.91 123 3847 : 0.02 2.88 124 3878 I) 0.04 1 2.90 Shallow corrosion. 125 3910 I 0.02 B 2.93 126 3941 0 0.04 2.93 Shallow oit/inQ. 127 3973 0 0.04 II 2.90 Shallow oittìnQ!. 128 4004 0 0.04 1 2 2.91 line shallow corrosion. 129 4036 ( 0.D3 >, 2.92 130 4067 0.02 3 2.91 131 4098 I) 0.04 B 2.93 Shallow nit/inº,. 132 4129 I) 0.02 If 2.89 133 4161 () 0.03 11 2.92 133.1 4192 0 0.02 7 2.87 PUP 133.2 4200 0 0 0 { N/A GlM 1 (latch @ 2:001 133.3 4207 0 0.03 7 ¡ 2.86 PUP Shallow oittim!. It. Deoosits. 134 4215 0 0.02 7 3 2.92 135 4245 0 0.04 16 2.91 Shallow corrosion. 136 4277 11 0.D3 n 2.89 Shallow nitting. 137 4309 0 0.01 ") 2.95 138 4339 :1 0.02 7 2.93 139 4371 I) 0.02 ¡¡ 2.93 140 4402 0.04 7 2.90 Shallow corrosion. 141 4434 I 0.03 !¡ 4 2.91 142 4465 ( 0.05 19 >, 2.90 Shallow"'ittin"'. 143 4496 ( 0.03 13 7 2.91 Shallow corrosion. Body Metal loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 3, 2007 Joint Jt Depth 1\ Pen. Pen. i ,,,'Ielal Min. Damag e Profile No. (Ft) Body I.IJ. Comments (% wall) ( (Ins.) (Ins.) 0 50 100 144 4528 0.02 :2 2.92 145 4559 0.03 j 2.86 Shallow nittiml. 146 4591 0.03 2.91 147 4622 ( 0.02 :¡ 2.89 148 4653 0.02 7 2.93 149 4684 ¡ 0.04 15 I 2.92 Shallow corrosion. 150 4716 iT 0.02 q i1 2.94 151 4747 n 0.03 y 2.93 152 4777 ¡) 0.02 î 2.92 153 4808 0.02 ) 2.90 154 4840 0.03 2.93 Shallow nittim!. 155 4871 ( 0.04 1 2.92 Shallow nittín2. 156 4902 ( 0.04 14 2.92 Shallow nittino. 157 4933 ( 0.03 I] 2.88 Shallow nittino. 158 4965 ¡ 0.04 14 1 2.88 Shallow nittin". 159 4996 ¡ 0.ü3 13 I 2.93 Shallow nittin". Denosils. 160 5027 11 0.04 1 4 2.94 Shallow corrosion. 161 5058 ') 0.Q2 2.90 162 5090 0.03 13 2.90 163 5121 ( 0.04 1 2.93 Shallow nittin2. 164 5152 ( 0.02 7 2.92 165 5184 0 0.ü3 12 2.91 166 5215 n 0.03 13 2.88 Shallow corrosion. 167 5247 0 0.03 11 .) 2.91 168 5277 n 0.04 It:¡ 4 2.89 Shallow corrosion. 169 5309 ( 0.03 i3 ) 2.90 Shallow nittin2. 170 5340 011 0.03 1 2.91 Pittin2 in unsel- 171 5371 0.ü3 10 2.93 172 5402 ( 0.ü3 2 2.90 Shallow corrosion. 173 5433 ( 0.03 12 2.90 174 5464 ¡ 0.04 1 2.91 Shallow corrosion. 175 5496 ¡) 0.04 1 Ii 2.91 Shallow corrosion. 176 5527 n 0.03 4 2.91 Shallow nittin2. 177 5558 0 0.06 4 2.90 Isolated nittin2. 178 5590 n 0.ü3 ) 2.91 . 179 5621 ¡) 0.04 4 2.90 Shallow nittin2.. 180 5652 ( 0.03 2.94 Shallow corrosion. 181 5683 ( 0.02 q 2.90 182 5715 ( 0.03 1 2.90 Shallow nittino. 183 5746 ( 0.03 13 2.89 Shallow nittino. 184 5778 ( 0.03 2.90 Shallow corrosion. 185 5809 0 0.02 ¡- 2.91 186 5841 0.02 4 2.92 187 5872 0.04 1 2 2.88 Shallow corrosion. 188 5903 I 0.02 I 2.88 189 5934 ( 0.03 1 5 2.92 190 5965 ¡ 0.02 I 2.91 191 5996 ¡) 0.02 'I ,~ 2.88 p 192 6028 ( 0.03 1 ¡ 2.90 p 193 6059 ¡) 0.04 1 ) 2.91 Shallow nittíml. !III Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 13, 2007 Joint Jt. Depth Pee. Pen. Perr ¡Melal Min. Damag e Profile No. (Ft.) -( Body I.D. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 194 6090 0.02 7 4 2.91 195 6122 0.04 14 1 2.92 Shallow oittim:!. 196 6153 0.04 14 2 2.92 Shallow corrosion. 197 6183 I 0.ü1 2 2.90 198 6215 0 0.04 7 I 2.88 Shallow corrosion. 199 6245 0 0.ü3 1 2.91 200 6277 0 0.03 2.91 201 6307 0 0.03 I 2.91 202 6339 0 0.03 1 2.93 Shallow oitting. 203 6370 0 0.03 I 2.89 Shallow oitting. 204 6402 0 0.02 ß 2.90 205 6433 0 0.02 9 2.92 206 6464 0 0.03 ¡I) 2 2.92 207 6496 0 0.02 4 2.92 ! 208 6527 0 0.04 ß 2.90 Shallow nittim~. 209 6559 0.10 0.03 2.89 Pitting in unset. 210 6590 0 0.04 2.89 Shallow corrosion. 211 6621 0 0.04 2.91 Shallow nilting. 212 6653 0 0.04 15 2.90 Shallow corrosion. 213 6684 0 0.02 ß 3 2.91 214 6715 0 0.04 1 3 2.93 Shallow Dittim~. 215 6747 I. 0.03 2.91 == 216 6779 012 0.04 2.92 Shallow corrosion. 217 6809 0 0.06 2.90 Isolated nittir¡g. 218 6841 0 0.04 2.90 Shallow nittim:!. 219 6872 0 0.03 11 2.92 Shallow oittin2:. 220 6903 0 0.02 B 2.90 221 6934 0.04 15 I 2.92 Shallow oittiml. 222 6965 0.04 I i 2.91 Shallow corrosion. 223 6997 0.05 21 2 2.90 Corrosion. 224 7028 0.04 2.92 Shallow Dittim¡:. 225 7059 0 0.03 2.91 226 7091 0 0.02 2.88 Lt. Denosits. 227 7122 0 0.03 I 2.91 It 228 7154 0 0.04 fj 4 2.91 Shallow corrosion. 229 7184 0 0.05 20 2 2.88 Shallow corrosion. 230 7216 0 0.02 B 4 2.89 231 7247 010 0.04 I 4 2.90 Shallow corrosion. 232 7278 0 0.03 4 2.90 233 7309 0 0.03 5 2.90 Shallow Ditting. 234 7340 0.03 I 2.91 235 7371 0 0.03 I 2.93 Shallow nitting. 236 7402 I. 0.02 2.88 237 7434 0 0.03 13 2.93 Shallow oittin2:. 237.1 7465 0 0.03 3 2.85 PUP Shallow corrosion. 237.2 7473 ) 0 0 N/A GLM 2 II atch @ 3:00) 237.3 7480 0 0.02 2.87 PUP U. Denosits. 238 7489 0 0.03 2.90 ~ 238.1 7517 0 0.01 2.89 PUP 238.2 7523 0 0.08 31 2.94 SeallCorrosion.ì Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 13, 2007 Joint Jt. Depth Fen Pen. Pen. !vlelal Min. Damag e Profile No. (Ft.) . Jpsel Body I.D. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 238.3 7543 0 0 ( N/A PACKER 239 7553 0 0.04 2.89 Shallow Dittim~. 240 7585 0 0.03 2.89 241 7616 0 0.04 I 2.89 Shallow corrosion. 242 7647 0 0.03 2.91 Shallow Dittim~. 243 7679 0 0.04 2.94 Shallow corrosion. 244 7710 0 0.02 a 2.91 245 7741 0 0.03 1 2.89 II 246 7773 0 0.04 I 2 2.88 Shallow Dittim~. U. Deoosils. 247 7804 0 0.03 I 2.91 248 7835 0 0.03 1 2.90 Shallow pittim~. 249 7867 0 0.05 1 2.90 Shallow pittim~. 250 7898 0 0.03 1 2.91 Shallow corrosion. 251 7930 0 0.05 1S 2.90 Shallow corrosion. 252 7961 () 0.03 13 4 2.90 Shallow oitting. 253 7992 () 0~1' 2 2.90 Shallow corrosion. 254 8022 0 0.11 3 2.90 255 8053 0 0.031 2.93 Shallow corrosion. 256 8085 0 0.04 1 2.89 Shallow corrosion. 257 8116 0 0.04 l' ( 2.89 Shallow Dittim~. Lt. Dennsits. 258 8147 () 0.05 J& 2.89 Line shallow pits. Lt. Denosils. 259 8179 0 0.03 :1 2.91 260 8211 () 0.03 1 /1· 2.93 Shallow pitting. 261 8242 0 0.04 I 3 2.92 Shallow pitting. 262 8273 0 0.05 2.89 Shallow pittim!. u. Deoosits. 263 8303 0 0.05 I 2.90 Shallow oittim¿. 264 8334 () 0.D3 2.90 Lt. Deposi ts. 265 8366 () 0.03 2.89 266 8397 0 0.03 2.88 Lt. Deposits. 267 8428 0.04 14 2.91 Shallow pitting. 268 8460 0.02 9 2.89 269 8491 0.03 13 2 2.94 Shallow pitting. 270 8522 0.03 1 2 2.90 Shallow nitting. 271 8554 0 0.03 1 (; 2.87 Shallow pitting. 272 8584 0 0.05 ¡. I 2.90 Shallow oitting:. 273 8616 () 0.04 I 2.89 Shallow corrosion. Lt. Deoosi ts. 274 8646 0 0.03 I 2.91 Shallow pittim~. 275 8677 ( 0.04 1 '1 2.91 Shallow pitting. 276 8707 ( 0.03 13 2.90 Shallow pitting. 277 8739 ( 0.03 1 0 2.89 Shallow corrosion. 278 8771 \ 0.04 6 2.89 Shallow oitting. 279 8802 6 0.04 1 2.91 Line of shallow pits. 280 8834 012 0.03 1 2.87 Shallow oitting:. Lt. Deoosits. 281 8865 0 0.03 1 ¿ 2.89 282 8896 ( 0.03 13 2.89 Line of shallow oits. 283 8928 0 0.04 14 2.90 Line of shallow nils. L t. Deoosi ts. 284 8959 I) 0.04 1 Î 2.92 Line of shallow nits. 285 8991 0 i= 4 2.90 Shallow pitting. 286 9021 () Î 2 2.95 287 9053 () 9 2 2.91 Body Metal Loss Body Page 6 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-30 EUE 3rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc USA April 13, 2007 Joint Jt. Depth 1\'1 Pen. Pen ! 1\/lelal Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (II (Ins.) (Ins.) 0 50 100 288 9084 ( 0.05 20 2.93 Shallow corrosion. 289 9115 0.04 14 2.91 Shallow nittino. 290 9147 0.03 i3 2.89 Line of shallow nits. 291 9178 0.04 16 2.84 Shallow nittin<>. Lt. Deoosits. 292 9209 0.03 11 .) 2.80 L t. Denosi ts. 293 9239 ì 0.05 21 ;; 2.93 Shallow nittino. II 294 9271 Oil) 0.04 ì .' 2.93 Shallow nittinQ. 295 9302 ( 0.04 1 2.89 Shallow nittino. 296 9334 () 0.04 4- 2.89 Line of shallow nits. 297 9363 () 0.04 2.90 Shallow corrosion. 298 9393 n 0.04 2.89 Shallow nittirw. 299 9425 U 0.02 II 2.92 300 9455 () 0.05 1ß 2.92 Shallow nittino. 301 9487 () 0.04 II 2.88 Shallow corrosion. 11III 302 9518 () 0.06 1 ) 2.91 Line of nits. 303 9547 () 0.03 1 2.92 Shallow niWnQ. 304 9580 0.02 q 2.92 Lt. Denosits. 305 9609 0.04 ì 2.90 Shallow nittinQ. 306 9640 0.05 2.92 Shallow corrosion. 307 9671 ( 0.05 19 2.90 Shallow nittino. 308 9703 I 0.04 14 2.90 Shallow nittino. 309 9734 () 0.04 1 (i 2.91 Shallow nittino. 310 9766 () 0.04 I ) 2.93 Shallow nittinQ. 311 9797 () 0.03 1 J 2.87 312 9828 () 0.04 I 2.89 Shallow níttinQ. 313 9860 0 0.03 2.90 Shallow nittinQ. U. Deoosíts. 314 9891 0.03 ( 2.90 Shallow nittinQ. U. Deoosits. 315 9922 0.04 17 2.86 Shallow corrosion. Lt. Deoosíts. 316 9954 I 0.04 17 i 2.91 Shallow nittino. Lt. Deoosits. 317 9985 '} 0.05 2() 2.93 Line of nits. 318 10016 ) 0.04 H '; 2.90 Shallow nittín<>. Lt. Deoosits. 319 10048 0 0.05 í 2.89 Shallow corrosion. 320 10080 () 0.04 2.93 Shallow nittinQ. 321 10112 C 0.02 2.90 322 10143 0 0.04 2.88 I íne of shallow nits. U. Deoosi ts. 323 10174 ( 0.05 21 2.90 Line of oits. 324 10206 0.05 20 i 2.88 Line of shallow nits. 325 10236 ( 0.04 15 {"; 2.88 Line of shallow oits. 326 10266 I 0.05 19 I 2.88 Line of shallow nits. Lt. Deoosits. 327 10297 0 0.04 17 1 2.89 Line of shallow nits. 328 10327 0 0.05 1B 1 2.88 Line of shallow nits. 329 10359 ( 0.06 2 7 2.89 Isolated nittinQ. 330 10390 0.04 I () 2.88 Shallow nittinQ. 331 10421 ( 0.03 1 2.88 Shallow nittinQ. I 332 10453 ( 0.04 1, 2.88 Shallow niWm;¡. 333 10484 I 0.03 11 2.89 334 10516 ì 0.05 2.90 Isolated nittínQ. 335 10548 () 0.04 7' 2.88 Shallow corrosion. 336 10578 0 0.04 ) 2.90 Shallow nittìnQ. 337 10609 () 0.04 1 2.90 Shallow nittinQ. U. Denosits. Penetration Body Metal Loss Body Page 7 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 3, 2007 Joint jt. Depth PCII Pen. Pen Melal Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (Ii) (Ins.) (Ins.) 0 50 100 338 10640 0 0.03 I 2.90 339 10671 0 0.04 , 2.89 Shallow nittim~. Lt. Deoosits. 340 10703 0 0.02 2.89 341 10734 0 0.06 2.91 Line of nits. 342 10766 0 0.04 2.90 Shallow nittimL 343 10797 0 ~ 2.90 Shallow nittiml. 344 10828 0 14 2.83 Line of shallow oits. Lt. Denosits. 345 10860 0 0.04 15 2.90 Shallow oittinl'!. U. Deoosits. 346 10891 0013 0.05 ) 5 2.90 Line corrosion. 347 10922 0 0.04 2 2.91 Line of shallow corrosion. 348 10954 0 0.04 ) 2.86 Shallow corrosion. .349 10986 0 0.0.3 ¿ 2.89 Lt. Denosits. 350 11016 0 0.04 2.88 Line of shallow nits. .351 11048 0 0.04 2.90 Line of shallow nits. .352 11080 I) 0.04 1, 2.89 Line of shallow nits. 35.3 11110 0.0.3 1( 2.87 .354 11142 I 0.04 14 2.88 Shallow Dittiml. .355 1117.3 I 0.03 1 2.88 Shallow Dittiml. Lt. Deoosits. .356 11205 I 0.03 6 2.91 m 357 11236 0 0.05 )1 2.93 Shallow corrosion. .358 11268 0 0.0.3 2.91 Shallow nittiml. Lt. Denosits. 359 11298 0 0.06 2.93 Line of nits. Lt. Deoosits. .360 11.329 I) 0.04 2.91 Shallow corrosion. 361 11 360 I) 0.03 i2 2.86 362 11391 I) 0.04 2.88 Shallow corrosion. .363 11421 C 0.04 1 , 2.85 Shallow Dittins~. , .364 11452 0 0.04 8 2.88 Shallow oittins!. 365 11484 0 0.02 =t=+ 2.88 .366 11515 I) 0.05 II 2.85 Isolated nittinQ. Lt. Deposits. 367 11546 0 0.04 '6 2.88 Shallow nittinQ. ¡n 368 11578 0 0.04 i4 S 2.88 Shallow corrosion. r 369 11608 () 0.03 13 ") 2.89 Shallow nittiml. ¡n 370 11638 () 0.0.3 n 7 2.87 Shallow corrosion. I 371 11670 0 0.04 14 1 2.88 Shallow corrosion. .372 11 701 0 0.03 11 () 2.89 iI\i .373 117.32 I) 0.04 I 0 2.86 Shallow nitting. iI\i 374 11763 () 0.04 1 2.89 Shallow nittinQ. 375 11795 () 0.04 1 6 2.88 Shallow corrosion. 376 11826 I) 0.05 ;; I 2.89 Isolated nittirw. 377 11856 () 0.0.3 1 1 2.88 !III 378 11 889 () 0.04 16 ;; 2.89 Shallow corrosion. III 379 11919 0 0.0.3 13 () 2.88 Shallow corrosion. ì 380 11951 () 0.05 19 ß 2.87 Shallow oitting. 381 11982 () 0.05 J 6 2.87 Shallow corrosion. 382 12012 () 0.07 ¡ 2.86 Isolated Ditting. 383 12044 II 0.04 ì 2.87 Shallow oining. .384 12075 () 0.05 1 S 2.86 Isolated nittinQ. m .385 12107 () 0.04 () 2.86 Shallow corrosion. Lt. Deoosits. i .386 121.37 () 0.04 () 2.86 Shallow oittinQ. 387 12169 () 0.06 2: I 2.87 Isolated oittirw:. Body Metal Loss Body Page 8 I I Pipe: Body Wall: Upset Wall: Nominall.D.: I I Joint it. Depth No. (Ft.) 388 12200 389 12231 389.1 12261 389.2 12267 389.3 12269 389.4 12275 389.5 12282 389.6 12292 389.7 12308 I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 13, 2007 Page 9 Comments ittin . Damage Profile (%wall) o 50 100 Body Metal Loss Body ------ - - -- .. - - .. .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA 3,5 ins 9,3 f L-BO EUE Brd Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: April 13, 2007 MFC UW 24 No, 214320 1,69 24 M, Tahtouh Cross Section for joint 105 at depth 3301.91 ft Tool speed = 43 Nominal 10 = 2,992 Nominal 00 = 3.500 Remaining wall area = 91 % Tool deviation = 81 0 Finger 22 Penetration 0,232 ins PROBABLE HOLE 0,2] ins = 91% Wall Penetration HIGH SIDE UP Cross Sections page 1 .. .. .. - ------ Well: Field: Company: Countly: Tubin : ------- - - PDS Report Cross Sections 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 EUE 8rd April 13, 2007 MFC UW 24 No. 214320 1.69 24 M. Tahtouh Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 71 at depth 2236.34 ft Tool speed = 43 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 52 0 Finger 22 Penetration = 0.199 ins Line Corrosion 0.20 ins = 78% Wall Penetration HIGH SIDE = UP Cross Sections page 2 - - - - I KRU 3M-23 I ~ ~M"23 TUBING API: 500292242600 Well Tvoe: PROD 12409 (0-12283, SSSV Type NIPPLE Oria Com letion: 12/29/1993 A 12750 00:3500, Annular Fluid· Last W/O 7/18/2006 PULL RHC, ID2.992) LEAKS FOUND œ Ref Loa Date: Last Update: 8n /2006 Last . 12491' RKB TO: 12750 ftKB Last 4/2006 Max Hole An Ie: 70deo@11019 Description Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16000 0 121 121 6258 H-40 WELDED SURFACE 9.625 0 3306 2530 53.50 J-55 BTC PRODUCTION 7000 0 12721 6374 26.00 L-80 BTC-MOD SURFACE 9.625 3306 5265 3246 36.00 J 55 BTC SURFACE 9.625 5265 5349 3276 53.50 L-80 BTC-MOD SURFACE 9625 5349 5437 3307 3600 J-55 BTC LEAK 7000 7695 7728 4141 2600 L-80 BTC-MOD LEAK f.Oo( 9214 9275 4710 26.00 L-BO '($mh!.l··~)Ti.lB.NG: Size I TOD I Bottom I TVD I Wt I Grade I Thread 3.500 ~ 12283 6060 I 930 I L-80 I EUE 8RD 3.500 12325 I 6090 9.30 I L-80 I - Interval TVD Zone Status Ft SPF Date Type Comment 12423 - 12443 6160 - 6174 C-4 20 4 9/12/2001 APERF 2 1/8" Ene~et wlP J chgs, 0 deg I ph +/- 90 deo orient 12450 - 12466 6179 - 6191 A-2 16 4 9/7/2001 APERF 2 1/8" Enerjet wlP J chgs, 0 deg : ph +/- 90 dea orient 12474 - 12484 6197 - 6204 A-1 10 4 9/6/2001 APERF 2 1/8" Ene~et wlP J chgs, 0 deg ) ph +/- 90 dea orient 12484 - 12494 6204 - 6211 A-1 10 8 9/12/2001 RPERF 2 1/8" Enerjet w/P J chgs, 0 deg orient 12494 . 12502 6211 - 6217 A-1 8 4 4/23/1994 IPER ak 180 deg ph t':!...... <I if'!' St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 4205 2859 CAMCO KBUG GLV 1.0 BK 0.156 1260 7/29/2006 ~ 7479 4049 CAMCO KBUG OV 1.0 BK 0.250 0 7/20/2006 MI'¡"" )i Depth TVD Type Description ID 31 31 HANGER GEN IV TUBING HANGER 3.500 518 518 NIP 2.875 7528 4067 LOCATOR BAKER LOCATOR wiNO GO RING ON THE BOTTOM 2.990 7533 4069 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 12267 6049 NIP CAMCO OS NIPPLE 2812 12282 6059 LOCATOR BAKER LOCATOR ~ 3.000 12283 6060 I SEAL ER GBH-22 SEAL _ Y 3000 ·:V{f'..."''''..'. ."'......UYi..""."'...YY,'" '..,¡c..... Depth TVD Type Description ID 7522 4065 SLEEVE HR LINER SETT ING SLEEVE wiNO GO 00 5.79", 10 4.42" 4.420 7536 4070 NIP BAKER RS PACK-OFF SEAL NIPPLE 4250 7539 4071 PBR BAKER 80-40 PBR 4.250 7551 4075 PACKER BAKER 7" RETRIEVABLE PACKER 2.930 Depth TVD Type Description ID 12282 6059 PBR BAKER 80-40 2.992 12283 6060 ANCHOR BAKER KBH-22 K-ANCHOR 3.000 LOCATOR 12297 6070 PKR BAKER SAB-3 PACKER 3250 (12282-12283, 12313 6081 NIP CAMeO 0 NIPPLE. 9/14/99 &1 OD:4.25O) 12325 6090 SOS BAKER SHEAR OUT SUB 2. TUBING (12283·12325, Date If; 003.500, 7/10/2006 LEAKS FOUND IN THE 7" CASING (éÏ! 7695'-7728' and (â) 9214'-9275' ISOLATED BETWEEN PACKERS 10:2.992) 7/18/2006 !TREE 3-118" 5 Ksi FMC GEN IV TREE CAP CONNECTION 3" OTIS = -- Perf ~- (12474-12484) - -- Perf - -- (12484-12494) - -. Perf - ¡---. (12484-12502) - ¡---. PROOUCTION ¡--- (0-12721, - 1= 00:7000, -~ Wt:26 00) - I I I I I I I I I I I I I I I I I I . Tubing Detail 3 1/2" Tubina Detail . Well: Date: 3M-23 07/17/06 I """.... ConocoPhillips AI""k'. Inc. I DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Oriainal Drillina Ria: RKB to Tu bina Head Lock Down Screw.!; 31.25 FMC 3-1/2" Gen IV Tubina Hanaer wi 2.45' Pin X Pin PUD J1 2.97 31.25 Jts 389 to 3B9 1 Jts 3-1/2",9.3#, L-BO, EUE BR Mod Tubina, drifted to 2.91" 31.20 34.22 Space Out Pups, 3-1/2", 9.3#, L-BO, EUE BR Mod Tba, 2.91" drift(10.10' + B.041 18.14 65.42 Jts 375 to 388 14 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.91" 434.77 83.56 Cameo 3-1/2" "OS" Nipple, 2.875" ID, 4.62" OD 1.57 518.33 Jts 257 to 374 118 Jts 3-1/2",9.3#, L-BO, EUE 8R Mod Tubina, drifted to 2.867" 3681.63 519.90 Tubina Measurement / Depth Correction - 133 Jts above -4.03 4201 .53 Pup Joint, 3-1/2", 9.3#, L-BO, EUE 8R Mod Tubina, drifted to 2.867" 8.17 4197.50 Cameo 3-1/2" X 1" KBUG GLM wi Dummv, BK-5 Latch. 5.39" OD, 2.920"ID 6.54 4205.67 PuP Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.867" 7.98 4212.21 Jts 153 to 256 1 04 Jts 3-1/2",9.3#, L-BO, EUE 8R Mod Tubina, drifted to 2.867" 3254.34 4220.19 Tubina Measurement / Depth Correction - 104 Jts above -3.18 7474.53 PuP Joint, 3-1/2", 9.3#, L-BO, EUE 8R Mod Tubina, drifted to 2.867" 8.01 7471.35 Cameo 3-1/2" X 1" KBMG. DCK-2 Shear Valve, BEK Latch, 5.39" OD 2.920"ID 7.02 7479.36 Pup Joint, 3-1/2", 9.3#, L-80, EUE BR Mod Tubina, drifted to 2.867" 8.14 7486.38 Jts 152 to 152 1 Jts 3-1/2" 9.3#, L-BO, EUE BR Mod Tubina, drifted to 2.867" 28.38 7494.52 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.867" 6.07 7522.90 Baker Locator, 5.0" 00 No Go Rina on bottom 1.57 7528.97 No Go Locator I Seal Assembly was Spaced out 2' above fully landed position 2.00 7530.54 Baker Seal Assemblv, Size 80-40,4" 00 Seals, 2.99" 10,18.18' Lona 7532.54 Bottom of Seal Assemblv / Mule Shoe (éj) 7548.72' Straddle Packer Assemblv set with Drilloioe on 7/16/06 TOD of Settina Sleeve @ 7522.39' No Go Landina Rinø is 10.15' below TOD of Sleeve @ 7532.54' "HR" Liner SettinQ Sleeve, 5.79" 00, 5.25" 10 Bore for DP settina tool 10.15 7522.39 No Go in "HR" Liner Settina Sleeve 5.79" 00, 4.42" 10 at No Go 3.86 7532.54 Baker "RS" Pack-Off Seal Nipple, 5.57" 00, 4.25" 10 2.49 7536.40 Baker PBR, Size 80-40, 5" 00, 4" Seal Bore 12.41 7538.89 Baker 7" "FHL" Rerievable Packer 5.97" 00, 2.93" 10 7.43 7551.30 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.B5O" 2.27 7558.73 Jts 1 to 151 151 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.867" 4704.60 7561.00 TubinQ Measurement / Depth Correction - 151 Jts above -4.58 12265.60 PuP Joint, 3-1/2", 9.3#, L-80, EUE BR Mod Tubina, 4.19" 00 SCC, drifted to 2.867" 6.14 12261.02 Cameo 3-1/2" "OS" Nipple, 4.19" OD, 2.812" ID, wi RHC Plua .96 12267.16 Pup Joint, 3-1/2'\ 9.3#, L-80, EUE 8R Mod Tubing, 4.19" 00 SCC, drifted to 2.867" 6.15 12268.12 PuP Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubina, 4.19" 00 SCC, drifted to 2.867" 8.02 12274.27 Baker Locator, 4.25" 00 .17 12282.29 Locator I Seal Assembly was Spaced out l' above fully landed position 1.00 12282.46 Baker GBH-22 Seal Assemblv, Size 80-40,4" 00 seals, 3" 10, 11.49' Lona 12283.46 Bottom of Seal Assembly / Mule Shoe @ 12,293.95' Existina PBR/Packer and Tail Assemblv set on 1/23/99 Baker PBR, 4" seal bore 13.02 12283.46 Baker KBH-22 Anchor Seal Assembly .92 12296.48 Baker SAB-3 Permanent Packer 4.91 12297.40 Crossover, 4-1/2" NU Pin X 3-1/2" EUE Pin .92 12302.31 PUP Joint, 3-1/2", 9.3#, L-80, EUE-8RD Tubino 10.14 12303.23 Camco3-1/2" D-Nipple, 2.750"10 1.00 12313.37 PUP Joint, 3-1/2", 9.3#, L-80, EUE-8RD Tubino (Special 6.151" Drift on collar) 10.13 12314.37 Baker Shear Out Sub / Wireline Re-entrv Guide .90 12324.50 Bottom of Tail 12325.40 Remarks: Used Jet-Lube Pipe Dope. Averaae Toraue 2000 ft-Ib. Drifted Tubing with 2.B67" plastic rabbit. Drifted top 15 joints, space out pups, and tubing hanger to 2.91". Upper String: 83K# PU, 5OK# SO, 38K# Block Weight. Straddle Packer/Tail Assy: 145K# PU, 73K# SO with 3-1/2" DP - 105K#PU, 63K# SO after releasing DP - 68K# PU, 53K# SO before RIH on DP, 38K# Block Weiaht. Dropped 1-5/16" ball on rod and roller stem to RHC Pfua in OS Nipple @ 12267'. Nordic Ria #3 Supervisor: Peter Wilson I Don Breeden I I I I I I I I I I I I I I I I . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. -- : I, To: .......... ......-.......'.... .<""" ...,-.; ''; AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 ~APR 112001 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 24508952 1) 1 Report / EDE 2) 3) 4) 5) 6) 7) 3M - 23 31-Mar-07 Caliper Report /0;3 - /1;? -Jt ILfáCJa Signed: (l}L ~ ,IA rts+-¡ Me- (YL.1..illlAkp-M Date : "Æl Print Name: 1 0 Con~. ,~f!~aag~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORÞ.GE@MEMORYLOG.COM WEBSITE: 1ilf1J\JW.MEMORYLOG.COM D:lMaster _Copy _00_ PDSANC-2OxxIZ _ WordlDis1ributionlTrnnsmittal_ SbeetslTransmÍt _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska March 31, 2007 8584 2 3.5" 9.3 lb. L-80 Tubing Well: Field: state: API No.: Top Log IntvI1.: Bot. Log Intv/1.: 3M-23 Kuparuk Alaska 50-029-22426-00 Suñace 7,956 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into GUf #2 @ 7,479' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a hole recorded @ 3,308'. Maximum recorded wall penetrations ranging from 20% to 100% wall thickness are recorded in 450f the 246 joints logged. The damage recorded appears mostly in the form of Line Corrosion or Lines of Pits. There are no areas of significant Cross Sectional Wall loss or I.D. restriction recorded throughout the interval of tubing logged. This is the second PDS caliper of this well. A comparison between this log and the previous log ( April 18, 2006) indicates the 3.5" tubing has been changed. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes ( 100%) Jt. 105 @ 3,308 Ft. (MD) Line Corrosion ( 77%) Jt. 71 @ 2,242 Ft. (MD) Line Corrosion ( 75%) Jt. 74 @ 2,347 Ft. (MD) Line Corrosion ( 73%) Jt. 69 @ 2,192 Ft. (MD) Line Corrosion ( 71%) Jt. 81 @ 2,557 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>15%) are recorded in the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded in the interval logged. I Field Engineer: K. Miller Analyst: J. Thompson Witness: C. Fritzpatrick ProActive Diagnostic Services, Inc. i P,O. E·ox 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe Bay Field Office Phone: (90ì) 659-2307 Fax: (907) 659-2314 ,q 1> -/ t5'9- 1J: 1'1 SC78- I Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (21.7' - 7548.3') Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhiliips Alaska USA March 31, 2007 I I I Approx. Tool Deviation Approx. Borehole Profile 75 25 I 25 788 I 50 1569 I 2353 I I 100 3135 0 (¡j ~ ..Q .,..; E I.L. :::¡ 125 3916 ¡: z ..J:: GLM 1 ... Q.. ( ) 0 0 150 4721 I 175 5502 I I 200 6282 I 225 7065 I GLM 2 238.3 o 50 7548 100 I Damage Profile (% wall) ! Tool Deviation (degrees) I Bottom of Survey = 238.3 I I I I I Well: Field: Company: Country: 3M-23 Kuparuk ConocoPhiliips Alaska USA I Tubing: Weight 9.3 f Grade & Thread 1.-80 WE 8RD Nom.OD 3.5 ins I I Penetration am.! Metal loss ("to wall) penetration body metal loss body I 250 200 150 100 50 o o to 1% over 85% I I 1 o I pene. loss I Damage ( bQdy ) 100 80 60 40 20 0 isolated general line ring hole I poss pitting corrosion corm sion corrosion ¡ble hole I I I I I I DS Repo Overvi Region s Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st March 31, 2007 MFC 24 No 40665 1.69 24 J. Thorn son Nom.lD 2.992 ins Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) penetration body o o metal loss body 50 100 GLM 1 GLM2 Bottom of Survey = 238.3 Analysis Overview page 2 I I I JOINT ON SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3 M-23 Kuparuk ConocoPhillips Alaska USA March 31, 2007 I I I Joint JI. Depth Pen Pen. Pen, ! "¡Ielal Min. Damag e Profile No. (Ft.) '1 Body I.D. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 .1 22 ¡¡ 0.01 2 2.93 PUP ï+1 1 25 I)~I (i 2.95 1.1 55 o 2\ )1 2.92 PUP Corrosion. 1.2 65 D 0.03 10 2.94 PUP 2 73 0 0.04 2.92 Shallow nittina. 3 103==±=J± 0.04 2.94 Shallow nittim!. 4 134 nn4 2.93 Shallow níUinp'. 5 166 0 0.04 2.92 Shallow corrosion. U. Denosíts. 6 197 0 0.03 3 2.93 Shallow nittinº. 7 229 I. 0.03 j j~ Shallow corrosion. 8 260 0.03 13 Shallow nittìr1º. 9 291 0.03 12 ; 2.93 10 322 0.03 11 2.93 Shallow corrosion. 11 354 0.03 ) 2.96 Shallow oittim!. 12 385 0.02 c¡ 2.95 =tR 416 0.03 1 2.94 Shallow corrosion. 447 61ft 2 m 2.93 Shallow nittinp'. 477 U 2.92 15.1 508 D 0 D 2.88 NIPPLE 16 510 D 0.05 1 2.94 Shallow corrosion. 17 541 u 0.Q3 1 2.94 Shallow nittin\:!. 18 572 0 0.04 2.94 Shallow nittin\:!. 19 603 D 0.03 2.91 Shallow corrosion. 20 635 D 0.04 2.90 Shallow corrosion. 21 666 0 0.04 2.89 Shallow corrosion. 22 697 0 0.05 19 r:, 2.88 Shallow corrosion. 23 727 0 0.03 1 2.88 24 757 0 0.04 1 2.93 Shallow corrosion. 25 788 0 0.Q3 2.91 Shallow corrosion. 26 818 0 0.03 2.92 Shallow oittim¡:. 27 850 0 0.04 2.91 Shallow corrosion. 28 880 0 0.04 2.89 Shallow corrosion. I 29 912 0 0.04 2.91 Shallow corrosion. 30 943 0 0.04 ì S 2.93 Shallow niuina. 31 975 () 0.03 I S 2.89 32 1006 0 0.05 11 2.87 Shallow corrosion. 33 1038 { 0.04 4 2.87 Shallow níttinQ. 34 1069 0.04 () 2.92 Shallow nittim1.. 35 1099 0.04 (, 2.91 Shallow corrosion. 36 1131 0.05 1 2.94 Shallow oiUin\!. 37 1162 0.03 1 2.91 Shallow nittinp'. 38 1193 () 0.04 I¿ 7 2.92 Shallow corrosion. 39 1225 0 0.03 L h 2.91 Shallow corrosion. 40 1256 0 0.01 6 2.92 41 1288 () 0.05 ) :1 2.91 Shallow corrosion. 42 1319 () 0.04 1 2.90 Shallow corrosion. 43 1350 () 0.03 I 2.93 44 1382 0 0.02 9 ;; 2.90 45 1413 0 0.07 2[1 S 2.90 Isolated nittinQ. 46 1444 0 0.04 14 ) 2.90 Shallow nittim¡:. I I I I I I I I I I I I Page 1 I I I REPORT JOINT TABULATION 5 EET I Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhìilips Alaska USA March 31, 2007 I I I Joint Jt. Depth Pen. Pen. Pen. !\/Ietal Min. Damage Profile No. ·t Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 47 1475 () 0.04 17 6 2.89 Shallow corrosion. 48 1507 0 0.03 11 6 2.89 49 1538 (J 0.11 43 6 2.90 Line corrosion. Lt. DeDosits. 50 1569 0 0.08 \2 3 ~ Lt Deposits. 51 1601 0 0.07 28 6 ~632 ( 0.04 1 4 2.90 Shallow corrosion. 53 664 ( 0.04 4 2.90 Shallow corrosion. 54 1695 ( 0.06 ~ Corrosion. 55 1726 ( 0.09 Line of nits. 56 1758 ( 0.04 Shallow corrosion. 57 1789 ( 0.08 4 2.89 Line of oits. 58 1821 ( 0.14 "-) 2.89 Line corrosion. 59 1852 0 0.09 I '/ e ') Qn Line corrosion. 60 1884 0 0.11 4 2.89 Line of oits. 61 1915 0 0.13 ß 2.93 Line corrosion. 62 1947 n 0.07 ( 2.94 I ine corrosion. 63 1978 ~.~ =±::õti ( 2.90 Line corrosion. 64 2009 I 2.89 Line corrosion. 65 2040 o 0.12 2.90 Line corrosion. 66 2071 0 0.17 6') 7 2.89 Line corrosion. Lt. Deoosi ts. 67 2102 (I 0.17 67 6 2.90 Line corrosion. 68 2133 0 0.04 2.88 Shallow Line of oits. 69 2164 0.19 2.89 Line corrosion. Lt. Deposits. 70 2196 0.18 2.85 Line corrosion. 71 2227 0.20 2.86 Line corrosion. Lt. Deoosits. 72 2258 ( 0.05 2.85 Shallow line corrosion. 73 2290 0.02 2.86 74 2321 0 0.19 ') 2.88 Line corrosion. Lt. Deoosits. 75 2353 U 0.04 17 2.87 Shallow line of oits. 76 2385 0 0.10 39 ;; 2.89 I ine corrosion. 77 I )416 0.17 61 -j'1 2.88 Line corrosion. 78 I 2447 0.04 1 ] 2.86 Shallow corrosion. 79 2478 0.Q3 ( 2.87 Shallow oitting. Lt. Denosits. 80 2510 0.04 2.91 Shallow corrosion. 81 2541 ( 0.18 2.86 Line corrosion. 82 2573 0 0.02 2.86 83 2603 0.04 I 10 2.89 Shallow line corrosion. 84 2635 0 0.05 19 6 2.88 Shallow line corrosion. 85 2666 0.04 7 4 2.88 Shallow line corrosion. 86 2698 0.14 7b (, 2.86 Line corrosion. 87 2729 0.02 1 2.86 88 2760 I 0.03 1 2.82 89 2792 Oil 0.10 (, 2.84 Line corrosion. 90 2824 0 0.11 ') 2.87 Line corrosion. U. Deoosits. 91 2854 () 0.04 5 2.88 Shallow line corrosion. 92 2886 () 0.04 Cl4 3 2.82 Shallow oittinl!. Lt. Deoosíts. 93 2917 ( 0.04 I 2.79 Shallow corrosion. 94 2949 I 0.03 1 2.79 Shallow oitting. U. Deposits. 95 2980 ( 0.04 I 2.79 Shallow nittinQ. 96 3011 ( 0.ü3 1 ( 2.83 I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I REPORT JOINT lATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-30 WE 3RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska USA March 31, 2007 I I I Joint Jt. Depth Peli Pen. Pen Iv\elal Min. Damage Profile No. (Ft.) \:;::el Body I 1.0. Comments wall) (Ins.) (Ins.) 0 50 100 97 1042 () 0.04 ''j 2.83 Shallow corrosion. Lt Deposits. 98 3073 0.03 ( 2.86 Shallow corrosion. 99 3104 0.04 2.87 Shallow corrosion. 100 3135 0.04 2.87 Shallow corrosion. 1 7 0.ü3 2.83 Shallow corrosion. U. Denosits. 102 1198 0.14 2.31 Line corrosion. 103 3230 :)~OO 2.84 Line corrosion. Lt. DeDosits. 104 3262 2.32 Line corrosion. 105 3292 15 2.81 Multinle HOLES I 106 3324 () 1 ) 0.03 1 3 2.83 Shallow corrosion. 107 3354 0.13 51 2.87 Line corrosion. It Denosits. 108 3385 0.04 17 I 2.84 Shallow line corrosion. 109 3417 0.06 n 2.83 Line corrosion. I 110 3448 0.05 20 2.82 Line corrosion. 111 3480 0 0.08 33 6 11ti ~11 0 0.10 39 6 Line corrosion. 113 42 0 ±m1 2.82 114 3574 0 2.86 Line corrosion. 115 3604 0 ¡ 2.86 Line corrosion. 116 3636 0.02 ~ L t. DelJosi ts. 117 3667 I 0.04 Shallow oittinQ. 118 3698 ( 0.04 ! 2.86 Shallow corrosion. 119 3729 ( 0.08 2.86 Line corrosion. 120 3760 0 0.04 15 6 2.85 Shallow corrosion. 121 3791 0 0.ü3 13 4 2.84 Shallow oittim!. 122 3822 0.02 4 2.31 123 3852 0.02 2.81 124 3884 0.04 2.82 Shallow corrosion. II! 125 3916 0.03 2.85 126 3947 0 0.03 2.90 I 127 3979 011 0.04 1 2.82 Shallow corrosion. 128 4010 0 0.ü3 13 4 2.81 Shallow oiUinQ. U. Deoosits. 129 4042 0 0.02 9 4 2.85 130 4073 0.03 I 3 2.85 Shallow oittim!. 131 4103 0.05 2.86 Shallow corrosion. Lt. Deposits. 132 4135 0.04 2.83 Shallow pittim!. It. DepOsits. 133 4166 0.04 2.83 Shallow corrosion. 133.1 4198 0.02 :¡ 2.80 PUP U. Deoosits. 133.2 4206 o~=r N/A GlM 1 (Latch @ 1 :om 133.3 4213 0 0.05 2.80 PUP Shallow corrosion. U. DeIJosi ts. 134 4221 0 0.ü3 0 2.88 135 4251 0.04 7 2.85 Shallow line of pils. Lt. DeDosits. 136 4284 0.02 ¡ 2.82 137 4315 0.02 ¡ 2.83 138 4345 ( 0.04 '1 2.82 Shallow nittinQ. 139 4377 0.02 ¡ 2.83 140 4409 0 0.04 17 1 2.86 Shallow corrosion. 141 4440 0 0.03 12 3 2.86 142 447' n lli~ 24 5 2.83 Line corrosion. 143 4502 n 6 3 2.84 Lt. Deposits. I I I I I I I I I I I I Penetration Body Metal Loss Body Page 3 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 3M-23 Kuparuk ConocoPhíllips Alaska USA March 31,2007 I Joint Jt. Depth Pe Pen. Pen. ¡\Aelal Min. Damage Profile No. ·1 Body I.D. Comments (%wa II) (Ins) (Ins.) (Ins.) 0 50 100 144 4534 ( 0.03 H ) 2.82 145 4566 ( 0.03 1 S 2.84 Shallow oittinQ. 1411 4597 ( 0.ü3 1 2.87 Shallow line corrosion. 147 I 41128 i 0.04 1 2.84 Shallow corrosion. 148 4659 ( 0.03 1 2.88 Shallow corrosion. 149 4690 ( 0.04 1 2.83 Shallow line corrosion. Lt. Deoosi ts. 150 4721 0 0.03 1 2.85 151 4753 0 OMI 2.87 Shallow corrosion. LL Deoosits. 152 4784 0 0.03\ 2.87 Shallow corrosion. 153 4815 0 0.02 1" 2.85 Lt. Deoosi ts. 154 4846 0.ü3 S 2.87 Shallow corrosion. 155 4877 i 0.04 I S 2.87 Shallow corrosion. 156 490' 0.05 I 2.86 Shallow line of oits. 157 4940 i 0.03 ) 2.83 158 4971 0 0.02 8 1 2.80 159 5002 0 0.03 1 "4 2.83 Shallow corrosion. 160 r:;m4 0 0.04 1, ~a8 Shallow corrosion. 161 5065 01 ) 0.05 I 2.84 Shallow nittíng. 162 5096 0 0.03 82 Shallow oitting. Lt. DeDosits. 163 5127 0 0.05 . 2.87 Shallow corrosion. 164 5159 () 0.ü3 S 2.86 Shallow niWna. 165 5190 0 0.ü3 1 2. 'nittim:!. , 166 5221 () 0.04 r, 2.82 Shallow corrosion. 167 5253 0 0.02 "4 2.86 till 5283 0 0.04 I 1 2.84 Shallow corrosion. 5315 () 0.04 1 ) \ 2.80 Shallow nittirw. 170 5346 01/ 0.04 1 2.81 Shallow corrosion. 171 5377 0 0.04 I 2.83 Shallow corrosion. 172 5409 0 0.04 I 2.80 Shallow nitting. Lt. DeDosits. 173 5439 () 0.03 1 2.80 174 5471 0 0.04 1 2.83 Shallow corrosion. 175 5502 0 0.04 1 h 2.86 Shallow corrosion. 176 5533 ( 0.04 1 ¿ 1 2.85 Shallow corrosion. 177 5565 0.05 2( h 2.85 Line Corrosion. 178 5596 0.ü3 1 2.85 Shallow nitting. 179 5628 0.04 I 2.84 Shallow corrosion. 180 5659 0.04 1 2.84 Shallow corrosion. 181 5690 0 0.03 2.83 Lt. Deoosits. ~ 182 5722 0 0.04 2.84 Shallow corrosion. 183 5753 0 0.04 2.87 Shallow corrosion. II 184 5785 0 0.ü3 2.85 Shallow oittina. 185 5816 0 0.03 1 -f: 2.84 Shallow nitting. 186 5847 ( 0.04 I' S 2.84 Shallow nitting. 187 5878 i 0.05 1 10 2.85 Shallow corrosion. 188 5909 I 0.02 2.80 oittimL 189 5940 I 0.04 1 2.81 Shallow corrosion. 190 5971 0 0.03 1 2.81 191 6002 0 0.03 13 ) 2.83 Shallow corrosion. Lt. Denosits. 192 6034 0 0.ü3 11 ~i 2.84 193 6066 () 0.04 14 4 2.84 Shallow corrosion. I I I I I I I I I I I I I Body Metal Loss Body Page 4 I I I PDS JOINT TABU ON S I Pipe: Body Wall: Upset Wall: Nominal J.D.: 3.5 in 9.3 ppf L-80 WE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhiilips Alaska USA March 31,2007 I I Joint Jt. Depth Pen. Pen. PerL [Metal Min. Damag e Profile No. (Ft.) 'I Body 1.0. Comments ('Yo wall) (Ins (Ins.) (Ins.) 0 50 100 194 6097 ¡ 0.03 m 2.86 ~ 195 6128 I 0.03 2.85 1% 61S9 0.03 2.83 Lt. Denosi ts. 197 6190 I 0.02 2.86 Lt. Denosits. 198 6222 0 0.05 21 4 2.80 Line corrosion. 199 6251 0 0.03 10 4 2.82 200 6282 0.04 15 ;¡ 2.B? Shallow corrosion. 201 ~~ ( 0.03 I( if 2.B5 Lt. Denosí ts. 202 0.03 1 I, 2.86 203 0.03 I H 2.79 Shallow nittinll. Lt. Deoosits. 204 6408 0.03 1 2.79 nittina. 205 6439 0.04 1 2.83 Shallow oittim;!. 206 6471 ( 0.03 1 2.84 Shallow níttina. 207 6502 0.02 9 2.86 208 6533 0 0.04 1 2.81 Shallow corrosion. 209 6565 i 0.04 1 2.81 Shallow corrosion. 210 6596 0 0.06 n m Corrosion. 211 6628 0.03 I 2.84 212 6659 ( 0.02 9 U. Denosi ts. 213 6690 ( 0.03 11 . 2.79 214 6722 ( 0.03 13 2.85 Shallow niHina. It. Denosits. 215 6753 () 0.05 19 2.83 Shallow corrosion. 216 6784 (112 0.04 14 2.81 Shallow corrosion. 217 6816 ( 0.06 23 ti 2.82 Corrosion. 218 6846 I 0.03 12 ;; 2.84 219 6878 0.04 6 1 2.86 Shallow corrosion. 6909 I 0.03 2.83 Lt. Denosits. H#= 6940 0.04 6 2.87 Shallow corrosion. Lt. Deoosits. 222 6971 0.04 2.82 Shallow corrosion. 223 7003 0 0.05 q 2.83 Corrosion. 224 7034 0 0.03 2.86 Shallow nittina. Lt. Denosits. 225 7065 I) 0.04 1· C; 2.80 Shallow nittinQ. 226 7097 I 0.03 1 4 2.82 227 7128 0.03 I. 1 2.84 Shallow corrosion. Lt. Deoosits. 228 7159 0.03 2.84 Shallow corrosion. ¡ 229 7191 ( 0.05 2.84 Shallow oittim/.. 230 7221 ( 0.04 2.82 Shallow corrosion. Lt. Denosits. 231 7254 0 0.05 2.82 Shallow corrosion. 232 7285 0 0.03 2.81 233 7315 0 0.03 12 I; 2.84 234 7345 í 0.04 17 \ 2.86 Shallow corrosion. 235 7377 ( 0.04 17 h 2.86 Shallow corrosion. 236 7408 í 0.04 1 4 2.85 Shallow corrosion. U. Deoosits. 237 7439 I 0.ü3 ¡ þ2.87 237.1 7471 I 0.03 I 2.80 PUP 237.2 7479 ( 0 0 11 N/A GLM 2 (Latch @ 3:301 == 237.3 7486 0 0.04 ( 1 2.77 PUP Shallow corrosion. Lt. Deoosits. 238 7494 0 0.04 17 . I, 2.85 Shallow corrosion. 238.1 7522 0 0.02 4 2.84 PUP 11I"'1 238.2 7528 0 0 0 0 N/A SEALS I I I I I I I I I I I I I I Body Metal Loss Body Page 5 I I I I Pipe: Body Wall: Upset Wall: NominaIID.: I I Joint Jt. Depth No. (Ft.) I 238.3 7548 I I I I I I I I I I I I I I REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L·80 WE 8RD 0.254 in 0.254 in 2.992 in Well: field: Company: Country: Survey Date: PACKER 6 3M-23 Kuparuk ConocoPhillips Alaska USA March 31, 2007 Comments Damage Profile (%wall) o 50 100 Body Metal Loss Body .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. .. PDS Repo ss Sections 3M-23 Kuparuk ConocoPhillips Alaska USA 3.5 ins 9.3 f L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: March 31,2007 MFC 24 No 40665 1.69 24 . Thom son Cross for Joint 105 at depth 3308.14 ft Tool speed ~ 51 NominallD 2.992 Nominal OD ~ 3500 Remaining wall area ~ 86 % Tool deviation 960 Finger 7 Penetration ~ 0.324 ins Multiple Holes 0.32 ins ~ 100% Wall Penetration HIGH SIDE ~UP Cross Sections page 1 .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. 3M·23 Kuparuk ConocoPhil!ips Alaska USA 3.5 ins 9,3 f L·80 WE 8RD Tool speed 49 NominallD'" 2,992 Nominal OD '" 3,500 Remaining wall area'" 94 % Tool deviation'" 62 0 71 at .. .. .. .. .. .. .. s Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: son ft Finger 7 Penetration'" 0.195 ins Line Corrosion 0,20 ins'" 77% Wall Penetration HIGH SIDE'" UP Cross Sections page 2 .. s .. .. .. I KRU 3M-23 I .~ 1311/1..23\ TUBING API: 500292242600 Well TIlDe: I PRo[ (0-12283, SSSV Tvoe: NIPPLE Orig Com olelíon: 12/29/1993 ~ 00:3.500, Annular Fluid· LastW/O: 7/1812006 . 0, PULL RHC, 10:2.992) LEAKS FOUND -. Ref LOQ Date: Last Update: 81712006 : 12491' RKB TO: 12750 ftKB Last : Max Hole Anale: 70dea@11019 Description Size Top Bottom TVD wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE 9.625 0 3306 2530 53,50 J-55 BTC PRODUCTION 7000 0 12721 6374 26.00 L-80 BTC-MOD SURFACE 9.625 3306 5265 3246 36.00 J-55 BTC SURFACE 9625 5265 5349 3276 53.50 L-80 BTC-MOD SURFACE 9.625 5349 5437 3307 3600 J-55 BTC LEAK 7000 7695 7728 4141~ ~K 7.000 9214 9275 4710 Size Top I Bottom I TVD I wt I Grade I Thread 3.500 0 I 12283 I 6060 930 I L-80 I ~ 3.500 12283 12325 I 609C 9.30 I L-80 I Interval TVD Zone Status Ft SPF Date Tvpe Comment 12423 - 12443 6160 - 6174 C-4 20 4 9/1212001 APERF 2 1/8" Enerjet wIP J chgs, 0 deg oh +/- 90 dea orient 12450 - 12466 6179 - 6191 A-2 16 4 9f112001 APERF 2 1/8" Enerjet wIP J chgs, 0 deg ph +/- 90 deQ orient 12474 - 12484 6197 - 6204 A-1 10 4 916/2001 APERF 2 118" Enerjet wIP J chgs, 0 deg Dh +/- 90 dea orient 12484 - 12494 6204 - 6211 A-1 10 8 9/12/2001 RPERF 2 1/8" Enerjet wIP J chgs, 0 deg ph +/- 90 deQ orient 12· 194 - 12502 3211 - 6217 A-1 8 4 4/23/1994 IPERF 4.5" BH Ultrapak 180 deQ ph iG~: <I :',ii·.'ii·'ii: Sf MD TVD Man Man Type VMfr I VType VOD Latch Port :ii "". R"" Vlv Mfr Cmnt 1 4205" KBUG I GLV 1.0 BK 0.156 7/29/2006 2 7479 KBUG ~1.0 BK 0.250 i Depth TVO Tvpe Description 10 31 31 HANGER GEN IV TUBING HANGER 3.500 518 518 NIP 2.875 7528 4067 LOCATOR BAKER LOCATOR wINO GO RING ON THE BOTTOM 2.990 7533 4069 SEAL BAKER 8040 SEAL ASSEMBLY 2.990 12267 6049 NIP CAMCO OS NIPPLE 2.812 _OCATOR BAKER LOCATOR 3.000 SEAL BAKER GBH-22 SEAL ASSEMBLY ~ De h Tvpe Description 7522 I 4065 SLEEVE HR LINER SETTING SLEEVE wINO GO 00579",104.42" 4.420 7536 I 4070 NIP BAKER RS PACK OFF SEAL NIPPLE 4.250 ~ PBR BAKER 80-40 PBR 4.250 7551 PACKER BAKER 7" RETRIEVABLE PACKER 2.930 Depth TVD TilDe Description 10 12282 6059 PBR BAKER 8040 2.992 12283 6060 ANCHOR BAKER KBH-22 K-ANCHOR 3,000 LOCATOR 12297 6070 PKR BAKER SAB-3 PACKER 3.250 (12282-12283, 12313 6081 NIP CAMCO 0 NIPPLE. 9/14/99 2.750 00:4.250) 12325 6090 SOS BAKER SHEAR OUT SUB 2.992 TUBING (12283-12325, Date Note OD3500, 7/10/2006 LEAKS FOUND IN THE 7" CASING @ 7695'-7728' and tãJ 9214'-9275' ISOLATED BETWEEN PACKERS ID:2992) 7/18/2006 TREE: 3-1/8" 5 Ksi FMC GEN IV TREE CAP CONNECTION 3" OTIS = r--- Perf f-- (12474-12484) - c--- Perf -- ~- (12484-12494) - f---- Perf -- ~ (12484-12502) - - PRODUCTION f---.. (0-12721, - ~ OD7.oo0, - Wt26 00) _. I I I I I I I I I I I I I I I I I I . . I -./ ConocoPhillips Alaska. Ino. Tubing Detail 3 1/2" Tubina Detail Well: Date: 3M-23 07/17/06 I DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Oriainal Drillina Ria: RKB to Tubing Head Lock Down ScreW! 31.25 FMC 3-1/2" Gen IV Tubina Hanaer wI 2.45' Pin X Pin Pup J1 2.97 31.25 Jts 389 to 389 1 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.91" 31.20 34.22 Space Out Pups, 3-112", 9.3#, L-80, EUE 8R Mod Tbg, 2.91" drift (10.10' + 8.04') 18.14 65.42 Jts 375 to 388 14 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.91"' 434.77 83.56 Cameo 3-112" "OS" Nipple, 2.875" [) 4.62" OD 1.57 518.33 Jts 257 to 374 118 Jts 3-1/2",9.3#, L-80 EUE 8R Mod Tubing, drifted to 2.867" 3681.63 519.90 Tubing Measurement / Depth Correction - 133 Jts above -4.03 4201.53 Pup Joint, 3-112", 9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.867" 8.17 4197.50 Cameo 3-1/2" X 1" KBUG GLM wI Dummy. BK-5 Lateh 5.39" OD, 2.920"ID 6.54 4205.67 PuP Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.867" 7.98 4212.21 Jts 153 to 256 104 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.867" 3254.34 4220.19 Tubing Measurement / Depth Correction - 104 Jts above -3.18 7474.53 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.867" 8.01 7471.35 Cameo 3-1/2" X 1" KBMG, DCK-2 Shear Valve. BEK Latch, 5.39" OD, 2.920" ID 7.02 7479.36 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.867" 8.14 7486.38 Jts 152 to 152 1 Jts 3-1/2",9.3#, L-80, EUE 8R Mod Tubina, drifted to 2.867" 28.38 7494.52 PuP Joint, 3-1/2", 9.3# L-80, EUE 8R Mod Tubing, drifted to 2.867" 6.07 7522.90 Baker Locator, 5.0" 00 No Go Ring on bottom 1.57 7528.97 No Go Locator / Seal Assembly was Spaced out 2' above fully landed position 2.00 7530.54 Baker Seal Assemblv, Size 80-40,4" 00 Seals, 2.99" 10, 18.18' Long 7532.54 Bottom of Seal Assembly / Mule Shoe @ 7548.72' Straddle Packer Assemtl/v set with Drilloioe on 7/16/06 Toþ of Settina Sleeve @ 7522.39' No Go Landing Ring is 10.15' below Toø of Sleeve a 7532.54' "HR" Liner Setting Sleeve, 5.79" 00, (:;.25" 10 Bore for DP setting tool 10.15 7522.39 No Go in "HR" Liner Setting Sleeve 5.?9" 00, 4.42" 10 at No Go 3.86 7532.54 Baker "RS" Pack-Off Seal Nipple, 5.57" 00, 4.25" 10 2.49 7536.40 Baker PBR, Size 80-40, 5" 00, 4" Seal Bore 12.41 7538.89 Baker 7" "FHL" Rerievable Packer 5.97" 00, 2.93" 10 7.43 7551.30 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R Mod Tubing, drifted to 2.850" 2.27 7558.73 Jts 1 to 151 151 Jts 3-1/2" 9.3# L-80 EUE 8R Mod Tubinq, drifted to 2.867" 4704.60 7561.00 Tubing Measurement / Depth Correction .- 151 Jts above -4.58 12265.60 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R lVIod Tubing, 4.19" 00 SCC, drifted to 2.867" 6.14 12261.02 Cameo 3-1/2" "OS" Nipple, 4.19" OD, 2.812"ID, wI RHC Plug .96 12267.16 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R lVIod Tubing, 4.19" 00 SCC, drifted to 2.867" 6.15 12268.12 Pup Joint, 3-1/2", 9.3#, L-80, EUE 8R lVIod Tubing, 4.19" 00 SCC, drifted to 2.867" 8.02 12274.27 Baker Locator, 4.25" 00 .17 12282.29 Locator / Seal Assembly was Spaced out l' above fully landed position 1.00 12282.46 Baker GBH-22 Seal Assembly, Size 80-40,4" 00 seals, 3" 10, 11.49' Long 12283.46 Bottom of Seal Assembly / Mule Shoe @ 12,293.95' Existinø P8RlPacker and Tail Assemblv set on 1/23/99 Baker PBR, 4" seal bore 13.02 12283.46 Baker KBH-22 Anchor Seal Assembly .92 12296.48 Baker SAB-3 Permanent Packer 4.91 12297.40 Crossover, 4-1/2" NU Pin X 3-1/2" EUE Pin .92 12302.31 Pup Joint, 3-1/2", 9.3#, L-BO, EUE-BRD Tubing 10.14 12303.23 Cameo 3-1/2" D-Nipþle, 2.750" ID 1.00 12313.37 Pup Joint, 3-1/2': 9.3#, L-BO, EUE-BRD Tubing (Special 6.151" Drift on collar) 10.13 12314.37 Baker Shear Out Sub / Wire/ine Re-entry Guide .90 12324.50 Bottom of Tail 12325.40 Remarks: Used Jet-Lube Pipe Dope. Average Torque 2000 ft-Ib. Drifted Tubing with 2.867" plastic rabbit. Drifted top 15 joints, space out pups, and tubing hanger to 2.91". Upper String: 83K# PU, 5OK# SO, 38K# Block Weight. Straddle PackerfTail Assy: 145K# PU, 73K# SO with 3-1/2" DP -105K#PU, 63K# SO after releasing DP - 68K# PU, 53K# SO before RIH on DP, 38K# Block Weight. Dropped 1-5/16" ball on rod and roller stem to RHC Plug in OS Nipple @ 12267'. Nordic Ria #3 Supervisor: Peter Wilson / Don Breeden I I I I I I I I I I I I I I I I 03/20/07 Schlumberger oJJ- ~r,h~lMi':r'j APR 0 3 2007 u~~D't~ NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Ivi I~ I) ¡]I 2. Z."Ot')7 1"\1\ ,.. . _ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Oilt), 193-/~~ Kuparuk Field: Well Job# Log Description Date BL Color CD 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1 E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 35-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1C-10 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 1 D-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 r Please sign and return one copy ofthis transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ì-S~' . . . ~ ConocOPhillips . Gary Eller Wells Engineer Drilling & Wells August 7, 2006 p. O. Box 100360 AnChorage, AK 99510-0360 Phone: 907-263-4172 CommisSioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 AnChorage, Alaska 99501 RECEIVED AUG 09 2006 Commission Alaska Oil & Gas Cons. Anchorage Subject: Report of Sundry Well Operations for 3M'23 Dear Commissioner: If you have any questions regarding this matter, Please COntact me at 263-4172. ConoCOPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent WOlkover of KUparuk Well 3M-23. \'~' J'~~II~ ( W~gin~ CPAI Drilling and Wells "," .11\,11\1 ¡:: r' ;:\ 1I G~ '7 .,1 ,jiv.'OI:'J....:J ., _ JGE/skad lCj3_ i~ . RECEIVt::U . . 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other U Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 193-187/306-240 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22426-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' 3M-23 8. Property Designation: 10. Field/Pool(s): ADL 25524:ALK 2655 Kuparuk River Field 1 Kuparuk Oil Pool. 11. Present Well Condition Summary: Total Depth measured 12750' feet true vertical 6394' feet Plugs (measured) Effective Depth measured 12491' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 89' 16" 121' 121' SURFACE 5405' 9-5/8" 5437' 3307' PRODUCTION 12690' 7" 12721' 6374' Perforation depth: Measured depth: 12423'-12443', 12450'-12466', 12474'-12502' true vertical depth: 6160'-6174',6179'-6191',6197'-6217' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12325' MD. Packers & SSSV (type & measured depth) pkr=Baker 7" retrievable pkr, BAKER SAB-3 PACKER @ 7551',12297' Cameo 'OS' nipple @ 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 200 126 3087 -- 159 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasO WAG 0 GINJO WINJO WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Coo"ct ,~=~172 Printed Name Gary Elle Title Wells Group Engineer ~\~\ Signature Phone "-\C>ì-LÍç¡~ ~ \ l'"2.. Date ()\o Prena""d bv Sharon IIRun-DrakE> 263-4612 Form 10-404 Re:ised 04~04 RBDMS BFl AUG 1 0 2006 ~ ~_ 8''''~ ~g9~ Sub I Origin Onl AUG 0 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIO~ska Oil & Gas Cons. Commission STATE OF ALASKA . ORIGINAL ( \ù y ConocoPhillips 'aSka, Inc. . KRU 3M-23 ~ 3M-23 TUBING API: 500292242600 Well Type: PROD Angle (â! TS: 44 dec¡ (â! 12409 (0-12283, SSSV Type: NIPPLE OriQ Completion: 12/29/1993 Angle (á) TD: 44 dea (â! 12750 00:3.500, Annular Fluid: Last W/O: 7/18/2006 Rev Reason: WORKOVER 10:2.992) Reference Loa: Ref Loa Date: Last Uodate: 7/25/2006 Last Taa: 12491' RKB TD: 12750 ftKB ~axHoleAnQle: 70dec¡@ 11019 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE 9.625 0 3306 2530 53.50 J-55 BTC PRODUCTION 7.000 0 12721 6374 26.00 L-80 BTC-MOD SURFACE 9.625 3306 5265 3246 36.00 J-55 BTC SURFACE 9.625 5265 5349 3276 53.50 L-80 BTC-MOD SURFACE 9.625 5349 5437 3307 36.00 J-55 BTC Tubina Strina - TUBING Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 12283 I 6060 I 9.30 I L-80 I EUE8RD 3.500 12283 I 12325 I 6090 I 9.30 I L-80 I EUE8RD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment - - 12423 - 12443 6160 - 6174 C-4 20 4 9/12/2001 APERF 21/8" Enerjet wlPJ chgs, 0 dea oh +1- 90 dea orient 12450 - 12466 6179 - 6191 A-2 16 4 9/7/2001 APERF 21/8" Enerjet w/PJ chgs, 0 - dea oh +1- 90 dea orient 12474 - 12484 6197 - 6204 A-1 10 4 9/6/2001 APERF 2 1/8" Enerjet w/PJ chgs, 0 dea oh, +1- 90 dea orient 12484 - 12494 6204 - 6211 A-1 10 8 9/12/2001 RPERF 2 1/8" Enerjet w/PJ chgs, 0 dea oh, +1- 90 dea orient 12494 - 12502 6211-6217 A-1 8 4 4/23/1994 IPERF 4.5" BH Ultrapak 180 deo ph Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 4205 2859 CAMCO KBUG DMY 1.0 BK-5 0.000 0 7/17/2006 2 7479 4049 CAMCO KBUG SOV 1.0 BEK 0.000 0 7/17/2006 DCK-2 Other [pluas, eauip., etc.) - COMPLETION 7/17/2006 Depth TVD Type Description ID 31 31 HANGER GEN IV TUBING HANGER 3.500 518 518 NIP 2.875 7528 4067 LOCATOR BAKER LOCATOR wINO GO RING ON THE BOTTOM 2.990 7533 4069 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 12267 6049 NIP CAMCO DS NIPPLE - 2.812 12282 6059 LOCATOR BAKER LOCATOR 3.000 12283 6060 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 Other fpluas, equip., etc.) - STRADDLE PACKER ASSEMBLY (Repair Casina Holes w/Drill Pipe Depth TVD Type Description ID 7522 4065 SLEEVE HR LINER SETTING SLEEVE wINO GO OD 5.79", ID 4.42" 4.420 7536 4070 NIP BAKER RS PACK-OFF SEAL NIPPLE 4.250 LOCATOR 7539 4071 PBR BAKER 80-40 PBR 4.250 (12282-12283, 7551 4075 PACKER BAKER 7" RETRIEVABLE PACKER 2.930 00:4.250) Other plugs, eauip., etc.) - COMPLETION 1/23/1999 Depth TVD Type Description ID TUBING 12282 6059 PBR BAKER 80-40 2.992 (12283-12325, 12283 6060 ANCHOR BAKER KBH-22 K-ANCHOR 3.000 00:3.500, 12297 6070 PKR BAKER SAB-3 PACKER 3.250 10:2.992) 12313 6081 NIP CAMCO D NIPPLE. 9/14/99 2.750 12325 6090 SOS BAKER SHEAR OUT SUB 2.992 General Notes Date I Note 7/18/2006 I TREE: 3-118" 5 Ksi FMC GEN IV TREE CAP CONNECTION: 3" OTIS ì f\()/ O~ - \-o~.AQ.ò... \~(:<\\.'> . 1'" Co.o;' \ "'~. \}.~~Q....'+^C)..\ \~,,~\.. ',05 '''' 'b ""\ \r-I Q.. ~ '" ., \:¡~s.' - ì -,~~. N\.t). '-Ç)",,~<' "'^-O<¡,~ \'to'.~ '" Perf - - ~x\""~~'" "'-\1..\6," - ~1..1 '5' (12474-12484) ~ ~ ~~. Perf = = (12484-12494) = = Perf = = (12484-12502) = = , ROOUCTION == (0-12721, - - 00:7.000, - - Wt:26.00) - - - - ConocJ'Phillips WelJvíew Web RepDrtlng Time log Summary . 06/30/2006 00:00 02:00 2.00 0 0 MIRU MOVE PSIT P Move rig from we1l3M-14 to 3M-23, spot, level and berm cellar, take on kill wt mud, Acce ted Ri at 02:00 hrs 02:00 12:00 10.00 0 0 MIRU MOVE RURD P Rack and Tally 31/2" DP, spot service shack and tanks, RU circ lines, hardline and kill tank, pressure test all lines, RU lubricator to uIlBPV. 12:00 13:00 1.00 0 0 RPCOr-. SFTY P Hold PJSM with rig crew and DSO on well kill, check line u of valves. 13:00 15:30 2.50 0 0 WELCT CIRC P Open tree to circ, SITP 1,820 psi, SICP 1,770 psi, break circ and pump kill wt 13.6 ppg Potassium Formate from 4 bpm to 6 bpm, 1,100 psi, pumped 420 bbls with a max of 13.1 ppg returns and ran out of kill wt mud, shut dwn and shut in well to monitor while transporting more mud from lant. 15:30 16:30 1.00 0 0 COMPZ WELCT OWFF P SITP and SICP at 350 psi, pressure bled off to 150 psi in tubing and annulus. 16:30 17:00 0.50 0 0 P Bull head 10 bbls kill wt mud dwn tubing at 1 bpm, 1,020 psi and shut in to monitor. 17:00 20:30 3.50 0 0 COMPZ WELCT OWFF P SITP and SICP at 70 psi, blow dwn hardline and demob kill tank, load 240 bbls 13.6 ppg mud in pits, cont rack and tall 31/2" DP. 20:30 22:30 2.00 0 0 COMPZ WELCT CIRC P Begin circ kill wt mud dwn tubing, losing 2 bpm while circ at 4 bpm, 1,100 psi, reduced pump rate to 2 bpm, 700 psi, max mud wt returns 13,4+ ppg, shut dwn, bled off, shut in to monitor well. 22:30 00:00 1.50 0 0 P SITP at 10 psi, SICP at 50 psi, annulus bled off to 20 psi, bled off tubing and annulus and observed for flow, no flow. 07/01/2006 00:00 00:30 0.50 0 0 P Cont monitor well, SICP at 20 psi, SITP at 10 psi, bled off well and watched for flow, no flow. 00:30 01:00 0.50 0 0 P Blow dwn circ lines and install BPV. 01:00 02:30 1.50 0 0 P ND tree and install blanking plug. 02:30 07:30 5.00 0 0 P NU 11" BOP stack and CO lower rams to 3 1/2". 07:30 11:30 4.00 0 0 P Test all BOP equipment at 250 psi low and 3,500 psi high, RD test equipment. State witness waived by Lou Grimaldi. 12:30 13:30 1.00 0 0 P Attempt to pull hanger to rig floor, up wt 200K, strin did not ull free. 13:30 18:30 5.00 0 0 P RU and circ 2 bpm at 720 psi, rate up to 3 bpm 820 psi, had max gas 3,000 units. 18:30 00:00 5.50 0 0 T PJSM, RU SWS and RIH with string shot, at 3,800' tool would no longer drop, RU and pumped tool dwn hole at 1/2 b m, 500 si. 07/02/2006 00:00 02:30 2.50 0 0 T Cont RIH with 1 11/16" string shot, pumping 1/2 to 2 bpm, 500 to 800 psi, could not et ast 8,750'. 02:30 04:00 1.50 0 0 T POOH w/string shot and LD same. 04:00 09:30 5.50 0 0 T PJSM, re-set string wt in slips from 170K to 140K, RU sheave and MU 2 5/8" chem cutter, RIH, had to start pumping tool dwn at 3,300', could not get past 7,750' WLM, cut tubing at 7,750'. 09:30 12:00 2.50 0 0 T POOH with chem cutting tool, at 2,816' anchors released and tool hung u . 12:00 13:00 1.00 0 0 T CBU at 3 bpm, 900 psi, max gas 206 units. 13:00 17:00 4.00 0 0 T Cont POOH with cutting tool on e-line, anchors trying to grab at every coupler, LD cuttin tools, RD SWS. 17:00 19:30 2.50 0 0 T Pull hanger to floor, up wt 85K, LD hanger and landing jnt, CO bails on To Drive, RU to circ dwn tubin . 19:30 00:00 4.50 0 0 COMPZ RPCO~ PULD T PU and MU 31/2" DP stnds in mousehole, rack back in derrick, cont circ at 2 b m, 700 si 07/03/200600:00 07:00 7.00 0 0 T Cont PU and MU 3 1/2" DP stnds in mousehole, rack back in derrick, cont circ at 2 b m, 700 si 07:00 08:00 1.00 0 0 COMPZ RPCO~ RURD T RD DP handling equip, RU tubing handling equip, on load Baker Fishing Tools. 08:00 13:30 5.50 7,750 0 COMPZ RPCO~ TRIP T RD circ lines, POOH with 31/2" tubing and stnd back in derrick. Pulled 246 joints 31/2" tubing, length 7,646', 2 mandrell's with pup's, length 41', DS nipple, length 1.5', hanger and pup, length 3.98', and cut off jnt, length 18.18'. Cut off jnt had numerous large pittted areas, the joint above the cutoff had 2 lar e holes, 15' above in end. 13:30 17:30 4.00 0 7,679 COMPZ FISH TRIP T MU fishing assembly, RIH with 3 1/2" DP from derrick to 7,679'. Break circ at 2 bpm, 950 psi, torque off btm 3,800 ftIlbs, up wt 115K, dwn wt 65K, rot wt 81 K, ease dwn over top of fish, tagged at 7,740' DP measurment, engage fish and attempt to pull tubing, max u wt 265K with no movement. 18:30 19:30 1.00 7,740 7,740 COMPZ JAR T Jar on fish while circ at 2 bpm, 1,100 si, no movement. 19:30 23:30 4.00 7,740 7,740 CIRC T Gas units increasing, stop jarring, CBU 1 1/2x through open port in GLM at 12,229', max as 350 units. 23:30 00:00 0.50 7,740 7,740 T Release grapple/overshot from fish, blow dwn Top Drive, fill trip tank while monitorin well to POOH 07/04/2006 00:00 05:00 5.00 7,740 0 TRIP T POOH stnd back 3 1/2" DP and 4 3/4" DC's. LD bumper sub, oil jar, intensifier and um out sub 05:00 05:30 0.50 0 0 OTHR T Installed wear bushing 05:30 06:00 0.50 0 6 PULD T CO grapple and MU overshot, extension and to sub. 06:00 08 :45 2.75 6 7,374 TRIP T RIH with fishing BHA #2 on 31/2" DP to 7,374' 08 :45 09 :45 1.00 7,374 7,740 TRIP T Cont RIH with BHA #2 PU 12 jts of 3 1/2" DP RIH from 7,374' and tagged TOF at 7,740', spaced out string with 2-6' DP u s 09:45 10:00 0.25 7,740 7,740 COMPZ FISH FISH T Est circ at 50 gpm at 790 psi, st wt up 100K, dn wt 65K rot wt 80K, Latched onto fish at 7,740', pulled 50K tension on fish and set DP sli s 10:00 11:00 1.00 7,740 7,740 EVALv\ RURD T RU pump in sub and safety valve, chan ed out elevator bales for wireline 11:00 13:30 2.50 7,740 7,740 EVALv\ RURD T Held PJSM with Schlumberger wireline and RU same, plan was to run a 2 318" chemical cutter and with 3 1/2" DP the tool jt ID is 27/16", the decisoin was made to run a 2 118" cutter for better clearance 13:30 19:00 5.50 7,740 7,740 COMPZ EVALv\ CIRC T Circ hole at 2 bpm at 1,000 psi while waiting on 21/8" chemical cutter, max gas was 240 units with BGG ave 50 units, circ at 2 b m with no losses 19:00 22:30 3.50 7,740 8,550 COMPZ FISH ELNE T MU 2 1/8" cutter, RIH to 2,400', start pumping tool dwn hole at 1 bpm, 700 psi, increased rate to 2 bpm 1,100 psi at 8,400'. Tool hung up at 8,520' with indication of a hole in tubing, worked tool dwn to 8,550' WLM and made cut leaving +/- 10' stub looking up, hole an Ie 68 de . 22:30 00:00 1.50 8,550 8,550 COMPZ ELNE T POOH with SWS e-line. 07/05/200600:00 01:00 1.00 8,550 8,550 COMPZ ELNE T Fin POOH with SWS E-line and used 2 118" chemical cutter, LD same & RD SWS Worked stuck tbg after making chemical cut at 8,550' WLM, worked st wt up to 240K and tbg came free, had 5K increase in st wt u 01:30 03:00 1.50 8,550 8,550 CIRC T Circ btms up from tbg cut at 8,550' WLM, staged pump rate up to 3.5 bpm at 1,180 psi, with no losses and max gas was 208 units, ave BGG 50 units, C/O elevator bales 03:00 06:30 3.50 8,550 0 TRIP T POOH with fishing BHA #2 from 8,550' to fish 06:30 07:15 0.75 0 0 RURD T RU 3 1/2" tbg handling tools 07:15 08:45 1.50 0 0 PULD T LD overshot with cutoff tbg and cont to POOH with 3 1/2", 9.3#, L-80 mod tbg, LD a total of 25 jts 780.58', and 2-cut pieces 1-inside grapple 12.95' from cut at 7,740' and btm cut at 20.62' from 8,550' WLM. (Total LD 814.15') Found tbg to have internal and external pitting on 1/3 of coupling, possibly from laying on low side of hole, on btm cut piece had a good 2/3 of tube cut from the cutter and pulled the other 1/3 loose, approx 14" from cut had a 1/2" wide x 1 1/4" long washout in the tbg. Original hole was est. at approx 8,570' and was found to be at approx 8,549' WLM. 08:45 09:15 0.50 6 6 COMPZ PULD T MU new 3 1/2" grapple on BHA #3 RIH to 6' 09:15 12:00 2.75 6 7,760 COMPZ TRIP T RIH with BHA #3 with 31/2" DP out of derrick to 7,760' 12:00 13:30 1.50 7,760 8,553 COMPZ TRIP T PU 25 jts of 31/2" DP out of pipe shed RIH with BHA #3 from 7,760' and tagged top of fish at 8,533' DP measurements, tbg was cut at 8,550' WLM, est circ at 1 bpm at 790 psi, rot wt 87K, up wt 120K, dn wt 65k, slacked off and latched onto fish, PU to 200K to confirm latch. 17:45 18:00 Est circ after latching onto fish at 8,553', GLM at 12,228' is open for circ. thru. staged pump rate up to 2.5 bpm at 1,400 psi, circ a total of 525 bbls with no losses, calc annulus volume from 12,228' is 322 bbls, after pumping 130 bbls bgg was 100 units, after 145 bbls bgg was 170 units, after 170 bbls, bgg was 220 units, 210 bbls was 511 units (210 bbls = 7,955' in the Ann.), after 228 bbls bgg maxed out at 740 units (228 bbls = 8,636'), bgg dropped to 150 units then at approx. 20 bbls after calc btms up from 12,228' (322 bbls) gas increased back up to 460 units before dropping out, after 380 bbls bgg was down to 330 units, after 450 bbls bgg was 170 units and after 525 bbls pumped bgg was down to 110 units. No losses while circ hole with 13.6 ppg potassium formate in and out. 740 units of gas from est. 8,636' could be from migration or possible hole in the cs 0.25 8,553 8,553 COMPZ FISH OTHR T Worked DP and tbg string attempting to pull out of seals, work string from 75K dn up to 210K up, calc 60K over DP and tb st wt with no movement 2.50 8,553 8,553 COMPZ EVALv\ RURD T Blow dwn Top Drive, CO bails, RU pump in sub and x-o's, hang sheave in derrick. 3.50 8,553 8,553 COMPZ FISH ELNE T PJSM, MU cutter, RIH to 2,500' and start pumping tool dwn hole at 1 bpm, 980 psi, at 8,000' increased pump rate to 1.5 bpm at 1,100 psi and at 11,100' increased rate to 2 bpm, 1,330 psi, tool at 11,950 WLM at 23:59 hrs 0.75 8,553 8,553 COMPZ FISH ELNE T Fin RIH with SWS 21/8" chemical cutter on e-line from 11,950' to 12,314' (EOT) , PU to 12,277', cont to pump cutter down at 2 b m at 1,330 si 0.75 8,553 12,277 COMPZ FISH ELNE T PU on tbg string to 200K, orig st wt up was 120K, calc st wt to 12,277' is 150K, (50K over) and set cutter on depth then cut tbg at 12,277' WLM, saw cutter fire with no chan e in st wt. 3.00 12,277 12,277 COMPZ FISH ELNE T POOH with 21/8" chemical cutter from 12,277', cutter's anchor began to drag at 4,200', began circ hole at 2 bpm at 1,220 psi while working cutter out of hole to 200' 1.50 12,277 12,277 COMPZ FISH ELNE T RD wireline scheave and pulled chemical cutter and LD same, had ood si n of 360 de cut from cutter 0.75 12,277 12,277 COMPZ FISH RURD T RD SWS pump in sub and safety valve, MU to drive to DP 18:00 20:30 20:30 00:00 07/06/200600:00 00:45 00:45 01 :30 01 :30 04:30 04:30 06:00 06:00 06:45 Worked DP and tbg string from 65K, orig. dn wt and staged up wt in 10K incriments from 200K up to 275K and after 2nd attempt at 275K tbg string pulled free, orig st wt up was 120K, calc st wt was 147K, new st wt after cut 157K, LD 1 single POOH to 12,265' 2.50 12,265 12,265 COMPZ FISH CIRC T Circ 1 complete hole volume from 12,265', staged pump rate up to 3 bpm, initial circ press was 1,530 psi, final circ press was 1,450 psi, max gas was 55 units, ave bgg was 35 units w/circ with 13.6 ppg potassium formate and no losses, changed out grabber dies and elevator bales on top drive while circ. POOH slow and wet with 3 1/2" DP and fish from 12,265' to fish est 3,724' left in hole RU to LD 31/2" tbg, LD overshot with 3 1/2" tb stub in ra Ie POOH LD 3 1/2" 9.3#, L-80, Mod tbg & fish, LD 115 full jts, 2 cut off jnts and 4 GLM's with pup's. Total length offish LD is 3,711.57', tubing and couplers looked to be in good shape. Lower cut off jnt was cut just above pin end, leaving 'W nipple, 6' pup and seal assembly in the hole. Tube was 2/3 cut and 1/3 was parted. Cut is even and no collapse or bulging. (Total completion equip LD to date is 12,236.35' + Nordic RKB of 26.30' = 12,262.65' 1.00 0 0 PULD T PU 1 jnt 3 1/2" DP, MU Baker Overshot and remove cutoff section from grapple, break dwn baker tools and clean floor. RIGMN SVRG P Slip and cut 48' of drilling line and serviced to drive P RIH with 82 stds (246 jts) of 3 1/2" 9.3#, L-80, EUE Mod tbg out of derrick to 7,645' RPCOfl. RURD P RU to LD 3 1/2" tbg 07:30 10:00 10:00 16:15 6.25 12,265 3,724 COMPZ FISH TRIP T 16:15 17:00 0.75 3,724 3,724 RURD T 17:00 23:00 6.00 3,724 0 FISH PULD T 23:00 00:00 07/07/2006 00:00 02:00 2.00 0 0 02:00 05:15 3.25 7,645 7,645 05:15 05:45 0.50 7,645 7,645 05:45 07:30 1.75 7,645 6,061 RPCOfl. PULD P POOH from 7,645' to 6,061' LD 51 jts of 3 1/2" tbg, (observed 208 units of gas at surface while RIH with tbg to 7,645' 09:00 11 :45 2.75 6,061 12,072 COMPZ RPCOr.. TRIP 11:45 13:45 2.00 12,072 12,072 COMPZ RPCOr.. CIRC 13:45 16:30 2.75 12,072 6,061 16:30 17:15 0.75 6,061 6,061 17:15 00:00 6.75 6,061 469 07/08/200600:00 01:00 1.00 469 0 01 :00 02:00 1.00 0 o COMPZ RPCOr.. RURD 02:00 02:15 0.25 5 5 COMPZ RPCOr.. PULD 02:15 05:00 2.75 5 8,536 RPCOr.. TRIP 05:00 09:00 4.00 8,536 12,248 RPCOr.. TRIP NP Precautionary circ hole from 6,061' due to gas while unloading tbg from pipe shed, circ hole at 86 spm, 4 bpm at 725 psi, after circ approx 5 min's had 725 units of gas at surface then gas dropped down to 200 units in 5 min's and after circ add. 10 min's gas peaked out at 1,082 units, had 13.6 ppg mud in and 13.0 ppg MWout with pressure scale and 12.2 ppg with non pressure scale at 1,082 units, cont to circ one hole volume and gas cont to drop out while circ, final gas was down to 147' units. decision was made to trip back in hole and circ an add. btms u . NP RU and MU XO from 3 1/2" EUE to 3 1/2" IF and RIH with 62 stds of 31/2" DP, RIH from 6,061' to 12,072' NP Circ 1 complete hole volume from 12,072', circ at 84 spm, 1,600 psi, st wt up 125K, dn wt 65K, max gas while circ was 376 units and final gas after circ hole was 50 units with 13.6 ppg in and out, no gas cut mud. Checked OA pressure and had 900 psi, opened to bleed tank and bled down to 20 psi uickl NP Monitored well-static, POOH with 3 1/2" DP from 12,072' to 31/2" tbg at 6,061' P CO handling equip for 31/2" tubing and re to LD same. P Cont POOH LD 31/2" tubing from 6,061' to 469', total of 177 ·nts. P Fin POOH from 469' LD 3 1/2" tbg, LD 15 add. jts of tbg, LD a total of 246 jts of 3 1/2", 9.3#, L-80 EUE-Mod tbg from derrick P RD 31/2" handling equipment and offloaded 3 1/2" tbg out of pipe shed. NOTE: NORM all tbg, tree and completion equipment POOH and ck ok P MU BHA #4, 6 1/8" Used mill tooth bit with no jets, 7", 26# csg scraper and bit sub with no float RIH to 5' P RIH with BHA #4 with 3 1/2" DP out of the derrick to 8,635' P Cont RIH with BHA #4 PU 3 1/2" DP out of pipe shed, RIH from 8,536' to 12,248' PU 115 jts of DP, (TOF @ 12,277' 11:00 12:45 1.75 12,248 10,278 COMPZ RPCOr-.. TRIP 12:45 14:00 1.25 58 14:00 16:00 2.00 58 16:00 21 :30 5.50 58 21 :30 22:30 10,278 1.00 10,336 10,336 22:30 23:30 1.00 10,336 23:30 00:00 0.50 10,278 07/09/200600:00 01:15 1.25 10,278 01:15 01:30 0.25 10,278 01 :30 07:15 5.75 10,278 10,278 10,278 10,278 COMPZ RPCOr-.. OWFF o RPCOr-.. TRIP Circ 1.5 X btms up from 12,248', staged pump rate up to 5 bpm, 105 spm at 2,860 psi, rot wt 93K, up wt w/pump on 125K, dn wt 87K, st wt up no pump 165K, dn wt 75K, while circ had 852 units gas back after circ 174 bbls, then dropped down to 350 units and within 40 bbls of btms up had the max gas of 999 units, gas then dropped out after 1 complete circ and after 1.5X btms up bgg was down to 25 units, 13.6 ppg mw in and out, at 999 units the lowest non pressured MWwas 12.5+ ppg and pressure scale was 13.5 ppg, calc btms up was 325 bbls and no losses while circ. P Monitored well-static, LD 1 single then POOH with BHA #4 20 stds of 3 1/2" DP to 10,278' P MU Baker storm packer and RIH setting same at 58', bit and scraper to 10,336' P Drained stack and attempted to pull wear bushing, after working retrieving tool over bushing, pulled same to surface and found top of bushing to be dented in sli htl , installed test lu P RU and tested BOPE, tested valves, rams and manifold to 250 psi low and 3,500 psi high, tested annular to 250 low and 2,500 psi high. Note: Jeff Jones with AOGCC waived witnessing of BOP test P RD test equip, pull test plug, install wear rin . P MU Baker retrieval tool, RIH and release storm packer, checked well for pressure and well was static, POOH LD storm packer, up wt 140K, dwn wt 70K. P RU and began to circ hole to monitor for as, circ at 5 b m, 2,400 si P Cont to circ hole after releasing storm packer from testing BOPE, circ hole at 10,278' at 105 spm, 5 bpm at 2,400 psi, after circ 124 bbls into of 271 bbls btms up had 754 units gas back, at btms up had 206 units gas, cont to cir hole and gas dropped out to 50 units, circ 440 bbls of 13.6 ppg potassium formate mud with no losses P Monitored well-static, blow down top drive P POOH with BHA #4, bit and scraper from 10,278' and LD same, hole took calc fill. Held PJSM with Baker rep and rig crew on MU and RIH with RBP and acker assembl 07:30 08:00 0.50 0 27 PU and MU Baker 7" 26# "G" lock set RBP with right hand set & release with a "EA retrievamatic pkr with left hand set and straight PU release pkr and RIH to 27' 08:00 15:45 7.75 27 T RIH with RBP and pkr on 31/2" DP from 27' to 12,230', st wt up 167K, dn wt 72K, RIH at 90'/min 15:45 18:15 2.50 12,230 T Set "G" lock RBP at 12,230' with rt hand set, attempted to release from BP by working torque down to tool with no success, est circ and after circ on tool was able to release from same. 18:15 19:00 0.75 12,230 12,205 RPCOII. RURD T LD 1 single DP POOH with pkr to 12,205' and RU to circ down DP 19:00 21:15 2.25 12,205 12,205 T Circ hole from 12,205' at 3 bpm at 1,500 psi, max gas while circ hole was 633 units, max gas was back after circ approx 103 bbls or approx 3,945', calc btms up was 322 bbls, lowest MWout using non pressure scale with max gas was 12.8+ mw with 13.6 ppg pressure scale, circ 1 complete hole volume with bgg down to 75 units and no mud loss 21:15 22:30 1.25 12,205 12,205 COMPZ RPCOII. DHEQ T Slacked off 17K st wt to set pkr at 12,205', pressure tested below pkr and to RBP at 12,230' to 2,500 psi for 5 min and ck ok, opened bypass on pkr and est circ, shut down and closed in well and attempted to test csg from RBP at 12,230', while pressuring up to 2,500 psi, csg began to leak off at 2,060 psi after pumping 2.25 bbls, pressure dropped down to 1,500 psi while shutting pump down and bled off ressure. 22:30 00:00 1.50 12,205 10,196 T RD test equip and POOH from 12,205' to 10,196', u wt 167K, dwn wt 72K. 07/10/200600:00 00:30 0.50 10,196 9,322 P Cont POOH from 10,196' to 9,322' 00:30 01:15 0.75 9,322 9,322 P RU and tested 7" csg from 9,322' to RBP at 12,230', tested to 2,500 psi for 10 min, ood test 01:15 02:30 1.25 9,322 7,383 P POOH 20 stds from 9,322' to 7,383' 02:30 03:15 0.75 7,383 7,383 P Set pkr at 7,383' and RU to circ, attempted to test csg below pkr at 7,383" and began to leak off at 1,050 si., no test btwn 7,383' to 9,322' 03:15 03 :45 0.50 7,383 8,352 RIH 10 stds from 7,383' to 8,352' Attempted to test 7" csg below pkr at 8,352' and broke back at 1,060 psi, no test 04:15 04:30 0.25 8,352 8,827 P RIH 5 stds from 8,352' to 8,827' 04:30 05:00 0.50 8,827 8,827 P Attempted to test csg at 8,827' and would not test 05:00 06:30 1.50 8,827 9,214 P RIH from 8,827' to 9,214' testing csg after each std and would not test. 06:30 07:00 0.50 9,214 9,214 P RU to test 3 1/2" x 7" annulus above pkr at 9,214' and broke down after pressuring up to 1,100 psi and um in 1 bbl of 13.6 mud 07:00 08:30 1.50 9,214 7,277 P RD circ head and POOH 20 stds from 9214' to 7,277', st wt at 7,277' 120K, set 20 t025K dn on kr 08:30 10:15 1.75 7,277 7,665 P RU & tested 7" csg at 7,277' to 2,500 psi for 10 min, good test, RIH 4 stds to 7,665' and tested csg to 2,500 psi for 10 min, ood test 10:15 11 :15 1.00 7,665 8,439 P Released pkr and RIH 8 stds from 7,665' to 8,439' 11 :15 14:30 3.25 8,439 7,695 P Tested 7" csg by moving pkr up hole from 8,439', csg did not test at 8,439', 8,343',8,245', 7,955', 7,857', 7,760', 7,728' then PU to 7,695' and csg held ressure at 7,695' 14:30 15:00 0.50 7,695 7,695 T Pressure tested 7" csg above pkr at 7,695' to 2,500 psi for 30 min, good test. NOTE: Top hole found to be btwn 7,695' to 7,728' 15:00 16:30 1.50 7,695 9,278 T RD circ head, released packer & RIH from 7,695' to 9,278' 16:30 17:00 0.50 9,278 9,278 T Set pkr with 25K dn wt at 9,278' and pressure tested 7" csg below pkr to 12,230', tested csg to 2,500 psi for 10 min, good test. NOTE Btm hole found to be btwn 9,214' & 9,278', (1,583' FI7,695' to 9,278') Lost approx 14 bbls of 13.6 ppg potassium formate while locatin holes in the cs . 17:00 18:30 1.50 9,278 12,200 COMPZ RPCOI\ TRIP T Released packer and RIH from 9,278' to 12,200'. 18:30 21:00 2.50 12,200 12,200 COMPZ RPCOI\ CIRC T CBU at 3 bpm, 1,360 psi, max gas 110 units at btms u . 21:00 22:00 1.00 12,200 12,235 COMPZ RPCOI\ OTHR T SO from 12,200' to 12,230' and engage retrievable bridge plug, st wt up 160K, dwn wt 75K, rotate right and release plug, SO to 12,235' and monitor well on trip tank while allowing RBP elements to retract, well-static, off-load excess drill i e. 22:00 00:00 2.00 12,235 T POOH slow from 12,235' to 10,203', up wt 160K. Cont to POOH with ret.pkr and RBP from 10,203' to assembly at 27', calc hole fil on trip out 65 bbls, actual 64 bbls 05 :45 06:30 0.75 27 0 T POOH from 27' LD packer and RBP, cleaned ri floor 06:30 08:00 1.50 0 405 PULD T MU fishing BHA #6 RIH to 405', MU 5 718" OD overshot with 4 1/2" grapple, bumper and oil jars, 12-43/4" DC's, intensifiers and um out sub 08:00 09:00 1.00 405 405 P Slip and cut 42' of drlg line 09:00 15:30 6.50 405 12,230 TRIP T Cont to RIH with fishing BHA #6 from 405' to 12,230', st wt up 175K, dn wt 72K 15:30 17:15 1.75 12,230 CIRC T Circ 1 complete hole volume monitoring gas, circ hole at 84 spm, 4 bpm at 2,100 psi, max gas was 65 units at btms up, 13.6 ppg potassium formate in and out, began loading pipe shed with 3 1/2", 9.2#, L-80 IBT-mod tb ,st wt u 175K, dn wt 80K 17:15 18:30 1.25 12,230 12,259 COMPZ FISH FISH T Est circ at 2 bpm at 1,150 psi, 20 rpm's at 5,800 ft-Ibs torque, RIH from 12,230' and sat down at 12,259' with 20K wt dn, (est TOF @ 12,273'), increased pump rate to 90 spm, 4.5 bpm at 2,500 psi and 40 rpm's at 7,100 ft-Ibs torque, attempted to wash down thru fill with no success, rot wt 90K, u wt 140K, dn wt 75K 18:30 00:00 5.50 12,259 0 COMPZ FISH TRIP T POOH from 12,259' to fishing BHA #6 at 405'. LD pump out sub & accelerator. POH 3 stands DC. LD cut Ii uide. 07/12/200600:00 01:00 1.00 0 410 COMPZ FISH PULD T MU fishing BHA #7 RIH to 410', MU 6" wash over shoe with 4 5/8" ID, 4' ext. with 41/2" grapple, bumper and oil jars, 12-4 3/4" dc's, intensifiers and um out sub 01:00 07:15 6.25 410 12,234 COMPZ FISH TRIP T RIH with fishing BHA 37 from 410' to 12,234', st wt u 170K, dn wt 80K 09:30 10:30 1.00 12,234 12,234 COMPZ FISH CIRC Est circ 84 spm, 4 bpm at 2,100 psi, st wt up 150K, dn wt 72K, washed down and tagged up 12,259', started rotation at 40 rpm's with 6,800 ft-Ibs torque, rot wt 100K, up wt 118K, dn wt 85K, started to wash down from 12,259' after setting 5-10K wt down was able to was deeper, washed down to 12,264' while rotating, PU and to see if we had gone over collar above "W' nipple with no indication of a catch, cont to rotate and wash and work shoe down to 12,265' (total catch from shoe to top sub 6'), stacked out 30K down and was unable to go deeper, PU and still had no inidications that we had latched onto collar, possibly may have damaged grapple while attempting to clean out dee er. T Fin cirtc btms up from 12,234', circ at 4 bpm and 2,100 psi, max gas at btms up was 586 units then dropped down to 25 units. No mud loss while circ over fish or while circ btms u . T Monitored well-static, POOH from 12234' to BHA at 410', hole took calc fill on tri out T POOH from 410', LD pump in sub and intensifier jars, stood back 4 stds of 4 3/4" dc's and LD shoe and inspected grapple, found grapple to be distorted and several flat spots on the wickers of the grapple, notice a 3 5/8" shiny spot on the no go indicating we were over fish. Cleaned ri floor. T MU fishing BHA #8 RIH to 405 , MU 5 7/8" OD cutlip guide with new 41/2" basket grapple, bumper and oil jars, 12-43/4" DC's, intensifiers and pump out sub. T RIH with fishing BHA #8 from 405' to 12230'. 175K# PU, 70K# SO WI. without um . T Circulate once around at 12230', 85 SPM,4 BPM, 2100 psi. Had initial gas spike to 380 Units, then another spike to 634 Units. Continued circulating until gas units down to 37 Units. Had 13.5 ppg returns near bottoms up, 13.6 ppg in & out when um shut down. 10:30 16:00 5.50 12,234 410 COMPZ FISH TRIP 16:00 17:30 1.50 410 o COMPZ FISH PULD 17:30 18:30 1.00 0 405 COMPZ FISH PULD 18:30 00:00 5.50 405 12,230 COMPZ FISH TRIP 07/13/200600:00 02:00 2.00 12,230 12,230 COMPZ FISH CIRC 10:30 12:30 Establish weights, 170K# PU, 70K# SO Wt. without pump. Circulate slow, 1 BPM at 900 psi, slack off and tag TOF at 12259'. Continue slacking off over fish and saw pressure increase as overshot engaged fish. Shut down pump & set 20K# down on fish. PU to 200K#, 30K# overpull. Continue working up in 10K# increments to 235K#, 65K# overpull, light jar, then PU and fish started moving at 50K# overpull. Continued with 50K# overpull for about 5', then weight gradually dro ed back to 170K# PU Wt. 5.50 12,259 405 TRIP T Blow down top drive and POOH with fishing BHA #8 from 12,259' to BHA at 405'. 0.50 405 0 COMPZ FISH PULD T POOH from 405' LD intensifier jars and pump in sub, stood back 4 stds 4 3/4" dc's and pulled overshot out and had full recove of fish 1.75 0 0 COMPZ FISH PULD T LD fish from overshot, rec'd 3/4" of piece of cutoff jt, "W' nipple (4.5" OD), 6' pup jt and seal assembly, total rec'd 21.05', LD remaining fishing tools and offloaded from pipeshed while cleaning ri floor 2.00 0 0 COMPZ CASIN( RURD T RU to run 5 1/2" scab liner, changed out 3 1/2" handling tools to 5 1/2". Fin re arin 5 1/2" liner in i e shed 4.75 0 1,692 COMPZ CASIN( PUTB T MU 51/2" scab liner RIH to 1,692', MU Baker 5 1/2" x 7" 3D Liner hanger/Pkr assembly with mule shoe, then PU & RIH with 38 jts (1,626') of 5 1/2", 15.5#, L-80, Hydril511 liner, MU Baker 5112" x 7" HMC Liner hanger withCPH liner top packer RIH to 1,692', st wt u 58K, dn wt 53K 0.75 1,692 1,692 COMPZ CASIN( RURD T Changed out 51/2" liner handling equipment over to 3 1/2" DP handling tools. 6.00 1,692 4,893 COMPZ CASIN( RUNL T RIH with scab liner on 3 1/2" DP from 1,693' to 4893' at 2400 hrs. RIH slow and drifting DP with 1.9" rabbit while RIH. 8.50 4,893 9,241 COMPZ CASIN( RUNL T Cont to RIH with 51/2" scab liner on 3 1/2" DP from 4,893' and sat down at 9,241', st wt u 125K, dn wt 70K 02:45 08:15 08:15 08:45 08:45 10:30 12:30 17:15 17:15 18:00 18:00 00:00 07/14/2006 00:00 08:30 11 :30 15:45 4.25 9,248 6,825 COMPZ CASIN( RUNL Est circ at 21 spm, 1 bpm at 900 psist wt up wlpump on 107K, circ 8 bbls of mud then shut down pumps, slowly worked liner down from 9,241' to 9,248' setting 10-12K add. wt down, circ and add. 18 bbls at 11 spm, 1/2 bpm at 700 psi, was able to PU to up wt wIno problems, shut pump down and try to go deeper and was not able to after many attempts, PU 8' and closed annular, then est reverse circ at 1/2 bpm at 760 psi, attempted to RIH rev circ and set down again at 9,248' with 10-15K wt down and no movement, shut down pump and opened annular, PU and had an initial10K add. drag then dropped down to 125K, PU & went down with no problems. With mule shoe at 9,248' that puts the lower packer at 9,233', btm of upper paker at 7,571' with hanger at 7,575'. circ hole while discussing options with town, Decision was made to POOH & LD liner T Began POOH slow from 9,245', pulling at 20'/min due to hole wanting to swab, after POOH to 7,219', hole wasn't taking calc fill, est circ with 2 1/2 bbls and pump out 1 std to 7,122', then POOH 3 stds to 6,825' and hole still wasn't taking proper fill, hole fill off a rox 2 bbls, st wt u 110K T Circ hole at 6,825', circ hole at 2 bpm at 1,160 psi, gas increased to 440 units, calc btms up was 150 bbls and gas was down to 97 units after pumping 200 bbls, cont to circ hole and began to see 13.4+ MW out while circ hole till 13.6 ppg MW out gas began to increase again to 583 units after pumping 360 bbls or 2X btms up, shut down um s T Monitored well for 10 min and well was static, attempted to RIH to 7,700' and was unable to go deeper because it appears packer element is holding us up, est circ at 1 bpm at 700 psi and still was unable to go down, PU to 6,796' while attem tin to 0 down 15:45 18:45 3.00 6,825 6,825 COMPZ CASIN( CIRC 18:45 19:15 0.50 6,825 6,796 COMPZ CASIN( OTHR Circ hole staging pump rate up from 2 bpm at 1,130 psi, 2 1/2 bpm at 1,300 psi, gas increased to 683 units and began to drop, decision was made to raise MW to 13.7 then pump out of hole due to packer. Continue circulating 2-1/2 BPM, 1300 psi, and weight up mud to 13.7 ppg. Gas down to 180 Units. 22:00 00:00 2.00 6,796 5,668 COMPZ CASIN( OTHR T Monitor well 15 minutes, static. Break circulation and pump out of hole from 6796' to 5668' at midnight. Hole taking proper fill while pumping out at 1-1/2 to 2 BPM. 07/15/200600:00 05:30 5.50 5,668 1,693 COMPZ CASIN( OTHR T Cont to pump out of hole with 3 1/2" DP and 5 1/2" scab liner from 5,668' to liner and hanger assembly at 1,693', pumped out a 2-2.5 bpm and hole took calc fill 05:30 10:00 4.50 1,693 0 COMPZ CASIN( PUTB T POOH LD 5 1/2" scab liner assembly from 1,693', LD CPH Liner top packer, HMC liner hanger, 38 jts, 1,626' of 5 1/2", 15.5#, L-80, Hydril 511 liner and 3D hgr/pkr, HMC liner hanger slips were in the up and set position, possible cause for not allowing us to RIH and 3D hgr/pkr on btm showed no sign of damage, had a hard hand full of calcium carbonate in btm of mule shoe. Note: Sim-Ops, tested portion of choke manifold while LD liner 10:00 10:30 0.50 0 0 WELCT EQRP P Pulled wear bushing and installed test lu 10:30 13:30 3.00 0 0 WELCT BOPE P RU and tested BOPE, tested valves, rams and manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi then to 2,500 psi. Note: Chuck Scheve with AOGCC waived witnessin of the test 13:30 15:30 2.00 0 0 COMPZ RIGMN SVRG P Slip and cut 42' of drlg line and serviced top drive, blocks and swivel. Be an to RU to run 31/2" com letion 15:30 15:45 0.25 0 0 COMPZ RPCOI\ RURD P Fin RU to run 31/2" completion 15:45 16:00 0.25 0 0 COMPZ RPCOI\ SFTY P RIH with 3 1/2" straddle packer assembly to 4,781', MU 80-40 seal assembly, 4.25" locator sub, 2-pup jts with 4.2" SCC's, 2.812" "DS" nipple with RHC plug and pup jt above with 4.2" SCC, then RIH with 151 jts 4,704' of 3 1/2", 9.3#, L-80, EUE-Mod tbg and then MU Baker's 7" "FHL" retrievable packer with 80-40 PBR, "RS" pack-off seal nipple and liner setting sleeve. 68K# PU, 53K# SO, 38K# Blocks. 22:30 23:00 0.50 4,781 4,781 COMPZ P Rig down tubing tongs. Rig up DP sinners. 23:00 00:00 1.00 4,781 6,816 COMPZ P RIH with FHL Packer and tailpipe assembl on DP, to 6816' at 2400 hrs. 07/16/200600:00 03:00 3.00 6,816 12,246 COMPZ P Cont to RIH with straddle packer assembly from 6,816' to 12,246', st wt u 145K, dn wt 73K. 03:00 05:00 2.00 12,246 12,283 COMPZ RPCOtl. PACK P MU top drive. Break circulation, 1 BPM, 940 psi, 133K# PU, 70K# SO Wt with pump. Tag top of PBR at 12274' MD, stab-in seals, locate out with muleshoe at 12286'. Verified location with weight indicator and pump. PU and space out with seals 2' up from fully located out position, muleshoe at 12284' MD. Drop slickline retrieveable roller stem with 1-5/16" ball and let fall to RHC seat in DS- Nipple. Stab seals back into PBR and re-verify position. Pressure up on DP to 2500 psi and set FHL Packer. Set weight on packer and continue pressure up on DP to 3500 psi to release settin tool. 05:00 05:30 0.50 12,283 7,507 COMPZ RPCOtl. DHEQ P Close pipe rams. Pressure up on DP X 7" Annulus to test FHL Packer and casing to 2500 psi for 10 minutes, lost 20 psi, OK. Bleed off test. Release Baker setting tool and PU out of HR Settin Sleeve, to at 7507' MD. 05:30 07:30 2.00 7,507 7,465 COMPZ RPCOtl. CIRC P Pull 1 stand to 7465' to clear setting tools above Straddle Packer Assembly. Circ btms up at 7,465', circ at 84 spm, 4 bpm at 1,300 psi, max gas at btms up 306 units, circ till gas was below 100 units and 13.6 ppg mw in and out, st wt up 95K, dn wt 65K 07:30 18:00 10.50 7,465 0 COMPZ RPCOtl. PULD P PJSM. POOH from 7,465' LD 3 1/2" DP, LD 231 jts of DP along with "HR" settin sleeve runnin tool. 18:00 19:00 1.00 0 0 COMPZ RPCOtl. PULD P Finish LD Baker setting tools. Unload DP from shed. Clean floor. RU to RIH and LD DC and DP. RIH 4 stands DC and 49 stands DP, to 5100'. 21:00 00:00 3.00 5,100 2,108 P POOH LD DP, to 2108' at midnight. 07/17/200600:00 03:00 3.00 2,108 0 P 03:00 03:30 0.50 0 P 03:30 03:45 0.25 P Held PJSM with rig crew and Baker re on runnin of 3 1/2" com letion 03:45 10:30 6.75 0 7,500 P RIH with 31/2" completion assembly to 7,500', RIH with seal assembly, locator sub, 2-GLM's and 2.875" "DS" ni Ie erwell Ian 10:30 12:30 2.00 7,500 7,507 P Est circ and RIH with seals tagging top of setting sleeve at 7,507', spaced out 31/2" completion, MU FMC Gen Vtbg hanger and landed tbg, landed tbg with end of seals at 7,533', GLM with DCK-2 shear valve at 7,466', GLM with dummy at 4,189' and 2.875" "DS" nipple at 498', ran a total of 238 jts, (7,430') of 3 1/2", 9.3#, L-80, EUE-Mod tbg.st wt up 83K, dn wt 50K. Note: tagged orig. PBR 10' higher on straddle packer run, made tbg correction on 3 1/2" detail. 12:30 15:00 2.50 7,507 7,507 COMPZ RPCOII. DHEQ P RU and tested 31/2" tbg to 2,500 psi and pressure bled down 250 psi in 15, min on 2nd test. Monitored IA and and ck'd ok, possibly bleeding out of RHC plug. Bled down to 1,500 psi then pressured up on 3 1/2" x 7" annulus and tested same to 2,500 psi for 30 min, initial pressure was 2,570 psi and after 30 min final press. was 2,520 psi, good test, bled off tbg and sheared DCK-2 valve at 2,350 si. 15:00 15:45 0.75 7,507 7,507 COMPZ RPCOII. RURD P RD pump in sub and LD landing jt 15:45 16:30 0.75 7,507 7,507 COMPZ P Installed BPV 16:30 18:30 2.00 0 0 COMPZ P ND BOP stack, riser and flowline, set back stack 18:30 23:00 4.50 0 0 COMPZ P NU refurbished 3 1/8" x 5M Gen V tree and tested same to 250/5,000 psi and ck ok, tested 7" pack-off to 250/5,000 si and ck'd ok 23:00 00:00 1.00 0 0 COMPZ RPCOII. RURD P RU hoses to tree and manifold in the cellar preparing to displace hole over from 13.6 ppg potassium formate to seawter PJSM. Reverse circulate and displace annulus and tubing to clean seawater thru bottom GLM at 7466' MD, 4044' TVD. Pumped 20 Bbl hi-vise SW spacer, followed by clean seawater, until clean seawater returns at surface. Pumped at 2.6 BPM, 54 SPM, 2300 psi. Taking returns thru choke, held 900 psi to 1100 psi after SW turned the corner. Pumped 520 Bbls SW total. 03:30 04:15 0.75 0 0 COMPZ RPCOI\ RURD P Shut-in choke and monitored well while rigging up lines to pump diesel. IA 880 psi, Tbg 890 psi. (may have trapped some ressure . 04:15 05:15 1.00 0 0 COMPZ RPCOI\ FRZP P Test lines to 2500 psi. Little Red pump 85 Bbls Diesel down annulus, 2 BPM, 1800 psi to 2200 psi. Took returns thru choke holding 800 psi to 1200 siback ressure. 05:15 06:30 1.25 0 0 COMPZ RPCOI\ FRZP P Jumper annulus to tubing and let diesel U-tube until equalized for freeze protection. Estimate diesel cap to 2424' MD, 2191' TVD. Final pressures: 700 psi Tubing, 770 psi 3-1/2" X 7" Annulus, 0 si on OA. 06:30 12:00 5.50 0 0 COMPZ RPCOI\ RURD P RD circulating lines. Set BPV using lubricator. Made some repairs on lubricator pump to get it working properly. Commenced cleaning pits and lines while repairs made on lubricator. RD FMC lubricator. Secured well. 12:00 18:00 6.00 0 0 COMPZ RPCOI\ OTHR P Dress tree. Continue cleaning pits, pumps, and lines. Well secured. Released Ri at 1800 hours, 7/18/06. Re: 3M-23 Workover (PTD# 193-187) . Howard, This acknowledges your message regarding 3M-23. Your way forward will depend on what the retrievable packer test determines. I should be available on the cell phone over the weekend if you need to converse. Tom Maunder, PE AOGCC Gober, Howard wrote, On 6/30/2006 1:47 PM: Tom, This e-mail is to confirm our phone conversation earlier today. We have moved on to 3M-23 for a workover to replace the tubing. The well has been diagnosed with several tubing leaks. A Combo MIT was performed on 4/2/06 with the D&D holefinder tool set in the 10' pup joint below the packer. The CMIT passed at 2500 psi. With that information, we planned the workover as a straight tubing replacement. This does not require a 10-403, so we did not submit a Sundry application. We decided to move forward with this workover earlier this week. Therefore we started our pre-rig wellwork. Here is what we did: · 6/27/06 Set CA-2 plug in nipple at 12313' RKB (below packer). PT plug. Would not hold pressure. This has happened in the past, so we were not surprised. We pulled the plug. · 6/28/06 Set WRP on e-line in pup joint below the nipple. PT plug. Would not hold pressure. The successful CMIT was performed with the D&D tool set in the pup joint above the nipple. It is possible that the tubing tail leaks below the packer. Equalize WRP. Pressure jumped from 750 psi to 1800 psi. Pull WRP. Obtain SBHP of 4195 psi at 12440' RKB. · 6/29/06 Pull DV from mandrel at 12229' RKB. MIRU Nordic 3. · 6/30/06 Well kill operations underway. The passing CMIT on 4/2106 suggests that the casing was good at that time. The pressure increase after equalizing the WRP suggests that we might have a casing leak above the packer. Another possibility is that there is a split in the tail that will hold some differential pressure. Due to the uncertainty, we will run a bridge plug and packer to test casing. This will verify casing integrity or allow us to determine the leak point. A repair plan will be formulated once we have the pressure test data. With the bottom hole pressure of 4195 psi, we have decided to run an extra pipe ram in our stack below the mud cross. I will communicate the results of the casing pressure test after it is complete. FYI - following 3M-23, Nordic 3 will be moving to Prudhoe Bay to do approx 3 months of workovers for BP. While Nordic 3 is a BP, we will utilize Nabors 3S for workovers at Kuparuk. 1 of't ~t~~~v:J 8/1 0/2006 9:55 AM FW: Revised Completion Proposal, 3M-2_ Lq~-li1 e Subject: FW: Revised Completion Proposal, 3M-23 From: "Eller, J Gary" <J.Gary.Eller@conocophillips.com> Date: Fri, 14 Jul 2006 14:30:48 -0800 To: winton_aubert@admin.state.ak.us Winton - FYI -----Original Message----- From: Eller, J Gary Sent: Friday, July 14, 2006 2:20 PM To: 'Thomas Maunder' Cc: Gober, Howard; Nordic 3 Company Man; Long, Jill W Subject: Revised Completion Proposal, 3M-23 Tom - This note is regarding the 10-403 that was submitted on July 11 for installation of a scab liner in well 3M-23. We were unable to get our 5-1/2" scab liner to bottom today. It hung up while we were running the last stand of drillpipe to put it on depth, and were unable to get it deep enough to span the known hole in the 7" casing. We don't know whether it was the upper packer or the lower packer tnat was hanging up, but my guess is the lower packer. We are currently coming out of the hole with the scab liner. I have attached a new proposed schematic showing how we would like to complete the well. Rather than trying to clean out with string mills and rerunning the scab liner, we would like to install a straddle packer above the known 7" holes. We'll leave formate brine in the tubing-casing annulus opposite the casing leaks because formate has excellent natural corrosion inhibition properties. The productivity of the well will not be compromised because the planned gas lift point is above the proposed straddle packer. The proposed packer will be retrievable to enable a simplified future workover if the need arises to run gas lift valves deeper in the well. Please contact me to discuss. Thanks. «3M-23 proposed schematic 7-14-06.pdf» J. Gary Eiler' Wells Engineer ConocoPhillips .. Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 Content-Description: 3M-23 proposed schematic 7-14-06.pdf 3M-23 proposed schematic 7-14-06.pdf Content..Type: application/octet-stream Content-Encoding: base64 1 of 1 7/14/20062:33 PM e ~þ-" ConocoPhillips API: 50-029-22426 AOGCC: 193-187 Lift thds: :3 Yz" 8rd BPV: 3Yz" type IS Wellhead: FMC (Jell IV-A, Proposed Completion · Tubing ::: 3%", 9.3 ppf, L-80, EUE 8rd Mod · OS-nipple at 500' 10 = 2.-375" · FHC packer at 7600' · OS-nipple at 12,275' 10=2.813" · 80-40 Seal assy for KBH-22 Anchor Existinq 3Yz" Completion · KBH-22 Anchor seal assembly at 12,296' · SAB-3 permanent packer at 12,297' Ð Camco D nipple at 12,313' 10 = 2.75" 00=6.151" · Re-entry guide at 12,325' i__.___ Directional: Max hole angle: 69°_70° at 2700' KOP = 55D' ,Angle at top perf: 44° ¡íMaX doglegs: 7.3°/100' at 759' 6.6°/100' at 2526' - . PROPOSED os I I I ! i i I I ~ I ~:~ : , 0 i , I n I ! L---'> I i : I ! I : ~'..l .. ".... .. ........... .... ................... ................... ."................ .................... ,................... ~,..................... .,................. ................... .................. ................... ~- Fill" 12,491' (4i4106) I TO = 12,750' e Well: 3M-23 Field: Kuparuk Conductor: 16",62.58 ppf, H-40 at 121' Surface Casinq: 9%", BTC at 5437' 0' - 3306', 53.5#, L-80 3306' - 5265', 36#, J-55 5265' - 5349', 53.5#, L-80 5349' - 5437', 36#, J-55 Gas Lift Mandrels MO TVO Tvpe 4180' 2850' KBUG-dummy 7482' 4050' KBUG-dummy 9116' 4650' KBG2 9 dummy 10038' 5000' KBG2 9 dummy 11520' 5580' KBG2 9 dummy 12240' 6030' KBG2 9 OCR Perfs C-4: 12,423'-12,443' (4 spf, 9/12/01) A-2: 12,450'-12,466' (4 spf, 9/7/01) A-1: 12,474'-12,502' (4/94 & 9/01) Production Casinq: 7",26 ppf, L-80 at 12,722' Casing communication confirmed 7/10/06. Holes confirmed between 7695'-7728' MO and 9214'-9275' MD. Last Updated: 14-Jul-06 Updated by: JGE e e .r¡:¡1 I ".... \" '" ~.;:\)iJ ,~ !ï::"\ð' ~l' " .1"? ?':\, · II L, lr ~ j] ·1' ,1""'" "f ~ \ ~;I : ~ .1, d 'w ., 1..;; tj:, ~ FRANK H. MURKOWSKI, GOVERNOR AI,A~1iA OILAl'WD GAS CONSERVATION COMMISSION 333 W. P" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 3M-23 Sundry Number: 306-240 Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced welL Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ DATED thisil- day of July, 2006 Dan T. Seamount Commissioner EncL l'ì3-/t'r e e Gary Eller Wells Engineer Drilling & Wells ConocJPhiiii ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 July 11, 2006 RECEIVED JUl 1 1 llMJ5 f Atøska Oi\ & Gas t6ft$. tmmússiQß tAncl'Ø. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 3M-23 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 3M-23: We are planning to workover this well to install a scab liner over holes discovered in the 7" casing. The holes were located at approximately 7700' and 9250' MD using a packer and bridge plug to test the casing. The good casing was tested to 2500 psi with 13.6 ppg brine in the hole, and the casing leaks broke down at about 2000 psi. We did not attempt to establish a leak rate, but we pumped a total of 14 bbl of brine into the 7" casing leaks during pressure testing. We would appreciate a verbal approval as soon as possible as we expect to do this work today. ./ If you have any questions regarding this matter, please contact me at 263-4172. J. Wells gineer CPAI Drilling and Wells JGE/skad 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 . Repair well 0· Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 193-187 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22426-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes 0 No 0 3M-23 . 9. Property D~signation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25524, ALK 2655 RKB 68' Kuparuk River Field 1 Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12750' -, 6394' 12491' Casing Length Size MD TVD Burst Collapse CONDUCTOR 89' 16" 121' 121' SURFACE 5405' 9-5/8" 5437' 3307' PRODUCTION 12690' 7" 12721' 6374' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12423'-12443',12450'-12466',12474'-12502' 6160'-6174',6179'-6191',6197'-6217' 3-1/2" L-80 12325' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER SAB-3 PACKER pkr= 12297' Cameo 'DS' nipple @ 503' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 11, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date:.1..,,¡k \'-\~Cø WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Á2- 9W}~ ,,-IlL 18. I h''''by œ,~ 10""0'" '1" 00' """''' to th, be" of my "owl"". Contact: Gary Eller @ 263-4172 Printed Name \. Garv Eller ç- Title: Wells Group Engirer II Signature . ('"\ 11.\, '''? 1\ Phone 263-4172 Date '7 \ \ ~ l -....> "'" 'V"-' Commission Use Only ..--J sun~ber: [)4{) Conditions of approval: Notify Commission so that a representative may witness ... IJ '" Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: 36>OO~c.,.\ "'\...... '\ 0/'-\, ~IM. ~OV \é"'.:.-\- RBDMS 8FL JUL J 3 2006 S,bso,,," Fom R',"''''~ Approv'" by' ~ APPROVED BY 7//3/0 COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 UKlblNAL Submit in D~licåte ~A 'IZ'O~ . Cfl/ 111'¡O~ .. RECEIVED STATE OF ALASKA ~/I? JUL 1 1 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO\QR¡l Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage . þ~ "",,/ ConocoPhillips API: 50-029-22426 AOGCC: 193-187 Lift thds: 3%" 8rd BPV: 3%" type IS Wellhead: FMC Gen IV-A Proposed Completion · Tubing = 3%", 9.3 ppf, L-80, EUE 8rd Mod and IBT-Mod with SCC (below top of scab liner) · DS-nipple at 500' ID = 2.875" · DS-nipple at 12,275' ID = 2.813" · 80-40 Seal assy for KBH-22 Anchor ExistinQ 3%" Completion · Tubing = 3%", 9.3 ppf, L-80, EUE 8rd-Mod · Baker PBR with 4" bore at 12,283' · KBH-22 Anchor seal assembly at 12,296' · SAB-3 permanent packer at 12,297' · Camco D nipple at 12,313' ID = 2.75" OD=6.151" · Re-entry guide at 12,325' Directional: Max hole angle: 69°-70° at 2700' KOP = 550' Angle at top perf: 44° Max doglegs: 7.3°/100' at 759' 6.6°/100' at 2526' e PROPOSED DS Fill = 12,491' (4/4/06) TD = 12,750' . e Well: 3M-23 Field: Kuparuk Conductor: 16",62.58 ppf, H-40 at 121' Surface CasinQ: 9%", BTC at 5437' 0' - 3306', 53.5#, L-80 3306' - 5265',36#, J-55 5265' - 5349',53.5#, L-80 5349' - 5437', 36#, J-55 Gas Lift Mandrels MD 4180' 7482' 9116' 10038' 11520' 12240' TVD 2850' 4050' 4650' 5000' 5580' 6030' Tvpe KBUG-dummy KBUG-dummy KBG2-9 dummy KBG2-9 dummy KBG2-9 dummy KBG2-9 DCR Perfs C-4: 12,423'-12,443' (4 spf, 9/12/01) A-2: 12,450'-12,466' (4 spf, 9/7/01) A-1: 12,474'-12,502' (4/94 & 9/01) Production Casincr 7",26 ppf, L-80 at 12,722' Scab Liner Over CasinQ Holes: 5%", 15.5 ppf, L-80, Hydril 511 at 7600' - 9350'. Baker packers at top and bottom. Last Updated: 11-Jul-06 Updated by: JGE Re: 10-403 for Casing Change in 3M-23 e e Hi Gary, Your plan looks appropriate. I will look forward to the sundry. You have approval to proceed with your plan. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 7/11/2006 7 :27 AM: Sharon - We need to submit a 10-403 to the AOGCC today for well 3M-23. We want to install a scab liner over holes that we have discovered in the 7" casing. The uppermost hole is between 7695 and 7728' MD and the lowermost hole is between 9214' - 9275' MD. As shown on the attached schematic, the 5-1/2" scab liner will span these holes. We do not plan to run a casing inspection log as the good casing above and below the holes has already been tested to 2500 psi. The casing holes are in the vicinity of holes that developed in the tubing string. Following installation of the scab liner we will retest the casing to 2500 psi. Please call if you have any questions. I'll be out much of the day but Howard can sign the 10-403. «3M-23 proposed schematic 7-11-06.pdf» J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 1 of 1 7/12/20061:27 PM e ~e WELL LOG TRANSMITTAL PRoAclivE DiAGNOSlic SERVicES, INC. ~,. \Cò 1 \~ To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1 ] Caliper / MTT Report for 3M-23 Dated 18-Apr-06 2] 3] 4] 5] 6] 7] &"CÞrl\tNE!J· JUN 132006 Signed: Date: Print Name: PRoAcTivE DiAGNOSTic SERvicES, INC., I ~o W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANCJ.tORAGE, AK 99"; 18 PJ.tONE: (907)24";;89"; I FAX: (907)24";;89";2 E;MAil: Dd5A~ld ORA{¡E@"I/EIV10RV!OG.COIV1 WEbsiTE: MEMoRyloG.COM C:\My Documents\ Work\ DistributionLablesNew\ Transmit_ Original.doc I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: e e j CJ3-/'Ör Memory Multi-Finger Caliper & Magnetic Thickness Log Results Summary ConocoPhillips Alaska, Inc. April 18, 2006 8018 1 3.5" 9.3 lb. L-80 EUE Tubing Well: 3M-23 Field: Kuparuk State: Alaska API No.: 50-029-22426-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 12,325 Ft. (MD) I Inspection Type: Assess Internal & External Co"osive Damage to Tubing COMMENTS: This Caliper/MTT data is tied into bottom of 3.5" Tubing @ 12,325' (Driller's Depth). This is the first log of this well with the 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface ofthe 3.5" tubing in this well and the Magnetic Thickness Tool responds to the total thickness of metal of both the 3.5" tubing and 7" casing strings within the logged interval. The entire tubing string was logged with both tools, but the MTT recorded useable data only up to the bottom of the 9 5/8" surface casing (5,424') - therefore MTT results are only provided for this interval (5,424' -12,325'). I I I I I I The caliper data is quantitative and accurate to +/-0.01" in measuring internal pipe defects. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (6,990'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5"" tubing and 7" casing. The MTT is ideally suited for logging single (non-concentric) pipe strings. It is useful in logging concentric strings, but as the number of concentric strings (or total metal thickness) increases, the signal-to-noise ratio of the signal between the transmitting and receiving coils decreases - ultimately resulting in poor signal transmission quality between the transmitter and receivers. The MTT experienced this degradation of signal quality as it entered the interval that includes the 9 5/8" surface casing in this well. The tool string experienced excessive drag during this log run, resulting in erratic (stop and go) tool string motion throughout the entire interval logged with the MTT. While requiring some data filtering, this does not appear to have significantly affected the interpretability of the MTT data with respect to overall meta/loss indications. I INTERPRETATION OF CALIPER LOG RESULTS: This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to poor condition with respect to corrosive damage, with a recorded hole in joint 246 (7,718'). An 80% wall penetration is also recorded in joint 273 (8,564'). The damage appears mainly in the forms of isolated pitting, lines of corrosion, and general corrosion. Wall penetrations in excess of 20% are recorded in 187 of the 405 joints logged. No significant areas of cross- sectional wall loss are recorded throughout the 3.5" tubing logged. The recordings indicate deposits in many of the joints, particularly below 8,000'. However, no significant 1.0. restrictions are recorded throughoutthe 3.5" tubing logged. I I I I I Pmf.\,ctive Diagnostic Services, Inc. Phone: or 565-9085 Fax: Prudhoe Bay Field Office Phone: P.O. Box 1369, Stafford, T;< 77497 565-1369 E-mail: 659-230ì Fa><: I I I I I I I I I I I I I I I I I I e e Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRA nONS: Hole Line Corrosion Line Corrosion Line Corrosion Line Corrosion ( 100%) ( 80%) ( 66%) ( 52%) ( 49%) 246 273 241 247 259 7,718 Ft. (MD) 8,564 Ft. (MD) 7,563 Ft. (MD) 7,746 Ft. (MD) 8,110 Ft. (MD) Jt. Jt. Jt. Jt. Jt. @ @ @ @ @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 16%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing logged. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 5,424' -12,325' (below the 9 5/8" surface casing). Graphs depicting the Average Circumferential Metal Loss and the Maximum Recorded Sectional Metal Loss indicated by the MTT are included in this report. The Average Circumferential Metal Loss refers to total metal surrounding the MTT tool and these results show very little (2% - 6%) total metal loss throughout the logged interval- indicating no major internal or external circumferential metal loss to the tubing or casing. In this graph, the gas lift mandrels, nipples and packer show up as significant (20%-40%) increases in metal thickness. The included graph illustrating the Maximum Recorded Sectional Metal Loss by the MTT refers to the maximum indicated metal loss by anyone of the 12 radial sectors recorded by the MTT. This graph shows maximum indicated sectional metal loss ranging from -5% to -35% throughout the interval logged. The MTT recordings between -6,800' and -11,700' appear to correlate very well to the internal damage recorded by the caliper, and this internal damage is believed to account for the vast majority of metal loss indicated by the MTT over this interval. Between 6,800' and the top of the (MTT) 10!:UJed interval @ 5.424'. the MTT indicates a line of metal loss on the low side of the tubing that is not indicated bv the caliper. This points to the probability of corrosive damage on the outside of the tubing over this interval. While the results in a concentric string application are not quantitative, the extent of the external damage over this interval appears similar to the internal damage recorded by the caliper over the lower portion of the tubing string. If this is the case. the results represent an external line of corrosion with penetrations on the order of 30% to 40% wall thickness over the loaaed interval 5.424' to -6.800'. It is likely that this damage continues up the 3.5" tubing into the interval covered by the 9 5/8" surface casing. Increased sectional metal loss indicated by the MTT over the interval 11,700' to the bottom of the tubing @ 12,325' indicate some minor external metal loss over this interval as well. I Field Engineer: R. Richey Witness: T. Senden I Analysts: J. Burton / M Tahtouh ProA.ctive Phone: or Prud!loe P.O. Box Stafford¡ TX 7ì497 565-1369 E-mail: 659-2307 Fax: 659-2314 Inc. 565-9085 F;,<' Field Office Phone: I I ew IS I Well: Field: Company: Country: 3 ;\1-2 3 Survey Date: fool Type: fool Size: No. of Fingers: Kuparuk ConocoPhillips Alaska, Inc. USA I I Penetration amI Metal loss (% wail) I metal loss ppnptri¡ lion penetr<1.tion 300 I 250 200 150 I 100 50 o o to 1% 1 to 10% 10 to 20 to 40 to ovpr 20% 40% 85';;' I CLivI 1 I loss o I Damage Configuration ( 150 CLM 4 CLM 2 I 100 CLM 3 I 50 o I Isolated pitting genera! Imp nng hole / po>;> CÜITOSlon corrosIon corrosion ¡ble hole CLM 5 I CLM 6 Botton! of Survey = 3139.8 I I Analysis Overview page 2 I I o a April 18, 2006 MFC UW 24 No. 1.69 24 2113137 Nom. Upset 3.5 ins Damage Profile (% wail) metal loss 50 100 ITIIT I I II I I' I I I I Pipe 1 I I I I I I I I I I I I I I I Bottom of I I (¡¡ 200 6251 ..Q .,..J E LL :1 C Z ..c ..... ..... eLM 2 c Q.. 0 Q) 250 7827 0 Recorded Damage to Borehole Profile 3.5 in (14.8' -12325.0') Well: Field: Company: Country: Survey Date: 3 M-23 Kuparuk ConocoPhillips Alaska, Ine. USA April 18,2006 Appro,. Tool Deviation Appro,. Borehole Profile 50 100 eLM 1 150 eLM 3 300 eLM4 350 eLM 5 eLM 6·· 389.8 o 50 Damage ProtÎle ('X, wall) / rool Deviation ~ 389.8 15 1551 3113 4689 9410 10994 12325 100 I I I I I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: 3M-23 Pipe: 3.5" 9.3 lb. L-80 Average Recorded Metal loss Relative to Calibration 6,990' -50% -40% -30% -20% -10% 0% 10% 20% 30% 40% 50% T' 3.5" I I I I I I I I I i I I I I I I i I I ' I I I i I I I I I I I I I I I I i I I I I I I I I I I . ,.-,----,----r-- I --1 ---,--+--; Inc. USA 18,2006 Depth 173 5.424' 198 6.189' 223 6.965' 248 7,671' 273 8,453' 298 9.188' 32l945' 4 348 10,653' 5 373 11.430' GLM 6 398 P cker 12.133' Change il"l Metal Thickness {%j in Metal I I I I I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: 3M-23 Pipe: 3.5" 9.3 lb. l-80 Tubing Inc. Maximum Recorded Sectional Metal loss Relative to Calibration at 6,990' 248 7,671' + i m8~3 t I~ j í 2~.188' t 3~9," f~6~ I I I ¡ 373 I I r 11.430 i jl I +398 I' t 12,133' I, ~ ~ ~~ ~'--,--r ~---1------.---! -50% -40% -30% -20% -10% 0% 10% 20% 30% 40% 50% 7" 3.5" USA 18,2006 Jt. # Depth 173 5.424' 198 6~ 189' 223 6.965' Change in Metal Thickness (%) in Metal III Increase in Metal I I I I I I RT JOINT U ON EET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf 1.-30 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 13, 2006 I I I I I I I I I I I I I Joint It. Depth F\ Pen PelL :vie-L11 Min. Damage Profile No. (Ft.) Body !.D. Comments (%wall) I (Ins.) (Ins.) 0 50 100 I 1 15 ! U ') m~1 i:~'"OW piUing " -. ) 43 ! I 17 ) C)' . Shallow pitting. III! " i 84 1 III! ~~__~_...".m.."'~",~..._m_ 4 .lJ2 I ') ) IJJIj I 5 ..146 II I I 2. Shallow Ditting. II I 6 1]3 () I ) ) (" - . . III! I ~.J.2h,}llow plUmg. I I I L-Z_~_~;ZJ.O () II ) 2.93 IJJIj I I I ß 242 () 0.02 ') ) )93 I I i 9 ') .. ..~ 0.03 10 ) 2.92 I I ~I .) >--...Jº~~ 304 0.02 ) 2.94 I ",.. 002 I II 336 ) 2.93 12 167 ! 0.02 2.ci3 ..._.._~._._-_.............~......__._...._.~...~-~.~ . Ii F)8 II 002 2 2.93 14 4:~9 u om I ) 2.93 ._.............._..~.~-~- . ~_.........__...._----. 15 41>1 I OJn II I 2.92 I i 15.1 )2 II 0 t I 0 DS Nipple I I I I 16 :n 0 0.02 B I I I I I !4 0 0.02 B I I I 1 ;6 II 003 I 1 J7 0 0.03 U Shallow nÎt ¡I1\I. 2 d8 0 0.02 9 ) 2.c)i 21 >49 II 0.02 -; 2cn I ..... b81 II 0.03 1) ) 2.93 Shallow pittim1;. I I I '12 0 0.03 II 2.94 i I I I I I I I I 743 I o Jr3 L2 ) 2.94 I I I ì75 0 0.02 .-; I 2.93 ~~;¡i' 0.01 6 2.93 0.02 7 ) 2.91 867 J3 I ) 2.c)2 Shallow DiuÎIW. 8 J3 10 I 2.B9 0 I 6 I 2.92 I )2 ~~=l: 2.93 32 0 II 0.02 2.93 II! 33 I ( 2.91 III 34 I 9 I 2.91 III I I v:¡ I 11 I 2.93 II! 36 0 7 I 2.92 III! u I 1) ) 2.92 [If 38 I 0.04 17 I 2.91 Shallow DiuinQ. I 39 ¡207 0 0.02 9 I 2.94 [If I I I I I 40 P39 II 0.01 4 ) 2.94 I I I I I 41 1:170 t 9 2.93 Lt " I I I 4) 1302 0 I) I " I 2.93 4':\ Jin 0 () ) 2..93 III! 44 1\6') 0 U ) . 2,93 Shallo\\IJ2ilti.t.Ig,......~_... III! 4') IF)') 0 I II ) 2ítili;;::~:' pitting ,._-~",.."._.._-~._--_.._- -_._~_.~ - - II 0.03 46 1426 ¡) 0.04 14 ) 2 Shallo'6l...pittil1\<. III III I 47 1458 () 0.02 ) 2. III I 4ß 14ß9 II ) III I 0.02 2.93 _ IIII I I 49 1520 (I p.02 ) 2.90 '" I Body Metal Loss Body I I I I I I I I I I I I I I I I I I I RT J NT ULATION Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 18, 2006 Well: Field: Company: Country: Survey Date: loint Jt. Depth 1\'1 Pen. ['PIC ,'vlelel Min. Damage Profile I No. , Comments (%wall) . (Ins.) (Ins.) o 50 100 I .50 ¡ 551 U ÇUJ2 9 ) 2.92 111 I II I II ')1 1 ;81 U _D.03 1 13 I 2.90 Shallow Dittin\.!. II , I ~) II I 2 2.91 ", I I II 12 0.03 I I I ,)i ')44 0.03 11 ) 2.91 ", , ii ')4 ')7') \1 - ¡):Ö2 7 --III I 2.93 ')') '06 U 0.02 6 ) 2<:13 I __2l.>~__ . 1737 U 0.04 7 2 2.93 Shallow Ditting;. ~ 5ì 1767 I) 0.02 9 ) 2.93 _5fL 1798 u 0.04 '6 2 2.9i I Shallow QÍ!~ I I I I 59 1829 U 0.03 0 ) 2.94 , I I (,0 1860 \1 0.02 ) 2.9í- , 61 1890 1.1 0.02 9 2 2.93 62 '¡920'" I) 0.04 ) 2.91 Shallow nitting. !'I 63 19,)() I) 0.02 ) 2.91 64 1981 I) j 2.91 Shallow nittiml(. I 6) 2012 I) 2 )2 III I I 66 204} U 1 ) I ! 67 2(7) U ) ) Sh, ¡lIow Ditting. I I 68 2107 U '0 i 01 !tee! Ditting. 69 2138 U 9 2 low Ditting 0 2169 U oen II ) low Ditting. 2201 U 0.04 14 low Ditting I I 2232 U 0.02 q ) 2 I I ! 2263 0 0.02 B 2. I ! 2295 U 0.04 17 ) 2. Shallow pitting I I I 2127 I) OJJ4 14 2 2.92 Shallow pitting 2158 Iì 0.04 14 I 2.91 Sllallow pittil.1R____~_~_._____~______.Jtt 2390 U 0.0'; II ) 2-02 2421 u 0.04 14 ) len Ck,1I n;H;nn III S I) 0.02 ß 4 I 2.91 I I B' U 0.02 9 Iì 2.90 I .-. I I ¡ Iì 0.05 19 2.89 , I 4' I) 0.03 12 2 2.91 IBO Iì O. J3 ! ! 2.W I \1 O. J3 II 2.9C I \1 J3 12 2.92 Iì J3 13 2.92 0 )3 12 Iì 2.81: \1 12 2.86 I \1 9 2.87 U. Ipnn" 90 II 10 II 2.87 !'II I <)1 Iì 13 ¡ 2.88 "I¡allow niHill\'!. !'II I , , <)) fI' 0 14 15 Iì 2.B8 Shallow nitting;. .~ 9'1 2891 (i 0.04 16 II 2.89 Shallow nitting;. .~ 94 ) ()-') II 0.03 ;, U 2.B8 "hallow Dittin\.!. It. ¡pnn"lt~ 9') 79')(, (i 0.02 ß I ) B~ !III 9¡) ')()f\¡) (i ß ---'-- -=~__L ----- --_..~~_.._-,_.~.,,_..~_.._-~-- --,-,~ . 0.02 I 2.87 97 '1017 i.1 ' 0.04 17 (i 2.85 _2lnllow Dinin\.!. !'II II <)8 '1049 (i 00'1 11 U 2.87 !J,12<::12Qsi ts. !'II 99 1079 (i ()"º2~_ () 2.84 pr Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I J NT ULATION Pipe: 3.5 in 9.3 ppf I.-3D Well: 3M-23 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NorninaII.D.: 2.992 in Country: USA Survey Date: April 13, 2006 joint jt Depth 1'1'1 Pen. Pen Mei,! Min. Damage Profíl No. (Fl.) ·t I.D. Comments (% wall) ( i (Ins.) (Ins.) 0 50 100 100 :¡In Ii 0.03 I 2.84 1.1. ILE:posits. f\I!I ì III 101 3144 Ii n 2.3ì -~"-~'. 102 :¡lTi n ; 286 II ! Hn 3205 () n 2.33 II I ¡04 V:¡8 n ') 2.36 c h;ll ImAl nittinç¡ f\I!I 105 '1269 n 3 I I 2.39 (h;ll low niHing I t jp,vw,k f\I!I :¡:¡m ._~~~, c h;ll low niHing II 11II 06 I) =8l~ I I 2.90 10ì r¡ "} ")') n 0.04 o 2.34 (hal low nitting t npnn"ik f\I!I ).)-)~ 103 3363 n 0.03 n 2~33 1M I I I :09 3394 n '3 IU8~ Shallow nlttllhl. " r- 110 3426 n 2 i) 2.8ì Shdllow nittll..,l, · II '1453 !) ì 2.89 · 11 1439 n I · n 520 n n · i I 11 L Fí52 n J Shallow nitlimL III II ' u533 n J. n Sh;lllow nittlnll. ,III n =:\1 14 I) ¡. Ii 2.86 Shallow nittinll, III 11 1645 Ii J. I I I 2.85 III I 1 16ìì I) J. 2.85 ¡allow nlllinll. : t. III I I I I .1 '08 !) (UB I 2.90 Pt JP Shallow nittlnll, III I I I I 1 .2 i) 0 0 Ii "N A (;1 M! II atch ø! 1 :o()) ! I 1 .3 Ii 0.03 II Ii \5 PUP 1.1. Denosits. ~ I) 0.12 41i ) \C} I;r;¡;t(=a~¡;i Uil12. ..m.~.,," -------- I n 0.11 43 i \7 Isolated DittimL It. I J1 I) 0.03 2 Ii I P' :~~~=l-=;: 0.10 40 ) Isobted niuinll. P 0.04 14 ) Shallow clUinll 1)4 3885 Ii 0~05 , ) I IsoblE'd ciUiml. I I. P5 391ì Ii 0.06 22 ) Isolated nit! InQl. I I 126 Ii (L05 19 I SIFllow DiU nil 12ì Ii 0.04 14 Ii <;Inllnw IJitting 128 Ii (j09 36 ,nh'prl "iBng Lt. 'l",nnc k 129 , J*=+=+=: 0.05 20 i Lt 30 (U2 4e ') LinE' ,I. 31 I()() 35 T ') inE' ..1. 'l",nnc,te ! I ! n;> I! .05 Ie I '-'¡ in I! ~..:-r 22 I 7 inp f\l!l1II n4 I! 13 ¡ 7m IJII II~. f\I!I l'H' I! II Ie 1 7R5 I.!. ~a ,)-) FIr. 4254 I! 12 I ., 2.86 ~'~., ~ I ! nì 4285 i) ..'2. iì 2.821 t )",nncite ~ FiR ~4.1~!(~ "-'0'- )Re¡ <;h;,!!nvv nittim' I t n ~ I I i lie¡ 4ci4ì I! 0.04 I ;>Rì Shallnw nìtting ¡ 140 43ì8 !I 0.04 I' I 2 fiR Slullnw nìttìng ~ 141 4410 I! ()'o6 ) I 2Rc) l<;nL1TPr! nittìng I T ~ 142 , I) I ;>f1C) 4L¡40 (U) I, I 14i 4468 () 0.04 I 1 2.8ì Shallow nittil\Q f\I!I 144 4500 I! Of)::;' 10 3 2.88 pi! 145 4'HI I! 0.0'; 20 I 27J(," Shallmv niUìm". IUS 146 4561 U 0.04 16 I 2.8R Shd!low nittimI. f\I!I Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I JOINT U N Pipe: Body Wall: Upset Wall: NomìnaII.D.: 3.5 in 93 0.254 in 0.254 in 2.992 in Well: Fìeld: Company: Country: Survey Date: L-80 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 18, 2006 Joint It. Depth Pen. PerL Pen. vi (' ¡:;¡ Mi;;. fhnuop Profile No, (Ft.) ( I.D. Comments ('y" wall) (! I (Ins,) (Ins.) 0 50 100 147 4593 i.I 0,04 14 ! ,2~ ~~r~~~~~1;~;~:' LLJ2§)Q;;its. : :11 Ilf I 148 462'1 I) 0.04 !6 2.88 I 149 46'16 II 16 ) 2.8'1 Shallow nittiml. I t. riP'''''''+'- 11II I' II I 0.04 - . I 1'10 4689 II 0.04 15 I 2.83 Sh'll1ow oittil]Q. Lt. Deoosìts. 1'11 477 Ii 13 1) I 2.85 Lt. Deoosits, ."-..-...-......-,. II 1'1) 47'1 Ii )4 14 ) ) 84 ... Sh;lllow nittim, It. ')"',,,1,c;;::·-..·-....·........'....'·--!III 1 S~ 47R Ii )4 16 ¡ 2,8;2. Sh;ll1ow nitti",,;> 11II11I 154 481 U 113 13 2.122 I Sllallow oì ttìlliL..hlJdJ:J2.Q;;LtL...._ I I 155 4844 {) 0.04 14 2.83 Shallow nittlng I j npnn~ik -!II' I I I 156 48 II i7 I -') JJ;! Shallow nlttinQ It. -III I I I I 1'17 49 II iB ) 287 Shallow niHinQ 11II11II I I I 1')8 4( {) 17 4 2.88 Shallow pitting._ 11II11I F¡9 4( ( 2 4 2,86 11II11II 160 S( I 0.04 I ) " low nittim, 1 t. flU 161 ')( I I " low nìftinQ -11II 162 S064 I I " ,a low nìttinQ I t. -!II 161 50% I 1 " 1a low nìttìmz. I t. -III I I I I I I 164 '1127 ( ( " 1;1 low nìttinQ - I I I 165 '1158 I 2.85 ,,1,.1, - 166 5189 I I 1,.1, i 167 5220 Ii 0.0'1 Ii I 168 5251 Ii (}o5 1/\ It I I 1 I I ~..9 , 5282 , II 0.04 F I t. DeDosits. I i70" ~_531~i_ ( 0.03 1 ) L t. L1?11Q;¡i!;¡. I , ___n__ , I ~..lZJEffi45 I! 0,03 II It. DeDQsits. rœ , I - "^__ __un ~-- L--J.Z: 5 3 76 II 0,03 Ii !!II e---l== 540ß i.I CUri 11 11II 17' 54{9 {} 0.03 12 11II 17' 5470 Ó 0,04 17 I 1,84 )ittillfL 11. Deuosits. lilfI!I I --, 17( 5502 I! o .en u I 2.ß6 Shallow Dining" 177 5533 Ií 0.04 15 Ií :7 8"; SI¡al!ow r;U¡;~g-:----'-- ! 7¡ 151)S II 0.03 I' íI ) li7 ¡ ¡ 7( 15% I .... I') I! 5ha Ilow DittÜ1IL,___.. ~ II 0.04 2.87 617 I! 0.03 13 -¡hi! IlowD tt ng. I ,9 I 0.04 16 ;ha IlowD it nR Lt. )"nne.k m 10 II 0.06 23 sol ated D tt ng, I I 1 I 0.04 14 I ,I);, IInw n Hng I CUB I) () '~ ! 0.03 II! I ) iii; q I II! 1 ~..-------_....~ ,Q,03 2.88 _~._.~__~~..u_ I I 187 e q, I 0.03 10 il ) li7 I HIli Sf) I Ö.Ö3 -- ! ') S :ì Iii) Slnllnw nlttlng I j I')pnncik I 189 '191 :ì liS Sh;1l!nw nitti,,º,, I ! !. O.O;L_ I' I ) 190 ')f) {( {) 0.05 19 I 2,85 S1al!nw nitti.w I t ')pnnc¡k .. 1f) Sf)7( !I 0.03 1\ ! 2,84 Sll1llnw nitting · 1f)) 6002 n 0.04 15 ! 2,85 Sì;ìllnw nlHing I t r)pnr,,";'" · 19'1 i)Oii !I 0.04 16 .....j 2.85 S 1);,llow I)lttl\1g. IiI 194 6065 II CUB 12 4 2.1\6 ! !!II 195 6096 nOb 0.04 14 I 2.89 Shallow nittinQ. · 196 6126 II 0.03 11 c, 2,R8 Shallow niailIQ. Body Metal Loss Body 4 I NT TABULATION I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date; 3M-23 Kuparuk ConocoPhillips Alaska, Ine. USA April 18, 2006 I I Joint jl Depth p, Pen. Pel ,V\e:;1\ Min. Damage Pl'OtÎle \ I.D Comments ('Yo (Ins.) (Ins.) 0 50 100 I 197 6157 0.04 Iß I 2../?4 Shallow nittimr. · !fill 1<}8- 6189 () 0.04 I' I I 2,82 "L " :- .) )9 6220 I 0.04 14 ) ins CI,.II ;H;, )(1 6251 --tli"' 10 2.86 ~ )1 . 6283 un 1) 2. n6l1.QE'PQ~i1~m_m._m...m...... )) 0JIL. .04 16 5 I ~:ft r=~;~TI(:;~~PittíIìg...LLJJep(22i!L...____ n 6346 I J16 )2 I 1 I 204 'm 6377 n (\04. 15 2.82 Lt. f-.205 6409 I 0.04 I'; 0 2 QÇ1.. n I n 1"'!f!II 207 I I ", Lt I )()8 n 2 209 II Lt !fill )10 I \ 28') I" )11 I 0.04 ) \8 I 212 61 I ) ;7 Lt 21\ 61 I 2 R ;7 knht",, "iltino I I 214 6688 I (, ) 4 Line Lt I I 21') 6716 I 2 """UW Plttmg. Lt DeposIts I 216 6748 í} m 0.04 281 - Lme shallow (01 loslon. 217 6779 n ní) 0.05 . 2 90 1s0I,lted Dlttmg I 218 6R10 II (H)') 2 R7.. _SIHllow wl~ Dep()ill~~__ 219 6841 II 007 21{ 2 n9 .. LIlli" (orroslon. Lt. Deposits 220 6872 n n.n6 24 2 8/?.. f-. 1s01,1ted PItting I 221 6903 -^^^ no;' O.OC 21 ') 2.BB Line I 222 6913 I O.OB 12 4 2.8B Line Lt. DeposIts I 223 0 0.06 21 5 Isola led pittim>;. Lt DeposIts. I I 6964 2.88 I I 224 6996 I 0.08 II ') LB7 line Lt I I ! ... 225 7027 I O·QZ --..- 2<) ') 2 B6 Line corrosIon. Lt Deposits. 226 705R on:- C1.IO 5<) () 286 Litle corrosion Lt. DeposIts 70,;9 I 0.07 2ß I 281L Isol,1ted pitting. Lt. Deposits. 71 10 I 0.09 3:- 'j 289 LI!iE:' .c9r]OSI011._Lt. DeliO."lts --- ----- -- '1 0.10 59 ( 2.86 LI!)e (QII()SIOJI_. .. _ m mm -- - m .. . IIU(, .07 29 '; 2.86 Lme C orrOSIOI.ì I I Deposits. . 1I.lIh .09 33 " 2.84 ,ine Lt. n .,. , .07 28 'i 2.85 Isolated nittimr. Lt I I I .11 43 (, 2.85 .ilìe I t DeDoslts I .07 29 4 2.86 .ine Lt. O!'f 23 4 , I t 2.86 .ilJe Lt. DeDoslts. 1.1 O.OH¡ (, 286 Line C 01 roSIOIì. Lt. DeDoslts. n O. 24 (, 2.85 Lme cOlJosloll_Lt. [)~pos¡ts_ - ---- - nR 74 11.11 0.09 37 '; ..; 88 lIne ( orroslOI1 Lt DeDoslts :nc¡ 741 ~~ 27 4 2.BC¡ Lme corrosIon Lt DeDoslts )40 74 .. (;¿-- 3'; '; 2.88 Line corrosIon. Lt DeDoslts. )401 7526 )3 2 )4() :> '7";1:; (I Nj~\ CLM 2 (Latch @ 3:(0) I )40.\ 7541 II 0.06 ) 286 P lJ P lll1e.i.orm.>lQ.Iì._ Li.l2..E:'PQ,sl.ts _ .__ ~ III. )41 . 7'147 "I¡~ Ie¡ 0.17 (, 290 Lme corroslorL 242 7578 II 010 2.89 Lll1e ( orroslon. 24:; 7609 II 010 (, 2.90 . Line ( oJrQ(o;I()I1___ - - -- . I I I I I I I I I I I I Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT u ON SHEET Pipe: Body Wall: Upset Wall: NomínaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in 3 M-23 Kuparuk ConocoPhillips Alaska, Ine. USA Aprí118, 2006 Well: Field: Company: Country: Survey Date: Jt. Depth ~^~----- Pen Men11 Damage Profíl I Joint Pen. Min. No. (Ft.) I -I I !.D. Comments (0' 10 ! 1 (Ins.) (Ins.) 0 50 100 .. 244 7641 !i 0.11 4) 6 . 2.91 Line corrosion. Lt. Deposits. 245 ----Z§ZJ_. j) 0.12 4 i .¿cJI. Line corrosion. --- -~~-"~~" . 24(, ìï01 !i. !i 7' OC)O ¡ [) 16 2.89 HOLE! -----~-~-~ , 247 71')2 -j - ~-- ____.__.,___·.____·___'m'..__'_,~____._'.'_m________ !i 0.13 2.86 Line corrosion. Lt. Deposits. 1)411 ìï6S !i !il 010 5 2.88 .JJIlç'...<ImJlQ?lO~LLL12~QQill>· 249 77% !i ()I 0 .5 2.86 .UIl'=~m[Q;;i()IL1LQE¿J2.(&i.!?~~~_~ 2S0 7fQ7 !i 0.09 6 2.86 Litle cQrro?jillL_L t. Deposits. ')51 78S9 I )!ii) 0.12 .h c 2.88 Line corrosion. Lt. Deposits. I 'S2 71190 !i 0.12 h 6 2.86 Line corrosion. Lt. Deposits. '53 7921 !). !il) 0.11 ·1 6 2.88 ine U.IIC II. .t I 254 7953 0 0.12 It It 2.88 ine ,Ie t ') ~ ~ 7984 !i .!iii 0.08 32 5 2.86 tne CUIIC II. .t. ~J¿_ 256 8016 0 0.10 3ß It 2.87 ine II. t 8047 !i !ii) 0.11 44 I It tne UlIle II. .t. 078 !i 0.10 4 It tne 1. ¡108 !i 0.13 49 It !ne 1. ¡I fO 0 0.11 44 7' ine c 11'- II. t I ,I ¡I '2 !) 0.09 3'1 'i 2 !ne Lt. Denosits. ,2 ¡2( i3 0 0.09 F ß 2.83 ¡ne 1 t ,3 32 :4 0 (LIO 39 4 2.85 Line corrQsion. i I 264 8265 0 0.10_ þ¡-- ~ LiIJE¿~QJlml;jQ_'LL.LJ)E:12Q.sltS___...___ I I ')( ~ ~6 0 0.10 2.87 __UllenQI!Q?jqlL.L.tDE.12Q;;jt;?;,...._._.___ I _.",.2.2.__ !i '1- 2.87 . 266 8328 .. 0.10 LinenQW2?ion. Lt.Deposi!?t_____..___..._.. )(,7 8359 !) .£1..uL ,. I' Line corrosio.n. Lt. Denosits. )(,f\ 0 0 ..OJJ8 33 -I:';'~~ .. Line corrosion. U. Deposits. )( !i. on 0.08 n I 5 .85 Line corrosion.. Lt. Deposits. 0 0.11 42 .85 Line corrosion. L.tJJJ:?.J2Q?.its. .D.!i . 0.09 35 .80 Line orrosion..JJ. Denosits. ~~. 8515 J.08 5 2.86 Line corrosion. .Lt. Deposits. n_n 8545 1.20 (, 2.84 line corrosion. LI. Deposits. 8576 ).11 "0 2.85 Line corrosion. Lt. D':"Dosits. I I 8608 ..Q. 1.11 (, 2.85 line .... ..... . Lt 276 .tHAO !! (UI (, 2.86 Line L1. ')-r-;r 8671 !! 0.10 (, 2.83 Lllle .t. ~II 2711 \7Ö' U '(is ~ 2.82 Line .t. 279 :1'1 !! ::~tb (, ¡1 Line ..t. 2110 :7(, U Line .t. 2111 :79 0 .(iti 33 4 line .1. 282 8827 Ii Hi8 'sl It Line .1. I 2Hi 8859 !! 0.08 "2 'j Line Lt. Deposits. I I 284 .12139£1_ {) 0.09 "5 -, tine..<~orrosion. Lt. Deposits. 28S 8922 !! (1.08 jj ) Line corrosiQIJ. Lt. Deposits. I 286 HUp,c)54 - 0 0.08 n L Line corrOSIOl1. Lt. Deposits. 2117 8985 o!! c 0.09 "il L Line co rrosiQ!l_l t. Deposits. 21111 90,6 0 OOC) 17 (, Li le corrosion. Lt. Deposits. 2WJ 9047 0 007 J(, 'i 2.82 - .. .LiDe.~:o rrosioll. Lt...Qe!2Q?i.1:2~.. ~^~~---~~...~-,~... III 2C)0 9078 0 0.08 II !J 2. I il1f' I I. flµ",,<c;¡<c I 291 9 111 L.!!5 007 211 'i 2. Line cOrm?iQlLlt.l2.tI.)Q?i!?.,....___ ...~.~~ 292 9142 U 0.06 23 (, 2. ¡ine 1 t. nµnnc,tc 292.1 9172 U 0.04 17 ) 2. PUP Shallow I Body Metal Loss Body Page 6 I REPORT JOINT u N SH I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 18, 2006 I Joint J1. Depth 1\ Pen. Pen. ivietal Min. Damage Profile No. (Ft.) I ID. Comments (OJ ,0 I (Ins.) (Ins.) 0 50 100 292.2 91ì8 0 0 . 0 N/A CI MI II Me-I. (àj 12:om 11m 292.3 9187 1)11", iH I 279 PUP Shallow niHinQ Lt. )(J ()' 0 15 6 281 Lllle ( orroslOII. L t._D.ej)i~1 t~_ ' I ~~ -~- - ~-- )9, 9 0.05 I, 282 It.l1t corr9SIQlL Lt. CltP9'ilts. - . -~ )9 ') 0 16 6 2.82 . . 111 H,' ç orr.o~9!LJJ. [)e!2051t~.__ . - ----- ~-- )C)¡ ') I)U(( 15 g 281 It.l1t ÇOlJOSIQII._i.t {)eposl!s.__ .- I I I )c)7 9;U.8 ¡) ;7 II I (UP Lme c orrOSIOl1. Lt Denoslts 298 9348 0 0.10 ¡Z---+ 10 2.80 LIIK' conoslon. Lt DtPoslts. I )C)C) 9379 0 0.07 I, 100 c)41O ¡) .09 34 6 27C) . t I i 'ml .-. 9442 ¡) 10D I 2K¡ Lme corrosion I t Deposits 1H)2 9472 -- 0 0.09 15 3 282 ine ·I·t.-;:¡ 'HB ')~(¡K Ii 0.09 h ) 8~ ¡ne t. ---'t-r .) 104 9535 Ii 0.10 I H 2.79 Lme c (HrOSIOlì,_I..Ll¿E'.1)9.s!!.s"'-_______ --~ ~~-~- 10') C)"j(,R 0 6 I 2 R2 Line c orrOSlOII. Lt Denoslts. 11 9599 I)! i5 I) 2.80 I Lllle corrosIon. Lt Deposits. I 31 9(,30 0 6 Tille .t. r1",nnc;tc I I 11 961;:; 0 6 ine .1. r1",nnc;k , 31 9(i92 ¡) 0.11 7 L!IIe corrosion L1. Denoslts 110 9ì24 II O.Óq- h LII1P corrosion I t Denoslts 111 97')7 ¡) 0.08 '7 L!IIe C0.lTQS!91l- Jt Q.e[2'=)S1Is.. . 112 9788 ¡) ill1 4, h Lllle c orro S I 313 ..- 0 0.09 I, I I 9820 Lllle corr I .114 98')1 0 0.09 Line I ~J.l,5 . _+.....2Q12;f 0 0.10 Line Lt.I'; I I I .. JJ 0. 9914 II 1).cJ9' 3 Lme c em oslon Lt Deposits 317 9945 () 0.10 . 40 Lllle corrosion. L t. Denosl ts f-----,.---..- 9977 n.05 0.09 Vi - )18 LII1P COI rosl.Q!l....Lt.I~[l-ºS.lts '319 I )8 (ì 0.08 33 ~ 28') LlIle corrosion Lt. Denoslts 320 ¡ 19 il 0.09 3'; H -)-...- LlIle corrosIon L1. Deposits 321 I 'I (ì 0.08 32 ~ ) illP Lt. Deposits. I 322 1 J3 11!i') 0.09 ;4 Ii 7' lie .t )nnn ik 323 .10 )4 !i O.!O 39 ~ ? np t. II. 324 10165 Ii 0.()9 37 CJ '7 np II. t. bnn ik 325 10 CI !i!i') 0.10 3ß ) :n np ill II. _t. 326 II !ì 0.10 40 Fi ) J: np I I I =4:==t 0.09 34 CJ ;¡ LII!e (orroslon. Lt. DeDoslts I I 0.09 \'i -, ) '() IIIIP (OIlOSlon. U. Dt"Q9slts . ~ - -~~~- 10322 ii 0.08 3; H )70 ine>·n ... - -'~II"- --.- !O353 Ii 0.10 3ß c ) 7') I inp I ¡ I 3: ¡ 103&iI {} 0.09 3') ) 7') ine . Ii I I I '1» .. I I I I 1Q4J4 {ì 0.06 22 4 '(.ZCL.~~)froslolh Lt.l~I2..QSlts.__ ~- -~ I ni 10445 !ì 0.( 30 ~ 28) Lllìe corroslon...Lt Dpposlts .____ _____.~ ii4- I (¡47 7 U CU 30 h=H% Lllle lorrOSlon. Lt DpPoslts 1)') lo')on !ì (j~' )7 26 ß -; LlIle corrosion Lt Denoslts '1'16 1{)540 Ii O. )5 21 h .80 L 1llE..,Ç 9L[(J5IQIJ~_Lt, QE'.L2OS!ts.. . .- . -n6! 10571 U 017 2ß 1 2.80 r;¡ JP I illP I -nc,2 10577 )) 0 0 !i N/A (~I M J. II ,,1,-1.. (i¡) 230ì BId 10585 !i 0.07 2ß I 2.76 r'Ut Isol<ned nittinQ. Lt. I B7 10.592 )) OQ9 3') 6 2.83 Line Lt. I I I I I I I I I I I I I Body Metal Loss Body Page 7 I I I I I I I I I I I I I I I I I I I I I J NT u N Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 18, 2006 Joint It Depth 1\'1 Pel Pen lyleLd I Min, Profile No. liD. Comment,; (%wall) í I (Ins.) I (Ins.) 0 .50 100 i':\1] 101,2 II 0.08 r '. 2.80 .ine Lt II 'iF) 10(:'5' 1105 ()J)6 ) ~t=t=þ~9 Line lorrOSIOI!. Lt DeDo';lts. 340 101,1]' 0 0.08 iF 81 Line Lt DeDO'iI ts 341 10714 I I IIF 0.05 19 ,2.82 LlI1e shallow corrosion. Lt Deposits. 'i42 10746 II 0.06 24 (¡ 2.8) LlI1e corrosion. Lt. DeDoslts. I 343 10776 0 Q,DL - ß 2·2e1.. _~-')rruslon. _LLJ)Jéj,05IJs~ _, "'-.J - - ~~~ i44 ' 10ROR 0 0.06 (¡ 2.80 iJ1rr(),,1Yl) ,Lt. [ i45 10R40 001 (¡ 2.78 [nlLQ."lQ!.l it J MI. IOR70 II ,. f') 2.78 I 0Us:L'ililLìc LL [ I i47 10901 () (¡ 2.77 (", Lt. DeDoslts i411 10932 () 5 2mÉ~~~1En It Deno,," 149 1091¡'i 0 ~ 2. 0lL LJ~E9~IjS_..,._ ___ I 150 10994 0 I) 2 II " '. I i 11027 0 t 6 , 2 It 11058 iI t 6 Lt. 11089 0 0,06 h .ine .,t. f)p,y.,çit" 11121 II D.D5 (: .ine corrosion Lt Deposits 15'11151 II D.D9 H, (: ( OfIOSlon Lt Deposits 356 =f=~18¡ 0 0.07 Iß {¡ I Corrosloll. J.! Q.ITJQ"lts I ')"'7 ')1" n 0.06 I) h ( orroslon Lt Denoslts --- I I I -),) "'- ~) ;8 12 II ---- 24 ¡, 2.76 I II Qi}6 ( orroslon I t. Deposits . ;9 11 '3 0 0.05 20 II 2.77 111le (orro5IrJlj__JJ.12e.!295lli__ - ------ 0 11 0 CJ.(}7 I )] I 2.82 I ¡ne I t. Dpnn"ít" 11 (I 0.05 19 '; 2.82 Shallow Lt. DeDoslts 11 {( II 0.06 25 (, 2.79 I ille t. DeDoslts. ¡ 1 3( (I 0.07 ?7 9 I 2.80 I ille t. rJpnn"ít" I I I 1142 0 0.06 211 1 2.82 I t. ", I I I 1145 II OOt, 14 (, 2.82 I ¡lie t. Dpnn"ít" JJ490 Ii .)0 '; 2.84 Shallow Lt. rJpnn<;it" 11522 0 36 6 2.8~_ Corrosion. Lt. DeDoslts. 8 11553 Ii --;:> (, 2.ß4 Line Lt. DeDoslb 369 115B3 Ii )7 I 2.83 370 11616 Ii 14 I) jl) - 2.81 LinE' corrosion. Lt. DeDoslts. 1 11647 Ii 0.05 ) 'I 2.B5 PUP Isolated DíttínQ. .2 6' 0 0 0 N/A CLM 5 II ;)f<'h (â)1 0:(0) '{ 61 OOi 0.07 (, 2.116 PUP knl·,t",1 n;tf;n" Lt. )P!,OSItS 161 0 0.09 6 2.B5 .. I ') 16' II I 0.09 ~ 2. )7 ".t. ! I I 'i 7 1106 0.08 6 2. )6 Lt. DE'DOSlts I I 374 11761 II 0.07 6 2. )4 .lne .t. __375__._ ¡ 1792 0 0.07 6 2. )5 LIIIE' corroslCl!.L .lL,.D.£'1 10SI Is {7(, 'ilR)' 0 '006 (, 2.85 1IIIP...LClJroslon...Jlc L:>E'I¡OSI.!S. .. _ . _ _ .. ___ i77 11 R54 007 0.07 () 2.84 ( orrosloLLLLQej)()SltS.____ _...__ i7R 1 18R~ II 0.0 .. 2.86 ( VI rosl()IL_L,LJ)f:Doslts ___._____ i79 11911 II 00 (, 2.85 (orrOSIOII. Lt Deposits I iRO 1194(, II on ß ).83 ì~'±tg~~~~!.g~ '{131 119713 U 0.06 ~ 2.81 LIIIE' (OfJOSIOII I '3132 12009 U.IIß 0.06 ... 2.83 .l1lE' Lt. " I ILL M~ _ 383 , ]2(j40 II Ii", 00') 6 2.86 111](' Lt DeposIts. I I 384 ..12071 DOl, 0.06 14 6 2.85 Body Metal Loss Body Page 8 I NTTABULATI N I I Pipe: Body Wall: Upset Wall: Nominal !.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA April 18, 2006 I i II IJ I Joint No> COl11lnents I I I I Penetration Body Metal Loss Body I I I I I I I I Page 9 I I - - - - - .. .. .. .. - - - .. .. .. .. p S Secti s Well: Field: Company: Coun try: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: April 18, 2006 MFC UW 24 No. 211387 1.69 24 3ft Tool speed = 43 Nominal 10 = 2.992 NominalOD 3.500 Remaining wall area = 95 % Tool deviation = 75 0 Finger 5 Penetration = 0.202 ins Line of Corrosion 0.20 ins = 80% Wall Penetration HIGH SIDE = UP Cross Sections page 2 - - - .. .. .. .. - - - .. - - Well: Field: Company: Country: 3M-23 Kuparuk ConocoPhillips Alaska, Inc. USA Tool speed = 43 Nominal 10 = 2.992 NominalOD 3500 Remaining wall area = 91 % Tool deviation = 87 0 Finger 5 Penetration = 0.9 ins Hole - - .. - - .. p S Secti ns o Survey Date: Tool Type: Tool Size: No. of Fingers: April 18, 2006 MFC UW 24 No. 211387 1.69 24 ft / 0.90 ins 100% Wall Penetration HIGH SIDE UP Cross Sections page 1 .. .. .. I KRU 3M-23 I I 131\1Mi!3 API: 500292242600 Well Type: . ~TS: 44d 12409 TUBING ~-- - vvvV ,vpt;: NipPLE - Oria Camaletlon: [---- Anole@-TD: 44e!< 12750 (0-12325, Last W/O: Rev Reason: Retri FISH 00:3_500. 1M; Last UDdate: 10:2.992) ~ TD: I öI 11I;<u\Jb 70 dea @ 11019 Descriouon I Size Too Bottom ND 1 Wt T Grade T Thread ~ CONOUcT0R _4-_J'.OOO 0 121 121 I 62.58 T H-40 rt V\[ELD!::º-. SURFACE--- SURFACE I 9.625 0 5437 3307 I 47.00 I J-55/L-80 BTC (0-5437. 7.000 0 12721 6374 OD:9.625, ("'TUBIIIIG< C) Wt47.00) ~ I Bottom I ND I Wt I Grade I Thread I 12325 I 6090 I 9.30 I L-80 I EUE 8RD "RODUC110N _.~-. Zone Sb:1tus I Ft SPF Date Type 12423 - 12443 6160 - 6174 CA 120 4 9/12/2001 APERF 2 1/8" Enerjet w/PJ chgs. 0 d~ Wt26.00) 91712Oõ1 APERF [Jh. +1- 90 deg orient I """VU - ¡¿<roo A-2 16 4 2 1/8" EnerJet w/P J chgs. 0 deg : 1 ph. +1- 90 ciA(! orient I 12474 12484 ,,~ u<:u A-1 10 4 I 9/612001 I APERF 21/8" Enerjet w/PJ chgs, 0 deg 9112/2001 J I ph, +1- 90 dea orient 12484 - 12494 A-1 10 8 RPERF ~ 2 1/8" Enerjet wlPJ chgs. 0 <leg ph. +1- 90 d~rìent ~ 6211 - 6217 A--1 8 4 4/23/1994 '¡PERF 4.5" BH Ultraœk 180 (i00l:)j¡ ~D I Man Mfr Man Type V Mfr I V Type VOD Latch Port IRO Date C~~t - ~- 371~ 2682 CAMCO MMG .t~- 1.5 0.250 1?hR 2/24/2006 7530 4008 CAMCO MMG C OV 1.5 0.250 0 2/24/2006 --ª-.- 9174 4672 CAMCO ~ MMG C 0,000 0 11/19/1999 4 '10573 5203 CAMCO MMG CAMCO I m 0.000 0 1123/1999 ~- -11648 5646 - CAMCO MMG CAMCO 1 ~ 0.000 ' 0 1/23/1999 6 12229 ~ T MMG CAMCO 0.000 0 1/23/1999 :·.!c\ME::i·.·.DV Depth ND Ie ID 503 503 2,812 12273 6053 =L ?R1? 12283 6060 ~-- 2.992 12297 6070 \('1<'<=10 3,250 12313 6081 D £ 9/14/99 - Pulled lM'" ""d GauQes. 2.750 12313 6081 F 1-(; 0.000 __ 12325 6090 SOS sUB 2.992 Gas lift ------ ;¡ndreUOummy Valve 6 NIP :12273-12274, 00:3.500) PBR :12283-12284. 00:5875) PKR -ÕD5~937j I I NIP ~. SOS --- I-- Pelf ............ 1- :12423-12443) - ~ ............. - Pelf c= :12474-12484) =.c :.: I I I I I I I I I I I I I I I I ! q ) - r 1?7 ScblumbepglP 03/30/06 NO. 3751 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk e Well Color Job# Log Description BL CD Date 18-06 11213713 PRODUCTION PROFILE W/DEFT (REDO) 02/27/06 1 2T-19 12213723 PRODUCTION PROFILE W/DEFT 03/24/06 1 1E-117 11213725 INJECTION PROFILE 03/26/06 1 1 H-1 0 11213726 PRODUCTION PROFILE W/DEFT 03/27/06 1 3M-23 11213727 LDL 03/28/06 1 e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 3M-23 (193-187) Failed TIFL ) ) Subject: 3M-23 (193-187) Failed TIFL From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Wed, 03 Aug 2005 05 :26:23 -0800 To: Thomas Maunder <tom_ maunder@admin.state.ak.us> , James Regg <jim_regg@admin.state.ak.us> :fg£-- ·eatJID~ Tom, Producer 3M-23 (193-187) failed a TIFL yesterday. T/I/O 150/1180/360. Short term plans are to change out the lift gas string and then Re TIFL it. I added it to the weekly SCP report for this week and have attached a schematic. «3M-23.pdf» Let me know if you have any questions MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 Content-Description: 3M-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 . f' ,. ,to., ¡:¡. -', 'I r\ (' \~ '<'f' f~\N~\\"rr.;.!. ;.) t \'" ('r ~'l ..' ,- '~"~ ,.,-:/' ¡,. ~, 1 of 1 8/3/2005 1 :40 PM ) ~PHILLIPS Alaska, Inc. .~ A Subsidiary of PHilLIPS PETROLEUM COMPANY --------,_.__.~---_._-,_._- - TUBING 3M~23 (0-12325, OD:3.500, 10:2.992) p ,:: -- 11'[,'"" -~". i~' . ,'1>0 ¡: ~:'~ .: ~ I~·---'; :.':' .."'" .,. .r. r¡¡ I II' i!!'I'-'-- ~ ~ -¡ . i , It-··~ ~.""'" ',~. '", ., . ''', . ~: \.,' ~ :"¥ Perf (12423-12443) Perf (12474-12484) ) KRU 3M-23 API: 500292242600 SSSV Type: NIPPIË----·--- Annular Fluid: ,_.Reference Log~--"- Last Tag: 12546 Last Tag Date: 9/2/2001 Ca~dng'··Strli'ig·~..ALJ..; Description CONDUCTOR SURFACE ... ......... . ... .. ..... . . ......... .............. ," . ... . '.. ...... ..........:....... . ..' , . . . . . Well Type: PROD Orig Completion: 12/29/1993 Last W/O: 1/23/1999 ___ Ref.J.9,g_ Date: _______ TD: 12750 ftKB Max Hole.~ngle:<7~~eg5iì)_1.101<9 :"':".::'::':. ........ ....... . ""... .......:. .: :'::'":'"':':.." ':.":. :. ....>::::..:..: : .... ......... ..... ..... ... . ....... ... ,..... ..... . . .___~~@ TS: 44 deg ~ 12409 Angl~@ TD: 44 deg ~ 12750 Rev Reason: Tag, PERF by ImO Last Update: 9/17/2001 12494 -12502 6211 - 6217 : Gas t.iftMándtêlslvalvesi ... .... . St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date VI v Mfr Type Run Cmnt --'¡---3717-2682 CAMCO MMGCAM-CÕ'-GL\I-'--;rs--- RK 0.250 '--1244- 11/20/1999 "2---'7530-'4068 'cArvic'Ö--'- MMG --CÄMCO OV --Ts'-'-RR--'-0.250 'O--T11"2-ò7f999 wICK 3 9174 4672 CAMCO MMG CAMCO DMY 1.5 RK 0.000 0 11/19/1999 --'¡-----10573-S2Õ3-CAMCO MMG CAMCO DMY 1.5 RK o"]oo"--Õ-'- 1/23/1999 5 11648 5646 CAMCO MMG CAMCO DMY 1.5 RK 0.000 0 1/23/1999 -'S'-'T222S"-'Š022-CAMCO MMG CAMCO DMY '-·T-s·--·-1fKp..--'--õ.()ciõ----'o- 1/23/1999 :qth~r{plu.9$;Etqitlp.,~t~;) ~Jl;we ;;~'{. ..P~I!!!!.__!Yº-___.lY.P~_ . Description ID 503 . S03 NIP Cameo 'DS' Nipple 2.812 ---12273-"605'3'-- NIP CAMCO 'W SELECTIVE NIPPLE -_.-~ ·-T2-iš'3-·'-S06Õ---------P BR BAKER 80-40 .-"--'-.----'----....,--=~=:::::=-~_=~~==~==~~=_=_~~=::::==:~~=~=:::::=:=_==_ 2.992 12297 6070 PKR BAKER SAB-3 PACKER 3.250 12313 6081 NIP CAMCO D NIPPLE. 9/14/99 - Pulled DHSIT and Gauges. ----.-...----..,~..- 2.750 12325 6090 SOS BAKER SHEAR OUT SUB - ------------------.-------- 2.992 12423 - 12443 6160 - 6174 C-4 20 4 12450 - 12466 6179 - 6191 A-2 16 4 9/7/2001 APERF 12474 - 12484 6197 - 6204 A-1 10 4 9/6/2001 APERF 12484 - 12494 6204 - 6211 A-1 10 8 9/12/2001 RPERF ..--.--,----- -.-- IPERF Thread WELDED BTC Comment 2 1/8" Enerjet w/PJ chgs, 0 deg ph, +/- 90 deg orient 2 1/8" Enerjet w/PJ chgs, 0 deg ph, +/- 90 deg orient 2 1/8" Enerjet w/PJ chgs, 0 deg ph, +/- 90 deg orient 2 1/8" Enerjet w/PJ chgs, 0 deg ph, +/- 90 deg orient 4..5::. .BHlJltrapak1~0 d~9ph PH.-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 2, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3M-23 (193-187) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 3M-23. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad O0 ?-- i ? 200;, Cons. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ ,Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 68 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1007' FNL, 1619' FEL, Sec. 25, T13N, RSE, UM (asp's 506246, 6016491) 3M-23 At top of productive interval 9. Permit number / approval number 1078' FNL, 945' FEL, Sec. 27, T13N, R8E, UM 193-187 / At effective depth 10. APl number 50-029-22426 At total depth 11. Field / Pool 1028' FNL, 1172' FEL, Sec. 27, T13N, RSE, UM (asp's 496135, 6016466) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12750 feet Plugs (measured) true vertical 6394 feet Effective depth: measured 12546 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 229 sxAS I 121' 121' SURFACE 5369' 9-5/8" 9oo sx AS H~ & 75O sx C~ass G 5437' 3307' PRODUCTION 12653' 7" 460 sx C~ass G 12721' 6374' Perforation depth: measu red 12423'- 12443', 12450'- 12466', 12474'- 12502' /,~-~'~ ~ ...... true vertical 6160'-6174', 6179'-6191', 6197'-6217 .... r[¢,,,~-,..,, ,;"., Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12325' MD. /'~_~ . . '/ Packers & SSSV (type & measured depth) BAKER SAD-3 PACKER @ 12297' MD. '-/Jfl£'l-~O/'~~/I°'-- CAMCO 'DS' @ 503' MD. ' ........ 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 531 796 1746 - 273 Subsequent to operation 511 670 2030 244 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Carl Mike Mooney263-4574 Signed /~,,~ ,/~~ Title Staff Engineer Date Michael Mooney Prepared by Sharon Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE . Date Comment 3M-23 Event History 09/06/01 MEASURED SBHP AT 12,500' ELM: 3649 PSI. NOTED APPARENT SCALED PERFS FROM 12,480'-12,494'. PERFORATED 12,474'o12,484' (Al ADD PERFS) WITH 2-1/8" ENERJET GUN WITH PJ CHARGES AT 4 SPF, 0 DEG PHASING, 0 DEG ORIENTATION. GUN GAMMA RAY FAILED DURING SECOND P 09/07/01 ADDED A2 PERFORATIONS 12,450'-12,466' ELM USING 2-1/8" ENERJET WITH PJ CHARGES AT 4 SPF, 0 DEG PHASING, 0 DEG ORIENTATION. BECAME STUCKWHILE RIH WITH SECOND GUN; EVENTUALLY RECOVERED ALL TOOLS BUT WILL STAND BACK FOR SLICKLINE DIAGNOSTICS AND REMEDIATIO 09/08/01 DRIFT TBG W/FULL BORE B. LINE BRUSH & 2.74" G. RING & TAG @ 12347' SLM. [TAG] 09/12/01 RE-PERFORATED THE TOP OF A1 SAND @ 12484' - 12494' & PERFORATED THE C4 SAND @ 12423' - 12443' USING 2-1/8" ENERJET W/PW CHGS, 4 SPF, 0 DEG PHASING. OBTAINED POST PERF SBHP AT 12500'= 3743.9 PSlA, AT 12360'= 3705.4 PSlA. [PERF, PRESSURE DATA] Page I of 1 10/2/01 oN. OR BEFO C:t,o~M.DOc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 31' RKF 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1008' FNL, 1622' FEL, Sec 25, T13N, RSE, UM 3M-23 At top of productive interval: 9. Permit number/approval number: 1078' FNL, 945' FEL, Sec 27, T13N, R8E, UM 93-187/399-004 At effective depth: 10. APl number: 1041' FNL, 1093' FEL, Sec 27, T13N, R8E, UM 50-029-22426-00 At total depth: 11. Field/Pool: 1024' FNL, 1173' FEL, Sec 27, T13N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 12750 feet Plugs (measured) None true vertical 6394 feet Effective Deptt measured 12570 feet Junk (measured) Two 1.5" DV's in ratholE true vertical 6266 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 89' 16" 229 Sx AS I 121' 121' Surface 5405' 9-5/8" 900 Sx AS III & 5437' 3307' 750 Sx Class G Production 12690' 7" 460 Sx Class G 12722' 6374' Liner Perforation Depth measured 12484' - 12502' true vedica. 6203' - 6215' RECEIVED Tubing (size, grade, and measured depth) OCT 2 "J, 3.5", 9.3 lb/ft., L-80 @ 12825' Al-as~ Oil & G~s Cons. Packers and SSSV (type and measured depth) Anchorage Pkr: Baker SAB-3 @ 12297'; None, nipple @ 503' 13. Stimulationorcementsqueezesummary 0 ~: ~, i ~ - i ~..i /~ Fracture stimulate "A" sand on 2/15/99. ~'~ Intervals treated (measured) L 12484' - 12502' Treatment description including volumes used and final pressure Pumped 104,369 lbs of 20/40 & 12/18 ceramic proppant into formation, fp was 6400 psi. ,14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 890 283 1242 1242 179 ** Note - well was worked over between these tests** Subsequent to operation 1074 221 753 1387 201 1~. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Dally Report of Well Operations_~X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l~/~'~-~ Title'. Production Engineering Supervisor Date /0/[~"-/~i~ Form 10-404 Re1 i/88 SUBMIT IN DUPLICATE~~ ,~laska, Inc. - KUPARUK RIVER UNIT ELL SERVICE. REPORT K1(3M-23(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-23 DRILLING SUPPORT-EXP WORKOVER 0110991519.3 DATE DAILY WORK UNIT NUMBER 02/15/99 'A' SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 (~ Yes (~ NoI (~ Yes ~ No DS-YOAKUM SMITH FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE 999299 230DS36MO $196,547 $266,963 ~P~.,C Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1323 PSI 0 PSI 1011 PSI 500 PSII 0 PSII 50 PSI DALLY SUMMARY PUMPED 'A' SAND FRAC @ 15 BPM. AVG TREATING PRESSURE 4641 PSI. 137,958# PROP PUMPED, 104,369# PROP IN FORMATION, 33,589# PROP LEFT IN WELLBORE. SCREENED OUT WITH 8.5 PPA SLURRY @ PERFS. [Frac-Refrac] TIME 08:12 08:49 09:00 09:06 09:08 09:11 09:14 09:18' 09:22 09:32 10:07 10:28 10:35 10:43 12:16 12:38 13:13 13:21 14:02 LOG ENTRY SAFETY MEETING. PT TO 890O PSI. PUMP 145 BBL BD STG @ 30 BPM, WHTP=8123 PSI. PUMP 50 BBL BD STG @ 15 BPM, WHTP=6422 PSI. PUMP 50 BBL 1 PPA 20/40 SCOUR STG @ 15 BPM, WHTP=4962 PSI. PUMP 50 BBL CONDITIONING STG @ 15 BPM, WHTP=5434 PSI. PUMP 50 BBL 2 PPA 20/40 SCOUR STG @ 15 BPM, WHTP=5690 PSI. PUMP 50 BBL CONDITIONING STG @ 15 BPM, WHTP=5809 PSI. PUMP 145 BBL FLUSH STG @ 15 BPM, WHTP=5717 PSI. SHUTDOWN, ISIP= 2393 PSI. PUMP 120 BBL DISPLACEMENT STG @ 5 BPM, WHTP=2399 PSI. PUMP 80 BBL DATAFRAC STG @ 15 BPM, WHTP=4298 PSI. PUMP 125 BBL FLUSH STG @ 15 BPM, WHTP=5650 PSI. SHUTDOWN, ISLP=2568 PSI. REPLACE POP-OFF VALVES ON PRV SKID. PUMP 120 BBL PRE-PAD STG @ 5 BPM, WHTP=3658 PSI. PUMP 530 BBL PAD @ 15 BPM, WHTP=4536 PSI. PUMP 100 BBL 2 PPA 20/40 STG @ 15 BPM, WHTP=6212 PSI PUMP 627 BBL 6 PPA RAMP STG @ 15 BPM, WHTP=6222 PSI. SHUTDOWN; SCREEN-OUT. MAX PRESSURE SEEN 6000 PSI. FLUSH SURFACE LINES AND START RIGGING DOWN. 1/2 OF THE TREE SAVER CUPS LEFT IN WELL. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $105.00 APO $10,000.00 $29,000.00 ARCO $400.00 $1,650.00 DOWELL $180,507.65 $209,577.65 HALLIBURTON $0.00 $5,129.00 LITTLE RED $5,640.00 $11,890.00 RADIUS $0.00 $9,612.00 TOTAL FIELD ESTIMATE $196,547.65 $266,963.65 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 1, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-23 (Permit No. 93-187/399-004) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 3M-23. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineer AAI Drilling GLA/skad STATE OF ALASKA ALASt'v-~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl_ OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate__ Plugging_ Perforate_ Pull tubing ._X Alter casing m Repair well __ Other __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development X. Exploratory ~ Stratagrapic _~. Service 4. Location of well at surface: 1008' FNL, 1622' FEL, Sec. 25, T13N, RSE, UM At top of productive interval: '"-- 1'078' FNL, 945' FEL, Sec. 27, T13N, RSE, UM At effective depth: At total depth: 1024' FNL, 1173' FEL, Sec. 27, T13N, RSE, UM 6. Datum of elavation (DF or KB feet): 32' Rig RKB 7. Unit or Property: Kuparuk River Field 8. Well number: 3M-23 9. Permit number/approval number: 93-187/399-004 10. APl number: 50-029-22426 11. Field/Pool: Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 12750' true vertical 6394' Effective Depth: measured 12570' true vertical 6266' Casing Length Size Conductor 89' 16" Surface 5405' 9.625" Production 12690' 7" Liner Plugs (measured) Junk (measured) Cemented 229 sx AS I 900 sx AS III & 750sx Class G 460 sx Class G Measured depth 121' 5437' 12722' True vedicaldepth 121' 3307' 6374' Perforation Depth measured true vertical 12484'-12502' 6203'-6215' Tubing (size, grade, and measured depth) 2.875",6.5~,J-55@11257' Packers and SSSV (type and measured depth) N/A OF,.:IO!NAL '13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) '14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure '15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _~X '16. Status of well classification as: Oil _~X Gas __ Suspended__ Service__ '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,Signed Title: Drilling Team Leader Questions? Call Mark Chambers 265.1319 Prepared by Sharon Aflsup-Drake Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Date: 2/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-23 RIG:NORDIC # 3 WELL ID: 999203 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:06/23/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22426-00 06/23/98 (C1) TD:12722' PB:12635' 06/24/98 (C2) TD:12722' PB:12635' 06/25/98 (C3) TD:12722' PB:12635' 06/26/98 (C4) TD:12722' PB:12635' 06/27/98 (C5 TD: 12722 ' PB: 12635 ' 06/28/98 (C6 TD:12722' PB:12635' 06/29/98 (C7 TD:12722' PB:12635' Displace sea water w/ll.0 MW: 8.4 SW SUPV:MC Accept rig @ 1000 hrs. 6/23/98. Start well kill brine workover fluid. P/U fishing assy MW:ll.0 SW SUPV:DLW Continue to kill well with brine completion fluid. Well dead. N/D tree, N/U BOPE and test to 250/3500 psi. Pull 3.5" tubing. WELL TRYING TO FLOW. CIRC MW:ll.0 SW SUPV:DLW POOH w/3.5" tubing. RIH with fishing assembly. Engage fish @ 12290' Jar on packer and PBR. Release from packer. Kill well, stop fluid los MW:ll.1 SW SUPV:DLW POOH for Baker wash over pipe. Starting to flow. Circulate, well stable. Pump hi-vis pill. No fluid loss, monitor well stable. Milled over Baker PBR MW:ll.1 SW SUPV:DLW RIH to 12265' Burn over top of PBR scoop head wash the length of PBR. Packer moving down hole. Pushed to 12307' C/O to 12620', fluid loss MW:ll.1 SW SUPV:DLW RIH w/spear and tag fish at 12415'. Clean out fill from 12444' to 12610'. Well started taking 30 bph slow rate to 2 bpm 400 psi. Loading 2-7/8" in pipe ho MW:ll.1 SW SUPV:DLW Spot hi-vis pill on bottom. Set storm packer 31' below rotary table and test. N/D BOPE. N/U BOPE and test to 3500 psi. Pull storm packer. Date: 2/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/30/98 (C8) TD:12722' PB:12635' 07/01/98 (C9) TD:12722' PB:12635' 07/02/98 (CiO) TD:12722' PB:12635' 07/03/98 (Cji) TD:i2722~ PB:12635' 0i/i4/99 (Ci2) TD:lii74' PB: 0~ 0i/15/99 (ci3) TD:ll174' PB:12620' 01/16/99 (C14 TD:ll174' PB:12620' 01/17/99 (C15 TD:ll174' PB:12620' 0i/i8/99 (Ci6 TD:lii74' PB:i2620' 0i/i9/99 (Ci7 TD:12150' PB:12620' POH to run completion ass MW:ll.1 SW SUPV:DLW RIH w/3.5" DP to 12499' Pump hi vis pill and spot @ 12499' Splicing cable MW:ll.1 SW SUPV:MCH Circ. tbg and monitor well for losses (hole stable). RIH w/2-7/8" tbg. POH w/WL MW: 0.0 SW SUPV:MCH Continue to run 2-7/8" tubing w/esp completion equipment. N/D BOPE. NU tree and test to 250/5000 psi. Move to new well MW: 0.0 SUPV:MCH Freeze protect well. Set BPV. Move rig off well. Release rig @ 1700 hrs. 7/3/98. SUPV: TAKING ON 11.2 PPG NABR MW: 8.5 SW Move rig to 3M-23. Accepted rig @ 1600 hrs. 1/14/99. Rig up. MIXING 75 BBL 11.5 PPG SP MW: 0.0 SUPV:D.BURLEY Pump kill fluid with seawater. Displace seawater with kill wt. brine. ND Tree, NU BOPE and test to 250/3500. POH, LAYING DOWN ESP ASSE MW: 0.0 SUPV:D.BURLEY Pumped spacer and change well to 11.5 ppg LSND mud. POH w/ESP laying down completion assembly. RIH WITH BIT AND SCRAPER MW: 0.0 SUPV:D.BURLEY POH with Centrilift ESP, laid down tubing. RIH, PU 3-1/2" DRILL PIPE SUPV:D.BURLEY RIH w/BHA %1. RIH w/new drill pipe. MW:ll.5 LSND CLEAN OUT FILL (FORMATION MW: 0.0 SUPV:DONALD L. WESTER RIH w/new 3.5" DP. Gaining mud while running in hole. Circulate and condition mud thick. Clean out fill formation & frac sand from 11356' to 12150' Date: 2/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 01/20/99 (C18) TD:12605' PB:12606' 01/21/99 TD:12605' PB:12606' C19) 01/22/99 TD:12605~ PB:12606' C20) 01/23/99 TD:12605' PB:12606' C21) 01/24/99 (C22) TD:12605' PB:12606' 01/25/99 (C23) TD:12605' PB:12606' RAISE MUD WEIGHT TO 12.2+ MW: 0.0 SUPV:DONALD L. WESTER Continue to clean out 7" casing from 12150' to 12530' Hole took 30 bbls while going through perfs. Monitor fluid loss. Gained 10 bbls well flowing. Shut in well. Continue clean out from 12530' to 12606' closing well in while making connections. Circulate well till clean. Raise mud weight to 12.1 ppg. Shut in monitor well. CIRCULATE BOTTOMS UP, LOA MW: 0.0 SUPV:DONALD L. WESTER Build mud weight to 12.2+ppg. Slow pump rate to control fluid loss. Monitor well dead on drill pipe and annulus. Set storm packer 50' below RT. Test to 3000 psi. N/D BOPE to change out 11" tubing spool to 7-1/16" tubing spool and test. Install 11" 5M x 11" 5M drilling spool. N/U BOPE and test. CONTINUE TO LAY DOWN 3-1/ MW: 0.0 SUPV:DONALD L. WESTER Pull 7" packer. Well dead. Bullhead 10 bbls @ 12020' Continue to lay down pipe, well flowing. Shut in well. Increase mud weight to 12.5+ ppg. Shut down, well dead. AT 0600 304 OF 389 JT'S R MW: 0.0 SUPV:DONALD L. WESTER POOH slowly so as not to swab w/ casing scraper. Run 3.5" tubing completion. WOW WEATHER FROM MIDNIGHT MW: 0.0 SUPV:DONALD L. WESTER Finish running 3.5" tubing. Set Baker 7" pkr @ 12297' N/D BOPE. N/U tree and test to 250/5000 psi. CONTINUE DIE-CHECK WELDS MW: 0.0 SUPV:DONALD L. WESTER WOW for phase 3 weather conditions. Pump Hi-vis pill and seawater. Freeze protect. Truck broke down. Look for cracks in mud tank welds. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, AJaska 99510-0360 Telephone 907 276 1215 January 21, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-23 Water Influx Weight Up jAN 2.5 Alaska Oil & 6as Cons. Anchora,gs Dear Mr. Wondzell: During the Workover of 3M-23, a fluid influx occurred during cleanout operation which required the well to be shut-in and weighted up from 11.5 ppg to 12.2 ppg. Weight up was in .3 ppg increments over a 12-hour period. Following is a short synopsis of events surrounding the weight up: Nordic Rig 3 moved onto location (SITP 360 psi, SICP 450 psi) Displaced well to seawater (SITP 110 psi, SICP 150 psi) Displaced seawater to 11.2 ppg brine (well dead) ND/NU/Test. Displaced 11.2 ppg brine to 11.5 ppg LSND mud. Pulled ESP Completion. Ran in hole w/3-1/2" drill pipe and tagged fill @ 11,356' Perforations from 12,484' to 12502' 1/19/99 02:00 PM - 12:00 AM 1/20/99 12:00 AM - 06:00 AM 06:00 AM - 06:30 AM 06:30 AM - 10:00 AM 10:00 AM - 05:30 PM 05:30 PM - 12:00 AM Cleaned out fill from 11,356'to 12,150 w/11.5 ppg mud. Continued to cleanout fill from 12,150' to 12,530' w/ 11.5 ppg mud. Hole taking fluid @ 15 bph while cleaning out across perfs w/85 spm and 2300 psi. Slowed pump rate to 60 spm and 1200 psi and fluid loss fell to 2 bph. Crew change / service rig. Well began to flow, taking a I0 bbl gain with the pumps off. Shut-in to monitor pressure (SITP 175 psi, SICP 200 psi). Well stable while circulating due to ECD. Installed dart valve and continued to cleanout fi'om 12,530' to 12,606', closing the bag during connections. Circulated well clean and raised mud weight from 11.5 ppg to 11.8 ppg. Shut-in to check pressure (SITP 215 psi, SICP 200 psi). Circulated at 60 spm and raised mud weight from 11.8 ppg to 12.1 ppg. Shut-in to check pressure (SITP 55 psi, SICP 100 psi). ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 12:00 AM - 04:00 AM Circulated at 60 spm and raised mud weight from 12.1 ppg to 12.2 ppg. Shut-in to check pressure (well dead). Continued to circulate and condition mud prior to POOH. Reduced the pump rate to 45 spm and 985 psi to control fluid loss. If you have any questions or require further information, please contact Mark Chambers at (907) 265-1319 or Chip Alvord at (907) 265-6120. Regards, Mark A. Chambers Drilling Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~J~0~ DATE: Chairman January 15, 1999 THRU: FILE NO: Blair Wondzell, ~4~~1~ P. I. Supervisor FROM' Lawence M~Va~ SUBJECT: Petroleum Inspector ac9gaoge. DOC BOP Test Nordic 3 KRU 3M-23 PTD ~ January 15,1996: I traveled to Kuparuk to witness a BOP test on Nordic 3 which was getting ready to pull and ESP completion. The BOP test went well other than a flange leak on the mud cross. The well that they were on hadn't had the usual pre workover prep work done as far as zonal pressure reduction by shutting in offset injectors a week or two in advance and the pump was thought to be sanded in. Inquiring about the problems associated with taking a kick with the powercable strapped to the tubing, I was informed that in a couple of previous incidents where they had a pressure pocket pulling an ESP, the hydril closing in on the pipe and power cable wasn't a positive shut off. They said that if there was serious inflow into the weilbore that the safest solution would be cutting the power cable on the floor and running the stub down below the pipe rams. SUMMARY: Witnessed the BOP test on Nordic 3, 4 hours, 0 failures. Attachments: ac9gaoge.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: x Nordic Rig No. 3 PTD # ARCO Rep.: 3M-23 Rig Rep.: 7" Set @ 12, 722 Location: Sec. X Weekly Other ~'2~./' ~ '7 DATE: 1/16/99 9g--"f6F~ Rig Ph.# 659-7653 Dave Burley Mike Spaulding Umiat 27 T. 13N R. 8 Merldlan Test Pressures 250/3500 MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign X Upper Kelly/IBOP Housekeeping: ok (Gen) Drl. Rig X Lower Kelly/IBOP PTD On Location X Hazard Sec. X Ball Type Standing Order Posted X Inside BOP BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams 1 Choke Ln. Valves 2 HCR Valves Kill Line Valves 2 Check Valve Test Press. P/F 250/3000 P 250/3500 P 250/3500 250/3500 P 250/3500 P 250/3500 P 250/3500 P 250/3500 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X Test Quan. Pressure P/F 1 250/3500 P I 250/3500 P 2 250/3500 P 1 250/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 250/35OO P 36 250/3500 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2350 2,900 I 1,800 minutes 15 sec. minutes 7 sec. x Remote: x Psig. Number of Failures: ,Test Time: 4.0 Hours. NumDer of valves tested 2'/ Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to tile AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) acggaoge.xls .---- STATE OF ALASKA _ r.. ALA,. ,A OIL AND GAS CONSERVATION COM .... 5SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ __ Alter casing Repair well Change appFoved program _ - Operation Shutdown Re-enter suspended well -- -- Plugging Time extension Stimulate Pull tubin~-X Variance_ P~'rforate_ -- Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory Stratigraphic - Service -- 6. Datum elevation (DF or KB) 32' Rig RKB 7. Unit or Property name Kuparuk River Unit feet ';4. Location of well at surface 1008' FNL, 1622' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1078' FNL, 945' FEL, Sec. 27, T13N, R8E, UM At effective depth At total depth 1024' FNL, 1173' FEL, Sec. 27, T13N, R8E, UM 8. Well number 3M-23 9. Permit number 93-187 10. APl number 50-029-22426 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 5396' Intermediate Production 12681' Liner Perforation depth: measured 12484'-12502' true vertical 6203'-6216' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55 @ 11257' Packers and SSSV (type and measured depth) N/A 12750' 6394' 12570' 6266' Size 16" 9.625" 7" feet feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 229 sx AS I 121' 121' 900 sx AS III 5437' 3307' & 750 sx Class G 460sx Class G 12722' 6374' ORIGINAL 13. Attachments Description summary of proposal X Contact Mark A. Chambers at 265-1319 with any questions_. Detailed operation program__ BOP sketch X -- 14. Estimated date for commencing operation January 11, 1999 16. If proposal was verbally approved 15. Status of well classification as: Oil X Gas -- Suspended_ Name of approver Date approved Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ,,///d~,,,~- ~t~.., ~ Title Kuparuk Drilling Team Leader / ' FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so represe~ntative may witness Plug integrity BOP Test ,,'" Location clearance Mechanical In~grity Test_ Subseque~form require 10- UN, -- Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED-BY '~,"~'"'~, ,,,~,,.,,, N. JApproval Commissioner SUBMIT IN TRIPLICATE KRU 3M-23 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w/wireline and set standing valve in D-Nipple @ 11241'. 2. RIH w/wireline and dummy off all GLM's. 3. Pressure test tubing to 2500 psi for 30 min. 4. RIH w/wireline and pull dummy valve from bottom GLM @ 11,179' leaving an open pocket. 5. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water through bottom GLM @ 11,179'. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 11.0 ppg). Circulate well to kill weight brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test B OPE. 4. Screw in landing joint. POOH w/2-7/8" ESP Completion laying down tubing and spooling up cable for disposal. 5. RIH w/bit and scrapper cleaning out fill to PBTD. 6. POOH laying down drill pipe. 7. RIH w/3-1/2" completion assembly as per schematic. 8. Set permanent packer above the A-Sand perforations. Shear out of PBR, space out and land tubing hanger. 11. ND BOPE. NU and test tree. 12. Displace well to seawater and freeze protect with diesel. Lower Limit: 4.5 days Expected Case: 5.0 days Upper Limit: 6.0 days No problems encountered MAC 1/06/98 3M-23 Proposed Completion 7" 26# J-55 @ 12,722' M. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down. L. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to the tubing hanger. K. 3-1/2" Camco 'DS' Nipple with 2.812" No-Go profile set @ +/- 500' MD (4616545). J. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to the 'DS' Nipple with 3-1/2" x 1-1/2" Camco 'MMG' mandrels w/DV's, spaced out as follows. GLM # MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD 6 TBD Note: Each GLM should have 6' L-80 handling pups installed. I. 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/DCR-1 dump kill valve & RKP-2 latch (3000 psi casing to tubing shear). 6' L-80 handling pup installed on mandrel. H. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod tubing G. 3-1/2" Camco YV' Nipple w/2,812" Selective profile (4247635). F. 1 Joint 3-1/2" 9.3# Lo80 EUE 8rd Mod tubing E. Baker S3 hydraulic set permanent packer (5.968" OD x 3.875" ID w/4-1/2" NSCT Box x Pin). 3-1/2" EUE 8rd Box x 4-1/2" NSCT Pin Crossover on top. 4-1/2" NSCT Box x 3-1/2" EUE 8rd Pin Crossover on bottom. D. Pup Joint 3-1/2" x 10' L-80 EUE 8rd Mod tubing. C. 3-1/2" Camco 'D' Nipple w/2.74" No-Go profile (4831355). B. Pup Joint 3-1/2" x 10' L-80 EUE 8rd Mod tubing. A. Baker 3-1/2" shear out sub (3500 psi shear). Tubing tail @ +/- 12,340'. A-Sand Perfs 12,484' - 12,502' PBTD @ 12,620' TD @ 12,722' 7-1/16"- ')00 psi BOP Stack--[ ' Kuparuk River Unit )rdic Rig 3 Kill Line 3 I Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing Stimulate_ Plugging__ Perforate Alter casing __ Repair well __ Other X Install ESP completion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1008' FNL, 1622' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1078' FNL, 945' FEL, Sec. 27, T13N, R8E, UM At effective depth At total depth 1024' FNL, 1173' FEL, Sec. 27, T13N, R8E, UM 12. Present well condition summary 5. Type of Well: Development X Exploratory __ Stratigraphic _ Service 6. Datum elevation (DF or KB) Rig RKB 32' 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-23 9. Permit number/approval number 93-187/398-111 10. APl number 50-029-22426 11. Field/Pool Kuparuk River feet Total Depth: measured 12750' true vertical 6394' feet feet Plugs (measured) Effective depth: measured 12570' true vertical 6266' feet feet Junk (measured) Casing Length Size Structural Conductor 80' 16" Surface 5396' 9-5/8" Intermediate Production 12681' 7" Liner Cemented Measured depth True vertical depth 229 SX AS I 121' 121' 900 sx AS III & 5437' 3307' 750 sx Class G 460 sx Class G 12722' 6374' Perforation depth: measured 12484'-12502' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 6203'-6216' 2.875", 6.5#,J-55 @ 11352' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alaska 0ii & Gas co~'~s. Commission. Anct,uraOe 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~~ ~ , Title Drilling Engineer Form 10%-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE Date: 7/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-23 WELL_ID: 999203 TYPE: AFC: 999203 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:06/23/98 RIG:NORDIC # 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22426-00 06/23/98 (C1) TD:12722' PB:12635' Displace sea water w/ll.0 MW: 8.4 SW SUPV:MC Accept rig @ 1000 hrs. 6/23/98. Start well kill brine workover fluid. 06/24/98 (C2) TD:12722' PB:12635' P/U fishing assy MW:ll.0 SW SUPV:DLW Continue to kill well with brine completion fluid. Well dead. N/D tree, N/U BOPE and test to 250/3500 psi. Pull 3.5" tubing. 06/25/98 (C3) TD:12722' PB:12635' WELL TRYING TO FLOW. CIRC MW:ll.0 SW SUPV:DLW POOH w/3.5" tubing. RIH with fishing assembly. Engage fish @ 12290'. Jar on packer and PBR. Release from packer. 06/26/98 (C4) TD:12722' PB:12635' Kill well, stop fluid los MW:ll.1 SW SUPV:DLW POOH for Baker wash over pipe. Starting to flow. Circulate, well stable. Pump hi-vis pill. No fluid loss, monitor well stable. 06/27/98 (C5) TD:12722' PB:12635' Milled over Baker PBR MW:ll.1 SW SUPV:DLW RIH to 12265' Burn over top of PBR scoop head wash the length of PBR. Packer moving down hole. Pushed to 12307' 06/28/98 (C6) TD:12722' PB:12635' C/O to 12620', fluid loss MW:ll.1 SW SUPV:DLW RIH w/spear and tag fish at 12415' Clean out fill from 12444' to 12610'. Well started taking 30 bph slow rate to 2 bpm 400 psi. 06/29/98 (C7) Loading 2-7/8" in pipe ho TD:12722' SUPV:DLW MW:ll.1 SW PB:12635' 06/30/98 (C8) TD:12722' PB:12635' Spot hi-vis pill on bottom. Set storm packer 31' below rotary table and test. N/D BOPE. N/U BOPE and test to 3500 psi. Pull storm packer. POH to run completion ass MW:ll.1 SW SUPV:DLW RIH w/3.5" DP to 12499' Pump hi vis pill and spot @ 12499' 07/01/98 (C9) TD:12722' PB:12635' Splicing cable MW:ll.1 SW SUPV:MCH Circ. tbg and monitor well for losses (hole stable). RIH w/2-7/8" tbg. 07/02/98 (C10) TD:12722' PB:12635' POH w/WL MW: 0.0 SW SUPV:MCH Continue to run 2-7/8" tubing w/esp completion equipment. N/D BOPE. NU tree and test to 250/5000.psi. 07/03/98 (Cll) TD:12722' PB:12635' Move to new well MW: 0.0 SUPV:MCH Freeze protect well. Set BPV. Move rig off well. Release rig @ 1700 hrs. 7/3/98. End of WellSummary for We11:999203 Prepared by: S. ALLSUP-DRAKE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Alter casing _ Repair well _ Plugging __ Change approved program _ Pull tubing ~ Re-enter suspended well Ti'~me extension _ stimu'Tate _~[~0-~"~-.~ variance_ Perforate_ Other X Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1008' FNL, 1622' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 1078' FNL, 945' FEL, Sec. 27, T13N, RSE, UM At effective depth At total depth 1024' FNL, 1173' FEL, Sec. 27, T13N, R8E, UM M 5. Type of Well: Development . X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 68' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-23 9. Permit number 93-187 10. APl number 50-029-22426 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 12750' (approx) true vertical 6394' feet feet Plugs (measured) None Effective depth: measured 12635' (approx) true vertical 6312' Casing Length Size Structural Conductor 80' 16" Surface 5396' 9.625" Intermediate Production 12681' 7" Liner feet feet Junk (measured) Cemented 229 sx AS I 900 sx AS Ill & 750 sx Class G 460sx Class G Measured depth 121' 5437' 12722' True verticaldepth 121' 3307' 6374" Perforation depth: measured 12484'-12502' true vertical 6203'-6216' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 12339' Packers and SSSV (type and measured depth) Baker FHL Pkr @ 12313' MD, Camco TRDP-4E SSSV @ 1959' 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions_. Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation June 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //'~..._/~__ 'L~ ~/~ Title Kuparuk Drilling Team Leader / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so represe, ptative may witness Plug integrity_ BOP Test ~ Location clearance -- Mechanical Integrity Test_ Subsequent form require 10- ~/-~' Approved by the order of the Commission Original 8igne0 David W. Johnstor, Form 10-403 Rev 06/15/88 Commissioner .'Appr°val No~~_~// Date SUBMIT IN TRIPLICATE KRU 3M-23 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline. Pull valve from bottom GLM leaving an open pocket. Dummy off all other GLM's. 2. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down 3-1/2" tubing and all jewelry. 5. PU DP and RIH with spear. Latch into PBR barrel and pull retrievable packer free. POOH with packer and tail-pipe assembly. 6. PU bit and scraper and RIH cleaning out well to PBTD. Circulate hole clean. 7. Set storm packer and change out tubing head for ESP completion compatibility. Pull storm packer and verify well is dead. POOH laying down DP. . RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 9. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 6.5 days Expected Case: 7.5 days Upper Limit: 9.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 04/17/98 3M-23 Proposed Completion L. 3-1/2" 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. Crossover immediately below hanger to 2-7/8" L-80 EUE 8rd tubing pup. 2nd cable splice at +/-325O' MD adjacent to 8' Round #2 power cable with tech wire in double armor wrap K. 2-7/8" L-80 EUE 8rd Mod tbg to surface with the bottom +/-1500' IPC. Space-out 2-7/8" x 1" Camco 'KBMM' mandrels w/DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 8' pup below and a LaSalle cable protector placed on cplg below pup. This well will have a second cable splice at +/-3250' MD due to the long cable length required. Insert an 8' pup into the tubing string at this depth and make the splice adjacent to the pup. Install LaSalle cable protectors on each coupling above and below the pup to protect the splice. LaSalle ESP Cable Protectors spaced out as procedure Cable splice from flat to round cable adjacent to 10' pup above pump J. 2-7/8" X 1" Camco 'KBMM' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 2-7/8" x 8' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 8' and 15' pups. H. Pup jt, 2-7/8" x 15' L-80 EUE 8rd Mod tubing. G. Internal sensing Baker 'Sentry' gauge with special cplg to replace conventional cplg on full joint of tubing below gauge. Conductor Wire for gauges will be run to surface with-in the 2nd Armor wrap of ESP cable. F. 1 jt of 2-7/8" L-80 EUE 8rd Mod IPC tubing with annulus sensing Baker 'Sentry' gauge clamped to tbg OD. E. 2-7/8" Camco 'D' landing nipple with 2.25" No-Go profile. Standing Valve to be set as nipple is made-up. D. Pup jt, 2-7/8" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. LaSalle Protectolizers at each flange of ESP assembl, C. Centrilift '20 GCNPSH/51GC4100/105GC3500' Series 513 Triple Taper Pump with bolt-on intake and bolt-on discharge head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift 'GST3 4B HL PFS' Tandem Seal Section. A. Centrilift '418 HP KMH 2610/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/-11,350' MD RKB. A Sand Perfs 12,484' - 12,502' 7" 26# J-55 @ 12,722' PBTD @ 12,635' WSI 3/31/98 STATE OF ALASKA AL, ._.(A OIL AND GAS CONSERVATION COMMI~o;ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1008' FNL, 1622' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1078' FNL, 945' FEL, Sec. 27, T13N, R8E, UM At effective depth 1041' FNL, 1093' FEL, Sec. 27, T13N, R8E, UM At total depth 1024' FNL, 1173' FEL, Sec. 27, T13N, R8E, UM 12. Present well condition summary Total Depth: measured 1 2750 feet true vertical 6394 feet 6. Datum elevation (DF or KB) RKB 68 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-23 9. Permit number/approval number 93-187 10~ 0A_~ 2n9u_~46.00 ~'~) 1 1. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth' measured 1 2635 feet true vertical 6 3 1 2 feet Junk (measured) 1.5" DV & 1.5 GLV in rathole Casing Length Size Structural Conductor 8 0' 1 6" Surface 5 39 5' 9 - 5 / 8" Intermediate Production 12684' 7" Liner Perforation depth: measured 12484'-12502' true vertical 6203'-6216' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 12339' Packers and SSSV (type and measured depth) Packer: Cemented Measured depth 229 Sx AS I 1 15' 900 Sx AS III & 5437' 750 Sx Class G 460 Sx Class G 12722' Baker FHL @ 12313'; SSSV: Camco TRDP-4E @ 1959' True vertical depth 115 3307 6374 IG!NA, L 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 9/28/97. Intervals treated (measured) 12484'-12502' Treatment description including volumes used and final pressure Pumped 188 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 7200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1 8 0 9 1080 813 1245 Subsequent to operation 2509 1721 132 1253 Tubing Pressure 198 2O7 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. Form J40?4 f' F~e~ 0~/1578~' - I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT ---- WELL SERVICE REPORT '~' K1 (3M-23(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-23 FRAC, FRAC SUPPORT 0921971552.3 DATE DAILY WORK UNIT NUMBER 09/28/97 PUMP "A" SAND RE FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O No (~ Yes (~ No DS-YOKUM BLACK ESTIMATE KD1588 230DS36ML $146,133 $161,555 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer A~rl-- I"FTnal Outer Ann 1 066 PSI 7200 PSI 335 PSI 500 PSII 75 PSI[ 75 PSI DAILY SUMMARY PUMPED "A" SAND FRAC MID WAY THRU 10 PPA FLAT STAGE & SCREENED OUT HARD (357 BBLS OF 412 BBL STAGE PUMPED). INJECTED 188,000 LBS OF PROP IN FORMATION W/10 PPA OF 12/18 @ PERFS. UNABLE TO FREEZE PROTECT DUE TO SCREEN OUT. TIME 07:00 08:45 09:45 11:00 LOG ENTRY MIRU DS FRAC (YOKUM & CREW), LRS & APC. HOLD SAFETY MEETING (15 ON LOCATION). PT BACKSIDE LINES TO 4000 PSI & RAISE IA PRESSURE TO 3500 PSI. SET TREESAVER & PT HI PRESSURE LINES TO 9500 PSI. PUMP BREAKDOWN W/50~ XL GW F/15-30 BPM. PUMPED 290 BBLS XL GW & 150 BBLS SSW FLUSH. MAX PRES~dRE 80'3~. ~"'~'::- ~-~, .'~,N,D. ENDING PRESSURE 5988 PSI. ISlP=2188 PSI W~ !' ,~:, ..........'" :-;;., ~:. ;¢',' JNITOR FOR CLOSURE. PUMP DATAFRAC W/50# XL GW F/5-15 BPM. PUMPED 200 BBLS XL GW & 120 BBLS SSW FLUSH. MAX PRESSURE 5763 PSI. SD & MONITOR FOR CLOSURE. PUMP FRAC TO 357 BBLS OF 412 BBL 10 PPA FLAT STAGE. SCREENED OUT W/MAX PRESSURE OF 7200 PSI (NO FLUSH VOLUME). TOTAL FRAC VOLUME PUMPED 1540 BBLS. PUMPED TOTAL OF 227,737 LBS PROP THRU JOB. PUMPED 222,184 LBS OF PROP THRU FRAC (17,450 LBS 20/40 & 204,734 LBS 12/18). INJECTED 188,000 LBS OF PROP IN FORMATION W/10 PPA OF 12/18 @ PERFS. LEFT 34,184 LBS OF PROP IN WELLBORE. SAND FROM TOP TO BOTTOM. UNABLE TO FREEZE PROTECT DUE TO SCREEN OUT. 13:00 BEGIN RD. DEPRESSURE IA TO 500 PSI & RD LRS. REMOVED TREESAVER. ALL CUPS RETURNED. 15:00 RD COMPLETE. DS OFF LOCATION. WELL SECURED, SI & AWAITING CTU CLEAN OUT. SERVICE COMPANY - SERVICE DALLY COST I ACCUM TOTAL $0.00 $1,000.00 APC $9,600.00 $9,600.00 ARCO $300.00 $300.00 DOWELL $134,473.00 $134,473.00 HALLI BURTON $0.00 $8,007.00 LI'FI'LE RED $1,760.00 $8,175.00 TOTAL FIELD ESTIMATE $146,133.00 $161,555.00 :- ~, RH i T DATA _~,..~ ind±v' ~ieual Wel~ eeoiog~cai Mater±als Inventory P age · 1 Date' 10/13/95 RUN DATE_RECVD ~e~-i87~ . ~.,~09 93~187 ~JRVEY T 545: ' ~-12750, OH-'CDR/CDN R 0~12750,,~"~ L 7300-12577 i 05 / 09 / 94 03/08/94 1 02/14/9~ 93~187 ~-LWD/DC L 5320~12740 CMPS 05/09/94 93-187 93-187 -~ '~ LWD ~ ~Q~.- DC ~ · / ~/qDR-VER/LWD/DC L 5350-12740 L 11750.-12740 CMPS 05/09,/94 CHPS 05/09/94 93-187 ~IT (C&C) L '7300-12606 1 02/14/'94 Are dry ditch s~mpzes ~q~zzed.~ ~h= well core~ Are wei~i tests required? Well is in compliance Initia1 COMMENT S yes ~_~%i~alysis & description receie~d? yes '~nd received? ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9079 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one si_qned copy of this transmittal. ,, 3H-31 /LIS Tape and Listing: 04--'25-94 94066 - "' LWD CDR/CDN 1 Bit Run 3H-25 LIS Tape and Listing: - 04-27-94 94083 '/'I_WD CDR/CDN 1 Bit Run 3H-23 LIS Tape and Listing: 04-25-94 94075 ¢' LWD CDR/CDN 1 Bit Run 3M-23 LIS Tape and Listing: 04-22-94 94018 ""CDR/CDN-4 Bit Run with QRO Processing 3M-26 ,LIS Tape and Listing: 04-27-94 94023 v"CDR/CDN-4 Bit Run with QRO Processing 2E- 17 LIS Tape and Listing: 05-03-94 94102 "-2 Pass CNTG Cased Hole Edit 3M-25 ..,,,biS Tape and Listing: 05-02-94 94027 _...., "Run with QRO Processina Receipt Acknowledged: ~ _,...,--~_~, ,~-,, -4.%/(~-~ ~/"~_~;fl, JDate: Please acknowledge receipt DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9078 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 //3H-25 G~q..-tf¢ k/ 3H.25 . %3H-25 /3H-31 d~'~'id~ <k 3H-3! ~.3H-31 H-23 H-23 H-23 M-23 M-23 M-23 /3M-26 ~ ~'/~ (/ 3M-26 _ \ 3M-26 H-26 /'3M-24 ~'''tot5 ~'",.3M-243M-24 /3M-25 %3M-25 ~Z¥ ¢-2r~{ -~ 2E-17 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. '/'CDR ¢'CDN ,/CDR Very-Enhanced I~esistivity v/CDR ¢CDN ¢- CDR Very-Enhanced Resistivity v'CDR /CD~l,J "/'CDR Very-Enhanced Resistivity ,,,'CDR ,,"CDN ,,CDR Very-Enhanced Resistivity CE;DR ,,"CDN ,-CDR Very-Enhanced Resistivity ¢'0"NT-G ,/"CDR ,,"CDN ¢CDR Very-Enhanced Resistivity ,,~CCDR DN '.'/CDR Very-Enhanced Resistivity ,.-CNT-G Acknowledged: DISTRIBUTI(~N: Please acknowledge 02-22-25-94 02-22-25-94 02-22-25-94 02-9-12-94 02-9-12-94 02-9-12-94 02-16-18-94 02-16-18-94 02-16-18-94 12-21-28-93 12-21-28-93 12-21-28-93 01-13-16-94 01-13-16-94 01-13-16-94 04-28-94 01-20-25-94 01-2O-25-94 01-2O-25-94 01-2-5-94 01-2-5-94 01-2-5-94 4-22-94 Date: 4650-12414 4650-12414 11800-12300 4950-10734 4950-10734 10100-10700 4080-9358 4O80-9364 8795-9296 5350-12740 532O-1274O 11750-12740 4282-9625 475O-962O 4282-9625 6090-6450 5200-12490 5170-12480 11600-12480 5050-10890 50151-10888 10100-1O82O 87O0-1OOO0 .% '~4~4.,~ 0// ,~- u 199¢ ~'~orag~ co, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~] SUSPENDED E~] ABANDONED [~] SERVICE ~] 2 Name of Operator 7 Permit Number ARCO Alaska, lnc 0 ~ I Gl [~,~A L 93-187 3 Address ~- ~ · [ 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22426 4 Location of well at surface 9 Unit or Lease Name 1008' FNL, 1622' FEL, SEC 25, T 13N, R 8E, uMi '"'~'? ;' ~.' ,~,.: ~ ~:'~':~4:~'-~, ] ~"~"'* T~ ...... 1 KUPARUK RIVER At Top Producing Interval " i~. '.:~i i~ i~ ~k.'~ I 10 Well Number 1078' FNL, 945' FEL, SEC 27, T 13N, R 8E, U...M ! ~-:~: 3M-23 AtTotal Depth '¥',.~'~i~.:;~ ! ~~ 11 Field and Pool 1024' FNL, 1173' FEL, SEC 27, T 13N, R8E, uM ~-,~..i. .... _~i i" ' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 68', 27' PAD GLI ADL 25524 ALK 2655 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 18-Dec-93 27-Dec-93 04/24/94(COMP)I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 12750' MD, 6394' TVD 12635' MD, 6312' TVD YES X[~_J NO [~ 1959' feet MDI 1700' APPROX 22 Type Electric or Other Logs Run LWD LOGS, USlT, CBT, GOT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 SURF 121' 24" 229 SX ASI CMT 9.625 47#/36# L-80/J-55 SURF 5437' 12.25" 900 SX ASlII, 750 SX G CMT 7. 26# L-80 SURF 12722' 8.5" 460 SX CLASS SG CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) DEPTH SET (MD) PACKER SET (MD) 12484'-12502' @ 4 SPF MD 6203'-6216' TVD 3-1/2" 9.3 L-80 12339' 12313' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ¢: FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :)9. 30. , GEOLOGIC MARl<ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 1241 4' 61 53' NA BASE KUPARUK C 12456' 61 84' TOP KUPARUK A 12456' 61 84' BASE KUPARUK A 1 2538' 6242' 31. LIST OF A1-FACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~"~--'~'f~~A Title //~-,. ~z' ~ ~ DATE 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OI'ERATI Ok PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-23 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25524 ALK 2655 50-029-22426 93-187 ACCEPT: 12/17/93 12:00 SPUD: 12/18/93 07:00 RELEASE: 04/24/94 05:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 12/16/93 ( 1) PARKER 245 TD: 0'( 12/17/93 (2) PARKER 245 TD: 0'( o) o) 12/18/93 (3) PARKER 245 TD: 121' ( 121) 12/19/93 ( 4) PARKER 245 TD: 2870' (2749) 12/20/93 (5) PARKER 245 TD: 5455' (2585) MOVING RIG F/2E-3M PAD MW: 0.0 VIS: 0 PREPARE RIG F/MOVE TO 3M PAD. MOVE RIG F/2E TO Y SPINE ROAD NEAR KCS PAD, HEADING TOWARDS CPF-3. NO MAJOR PROBLEMS ENCOUNTERED. MOVING F/2E PAD-3M PAD MW: 0.0 VIS: 0 MOVE RIG F/Y IN SPINE ROAD NEAR KCS PAD TO 3M PAD. @ 0600 HRS UTILITY MODULE IS ON 3M PAD & DRILL MODULE IS APPROX 1/4 MILE FROM LOC. NO MAJOR PROBLEMS ENCOUNTERED. PU 12.25" BHA 16"@ 121' MW: 8.6 VIS: 42 CONT MOVING DRILL MOD TO 3M PAD. ON LOC @ 0630 HRS. REMOVE SNOW F/BEHIND WELLS & UNDER FLOW LINES IN ORDER TO ACCOM DIVERTER LINES. LAY DIVERTER LINES. LINE UP UTILITY & DRILL MOD W/WELL, MOVE OVER WELL. SPOT & LEVEL BOTH MODULES. NU DIVERTER SYSTEM, MIX MUD, LOAD PIPE SHED W/HWDP & DC'S & FUNCTION TEST DIVERTER. PREPARE RIG FLOOR TO DRILL. PU & STD BACK 10 STDS HWDP, 2 STDS 8" DC'S, & 10 STDS DP. PU 12.25" BHA. ORIENT MWD TOOLS. RIG ACCEPTED @ 1200 HRS 12/17/93. DRILL & MWD SURV 16"@ 121' MW: 9.8 VIS: 63 FIN PU BHA & ORIENT MWD TOOLS. DRILL 12.25" HOLE F/121'-560' ATTEMPT SURV. MWD TOOL FAILURE. POOH. LD MWD. LOAD & PROGRAM SAME. MU MWD TOOL, & TIH. MWD SURV & GYRO SURV @ 560'. DRILL & GYRO SURV AS NEEDED TO 2870' CIRC & COND F/CSG 16"@ 121' MW:10.0 VIS: 41 DRILL 12.25" HOLE F/2870'-3430' CIRC & COND MUD. SHORT TRIP. TIH. DRILL F/3430'-5455' CIRC HOLE CLEAN F/TOH. MAKE SHORT TRIP. NUMEROUS TIGHT SPOTS. WORK THROUGH W/NO PROBLEMS. CIRC HOLE CLEAN & COND MUD F/CSG. MUD GAS CUT TO 9.0 ON BU. RECEIVED MAY -9 1994 ~,i~ska Ull & Gas Cons. Commission Anchorage WELL: 3M-23 API: 50-029-22426 PERMIT: 93-187 PAGE: 2 12/21/93 ( 6) PARKER 245 TD: 5455'( o) 12/22/93 ( 7) PARKER 245 TD: 7659' (2204) 12/23/93 ( 8) PARKER 245 TD: 7851' ( 192) 12/24/93 ( 9) PARKER 245 TD: 9197' (1346) 12/25/93 (10) PARKER 245 TD:ll700' (2503) 12/26/93 (11) PARKER 245 TD:12100' ( 400) TEST BOPE 9-5/8"@ 5437' MW:10.0 VIS: 0 12/27/93 (12) PARKER 245 TD:12615' ( 515) CIRC & COND MUD. POOH TO RUN CSG. WORK THROUGH TIGHT SPOTS. PULL WEAR RING. RU CSG EQUIP. RUN 369 J-55 & 80 JTS 53.5% L-80 9-5/8" CSG. SET SHOE @ 5437'. CIRC & COND MUD F/CMT JOB. PMP TOTAL OF 570 BBLS @ 8 BPM. CMT W/900 SX ASIII @ 12 PPG FOLLOWED BY 750 SX CLASS G @ 15.8 PPG. CIP @ 2230 HRS. FLOATS HELD, RD CMT HEAD & LANDING JT. LD CSG ELEVATORS, PU 5" DP ELEVATORS. ND DIVERTER SYSTEM & CHANGE OUT ADAPTER SPOOL F/NEW WELLHEAD ELEVATION. INSTALL 16" PACK-OFF & SPEED HEAD. NU 13-3/8" BOP STACK. PU TEST TOOLS & TEST BOPE. POOH F/BIT 9-5/8"@ 5437' MW: 8.8 VIS: 32 FIN TEST BOPE TO 300/3000 PSI. SET WEAR BUSHING. LD TEST JT. BLOW DN LINES. SLIP & CUT 123' OF DRILL LINE. MU BHA. ORIENT MWD. LOAD SOURCE IN CDN COLLAR. TEST MWD. SERV TOP DRIVE. TIH. WASH & REAM. TEST 9-5/8" CSG TO 2000 PSI. DRILL OUT CMT, FE, & 10' NEW FORM TO 5465'. CBU. PERFORM FIT. PRESS FORMATION TO 675 PSI W/8.6 PPG MUD F/12.5 EMW. DRILL & MWD SURV F/5465'-7659'. PENETRATION RATE UNACCEPTABLE. POOH TO CHECK BIT & TURBINE. DRILLING 9-5/8"@ 5437' MW: 8.9 VIS: 32 FIN POOH. RETRIEVE RA SOURCE. DOWN LOAD MWD. STAND BACK SAME. CHANGE BIT. LOAD RA SOURCE. RIH. SERV TOP DRIVE. TIH. BREAK CIRC. REAM. DRILL F/7659'-7664' BIT WILL NOT DRILL. POH. REMOVE SOURCE. LD TURBINE. MU MS82F ON 1 DEC NAVIDRILL(SLOW SPEED). RIH. TEST MWD @ 5518' REAM F/7624'-7664' DRILL & MWD SURV F/7664'-7851' DRILLING 9-5/8"@ 5437' MW: 9.1 VIS: 33 DRILL & MWD SURV F/7851'-8475' SERV TOP DRIVE. DRILL & MWD F/8475'-8697' CBU. PMP SLUG. POOH. REMOVE SOURCE. DOWN LOAD MWD. LD MOTOR. MU TURBINE. ORIENT MWD. RIH. TEST MWD @ 5560' REAM 60' TO BTM. DRILL & MWD SURV F/8697'-9197'. DRILLING 9-5/8"@ 5437' MW: 9.1 VIS: 33 DRILL & MWD SURV F/9197'-10434' SERV TOP DRIVE. DRILL & MWD SURV F/10434'-11700' MIX LCM 9-5/8"@ 5437' MW: 9.1 VIS: 38 DRILL & MWD SURV F/11700'-12100' CBU. MONITOR WELL. PMP SLUG. POOH. REMOVE SOURCE. LD ANADRILL TOOLS & TURBINE. MU ROTARY BHA. RIH TO 5369' SLIP & CUT DRILL LINE. RIH TO 12000' REAM F/12000'-12100' FOR LWD LOGS. CIRC & COND MUD. MIX LCM TO 30 PPB. DRILLING 9-5/8"@ 5437' MW:ll.2 VIS: 52 CIRC & COND MUD. ADD 30 PPB LCM & INCREASE MUD WT TO 11.3 PPG. ROTARY DRILL F/12100'-12615'. RECEIVED MAY -J9 1994 U~L & Gas Cons. Commlssi~: Anchora~]e WELL: 3M-23 API: 50-029-22426 PERMIT: 93-187 PAGE: 3 12/28/93 (13) PARKER 245 TD:12750' ( 135) 12/29/93 (14) PARKER 245 TD:12750' ( o) 12/30/93 (15) PARKER 245 TD:12750' ( o) 02/10/94 (16) DOWELL TD:12750 POH TO RUN 7" CSG 7"@12721' MW:ll.2 VIS: 46 DRILL & LWD LOG F/12615'-12750' CIRC & COND MUD. MONITOR WELL. WELL FLOWING SLIGHTLY. CIRC & INCREASE MUD WT F/ll.3 TO 11.6 PPG. HAD OIL & GAS CUT RETURNS @ BU. MONITOR WELL AFTER WT UP. OK. MADE SHORT TRIP TO SHOE. NO PROBLEMS. CIRC & COND. HAD GAS CUT RETURNS. OK. DROP SURV. PMP SLUG. POOH SLOWLY TO RUN 7" CSG. MAKE ROUGH CUT ON 7" CSG 7"@12721' MW: 0.0 VIS: 0 FIN POOH. LD LWD TOOLS. PULL WEAR RING. RU CSG TOOLS, & HOLD SAFETY MEETING. RUN 7" 26# L-80 CSG. TOTAL OF 296 JTS & MARKER JT RUN. SHOE @ 12722' CBU @ CSG SHOE & BROKE CIRC EVERY 2000' GOING IN HOLE. CIRC & COND MUD. RECIP PIPE W/FULL RETURNS @ 7 BPM W/850 PSI. BATCH MIX TAIL CMT WHILE CIRC. RU DOWELL. FLUSH LINES W/20 BBLS WATER. TEST LINES TO 4000 PSI. PMP 20 BBLS ARCO PREFLUSH, DROP BTM PLUG, PMP 50 BBLS OF 12.5 PPG ARCO SPACER. MIX & PMP 250 SX CLASS G @ 12.5 PPG. DROP SECOND BTM PLUG & PMP 200 SX CLASS G @ 15.8 PPG. DROP TOP PLUG & DISPLACE W/485 BBLS 11.6 BRINE. BMP PLUG TO 3500 PSI. FLOATS HELD. CIP @ 0330 HRS. DISPLACE ANN W/140 BBLS MUD @ 6 BPM W/900 PSI. MONITOR WELL UNTIL STAB. PU BOPE STACK. SET SLIPS W/280, 000#. MAKE ROUGH CUT ON 7" CSG. FINAL REPORT 7"@12721' MW: 0.0 VIS: 0 LD LANDING JT & RD CSG EQUIP. ND 13-5/8" BOPE. CHANGE OUT RISER. MAKE FINAL CUT ON 7" CSG & INSTALL PRIMARY PACKOFF. INSTALL TBG HEAD-SECONDARY SEAL FAILED. REPLACED & RETESTED TO 3000 PSI-OK. FREEZE PROTECT W/150 BBLS WATER & 70 BBLS DIESEL. LD DP F/DERRICK & CLEAN PITS. RELEASE RIG @ 1800 HRS 12/29/93. 7"@12721' PERFORM ARCTIC PACK ON 3M-23. 04/23/94 (17) NORDIC 1 TD:12750 PB:12635 RU SCHLUMBERGER 7"@12721' MW: 0.0 MOVED RIG F/3M-24 TO 3M-23. ACCEPTED RIG @ 0400 HRS 04/23/94. ND DRY HOLE TREE. NU BOP. TEST BLIND RAMS, BROKEN FLANGES & 7" CSG TO 3500 PSI F/30 MIN. RU SCHLUMBERGER. RECEIVED MAY --9 i994 Alaska Oil & Gas Cons. Commission Anchorage WELL' 3M-23 API: 50-029-22426 PERMIT: 93-187 · PAGE: 4 04/24/94 (18) NORDIC 1 TD:12750 PB:12635 FINAL REPORT 7"@12721' MW' 0.0 RIH W/SCHLUMBERGER & PERF GUN, 4 SPF, 180 DEG PHASING. PERF F/12484'-12502' POOH & RD SWS. RU FLOW RISER & NIPPLE. LOAD PIPE SHED W/3-1/2" TBG, DRIFT & STRAP SAME. RIH W/3-1/2" 9.59 L-80 MOD 8RD TBG-TOTAL OF 383 JTS. TBG TAIL @ 12,339', BAKER FHL RETRIEV PKR @ 12313', SSSV @ 1959' TEST ANN & TBG. TEST TREE TO 250/5000 PSI. FREEZE PROTECT WELL. RELEASE RIG @ 0530 HRS 04/24/94. SIGNATURE: DATE: / Y RECEIVED MAY --9 1994 Alaska Oil & Gas Cons. Corrlrnis.~ion Anchoraoe SUB. SURFACE DIRECTIONAl. $URVEY F'~'] UIDANCE ~]ONTINUOUS F~'JooL Company Well Name- Field/Location Date,,. I / ~ I 0 ( ik\~sY,~ rO'~' & GaS Cons. comm~ss~o~ ARCO ALASKA, INC. . ~-23 (1008'FNL, 1622'FEL,SEC 25, T13N, R8E, KUPARUK, NORTH SLOPE, ..A~S~ Job Reference No. 94045 Logged BY: FORMICA Date 30-JAN- 1994 Computed By; SINES · SCHLlJMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 30-JAN-1994 ENGINEER: FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 89 DEG 28 MIN WEST COMPUTATION DATE' 17-FEB-94 PAGE I ArCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 99 94 199 94 299 94 399 94 499 94 599 92 699 51 798 11 895 18 -68 O0 31 94 131 94 231 94 331 94 431 94 531 92 631 51 73O 827 0 0 N 0 0 E 0 10 S 2O 34 E 0 13 S 39 38 E 0 14 S 35 18 E 0 13 S 35 5 E 0 7 S 29 8 E 2 55 N 88 24 W 7 13 N 84 9 W 11 12 0 N 84 1W 18 15 2 N 85 49 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 05 -0 23 -0 47 -0 72 -0 89 0 45 9 17 25 47 49 34 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 0 02 0 04 0 05 0 O4 0 O0 N 0 O1 S 0 28 S 0 59 S 0 95 S 1 20 S 1 35 S 0.71 S 1.12 N 3.12 N 000 E 0 05 E 024 E 048 E 0 73 E 0 90 E 044W 9 17 W 25 48 W 49 37 W 1 1 1 9 25 49 0 O0 N 0 0 E 0 05 S 79 50 E 0 37 S 39 42 E 0 76 S 38 49 E 19 S 37 30 E 50 S 36 47 E 42 S 18 2 W 19 S 85 34 W 51 N 87 29 W 47 N 86 23 W 1000.00 1100.00 1088 1200.00 1184 1300.00 1280 1400.00 1375 1500.00 1468 1600.00 1559 1700.00 1649 1800.00 1739 1900.00 1825 991 75 42 1020 92 1116 68 1212 31 1307 10 1400 23 1491 95 1581 64 1671 60 1757 923 75 14 59 42 14 43 92 15 51 68 17 39 31 20 13 10 23 23 23 24 48 95 24 58 64 ,28 4 60 33 20 N 85 12 W N 84 26 W N 83 31 W N 84 54 W N 88 45 W S 89 22W S 88 58 W S 88 26 W S 88 20 W S 89 5W 75 19 100 66 126 73 155 29 187 54 224 77 265 92 307 99 352 18 403 17 0 02 0 O1 0 O1 0 O1 0 02 0 03 0 03 0 02 0 O1 0 02 5 12 N 7 10 13 15 15 14 13 12 11 45 N 100 22 N 126 32 N 155 10 N 187 13 N 224 48 N 266 56 N 308 21N 352 75 24 W 75.42 N 86 7 W 74 W 101.01 N 85 46 W 83 W 127.24 N 85 23 W 42 W 155.99 N 85 6 W 69 W 188.29 N 85 24 W 92 W 225.42 N 86 9 W 06 W 266.46 N 86 53 W 13 W 308.43 N 87 29 W 31 W 352.52 N 88 1 W 11N 403.29 W 403.44 N 88 25 W 2000 O0 1906 53 1838 53 38 22 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1982 18 1914 O0 2052 36 1984 O0 2117 69 2049 O0 2177 44 2109 O0 2230 84 2162 O0 2276 57 2208 O0 2315.78 2247 O0 2350.65 2282 O0 2385.61 2317 18 43 12 36 47 15 69 51 5 44 55 4 84 60 9 57 65 2 78 68 59 65 69 30 61 69 30 S 89 40 W 461.84 N 89 52 W 527.18 S 89 33 W 598.38 S 88 8 W 674.05 S 87 9 W 754 16 S 86 26 W 838 57 S 86 22 W 927 33 S 87 20 W 1019 20 S 87 30 W 1112 87 S 87 38 W 1206 50 0 O2 0 O3 0 O4 0 O4 0 04 0 04 0 O5 0 O5 O. 03 0.01 10.44 N 461.95 W 462 07 N 88 42 W 10.42 N 527.30 W 527 40 N 88 52 W 10.37 N 598.50 W 598 59 N 89 0 W 8 70 N 674.16 W 674 22 N 89 16 W 5 28 N 754.25 W 754 26 N 89 36 W 0 47 N 838.61W 838 61 N 89 58 W 5 22 S 927.32 W 927 34 S 89 41 W 10 34 S 1019.15 W 1019.20 S 89 25 W 14 53 S 1112.78 W 1112.87 S 89 15 W 18 50 S 1206.38 W 1206.53 S 89 7 W 3000.00 2420 82 2352 82 69 22 3100.00 2456 3200.00 2492 3300.00 2528 3400.00 2564 3500.00 2601 3600.00 2638 3700.00 2675 3800.00 2712 3900.00 2752 29 2388 04 2424 09 2460 80 2496 81 2533 82 2570 45 2607 97 2644 04 2684 29 69 5 04 69 3 09 68 40 80 68 19 81 68 10 82 68 33 45 68 24 97 67 12 04 67 4 S 88 3 W 1300.06 S 88 8 W 1393 54 S 88 8 W 1486 S 88 16 W 1580 S 88 9 W 1673 S 88 6 W 1766 S 89 38 W 1858 N 89 59 W 1951 N 89 48 W 2044 N 89 39 W 2136 90 15 15 02 91 96 65 69 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O1 0 O1 0 O1 0 O1 22.01S 1299 92 W 1300.10 S 89 2 W 25 06 S 1393 28 31 34 37 38 39 38 38 11S 1486 03 S 1579 02 S 1672 04 S 1765 80 S 1858 06 S 1951 78 S 2044 38 S 2136 36 W 1393.59 S 88 58 W 70 W 1486.97 S 88 55 W 93 W 1580.24 S 88 52 W 90 W 1673.25 S 88 50 W 76 W 1766.14 S 88 48 W 64 W 1859.04 S 88 48 W 68 W 1952.07 S 88 51 W 37 W 2044,74 S 88 55 W 43 W 2136.77 S 88 58 W COMPUTATION DATE' 17-FEB-94 PAGE 2 arco ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FI ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2788 37 2720 37 70 9 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2822 O0 2857 O0 2892 O0 2928 O0 2965 O0 3001 O0 3039 O0 3077 O0 3112 35 2754 12 2789 50 2824 64 2860 04 2897 81 2933 32 2971 18 3009 74 3044 35 69 55 12 69 27 50 69 3 64 68 42 04 68 33 81 68 16 32 67 40 18 68 28 74 69 16 N 89 35 W 2229 82 N 89 6 W 2323 N 88 44 W 2417 N 88 43 W 2511 N 88 33 W 2604 N 88 17 W 2697 N 87 49 W 2790 N 87 35 W 2882 N 87 45 W 2975 N 87 53 W 3068 85 57 06 25 33 24 82 25 62 0 02 0 02 0 O1 0 O1 0 O0 0 O0 0 O0 0 O1 0 O1 0 O1 37 73 S 2229 57 W 2229 89 S 89 2 W 36 34 32 30 27 24 21 17 13 68 S 2323 82 S 2417 78 S 2510 55 S 2604 97 S 2697 84 S 2790 06 S 2882 12 S 2975 78 S 3068 61W 2323 36 W 2417 87 W 2511 08 W 2604 18 W 2697 12 W 2790 75 W 2882 22 W 2975 62 W 3068 90 S 89 6 W 61 S 89 10 W O8 S 89 15 W 26 S 89 20 W 33 S 89 24 W 24 S 89 29 W 82 S 89 35 W 26 S 89 40 W 65 S 89 45 W 5000 O0 3148 47 3080 47 68 49 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3185 O0 3221 O0 3258 O0 3293 O0 3329 O0 3364 O0 3400 O0 3436 O0 3471 06 3117 96 3153 33 3190 38 3225 25 3261 91 3296 91 3332 56 3368 72 3403 06 68 25 96 68 13 33 69 21 38 69 24 25 69 5 91 68 59 91 68 56 56 69 17 72 69 17 N 87 28 W 3161 90 N 86'55 W 3254 N 86 30 W 3347 N 86 54 W 3440 N 86 46 W 3533 N 86 54 W 3627 N 87 6 W 3720 N 87 32 W 3813 N 87 51W 3906 N 88 8 W 4000 8O 53 46 92 08 32 47 78 31 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O0 0 01 9 99 S 3161 94 W 3161 96 S 89 49 W 5 0 5 10 15 20 25 28 32 34 S 3254 09 N 3347 66 N 3440 74 N 3534 85 N 3627 86 N 3720 21N 3813 95 N 3907 15 N 4000 89 W 3254 67 W 3347 66 W 3440 17 W 3534 38 W 3627 67 W 3720 87 W 3813 22 W 3907 78 W 4000 90 S 89 54 W 67 N 90 0 W 66 N 89 54 W 19 N 89 50 W 42 N 89 45 W 73 N 89 41W 95 N 89 37 W 32 N 89 35 W 91 N 89 32 W 6000 O0 3507 25 3439 25 68 57 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3543 O0 3579 O0 3615 O0 3653 O0 3690 O0 3727 O0 3763 O0 3800 O0 3836 01 3475 10 3511 93 3547 35 3585 75 3622 12 3659 59 3695 32 3732 97 3768 01 68 56 10 68 38 93 68 13 35 67 57 75 68 19 12 68 52 59 '68 32 32 68 22 97 68 43 N 88 39 W 4093.71 N 89 7 W 4187 06 N 89 50 W 4280 S 89 34 W 4373 S 88 52 W 4466 S 88 34 W 4558 S 88 23 W 4651 S 88 8 W 4744 S 88 0 W 4837 S 88 47 W 4930 31 27 O1 74 88 97 95 97 0 O1 0 O1 0 O0 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O0 34 90 N 4094 21 W 4094 36 N 89 31 W 36 37 37 36 33 31 28 25 22 74 N 4187 66 N 4280 42 N 4373 17 N 4466 98 N 4559 55 N 4652 70 N 4745 53 N 4838 75 N 4931 58 W 4187 84 W 4281 81W 4373 53 W 4466 25 W 4559 37 W 4652 44 W 4745 39 W 4838 39 W 4931 74 N 89 30 W O0 N 89 30 W 97 N 89 31W 68 N 89 32 W 38 N 89 34 W 47 N 89 37 W 52 N 89 39 W 46 N 89 42 W 45 N 89 44 W 7000 O0 3873 19 3805 19 68 38 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 39O9 O0 3946 O0 3983 O0 4019 O0 4O56 O0 4093 O0 4130 O0 4166 O0 4203 88 3841 88 68 19 81 3878 81 68 31 43 3915 43 68 34 89 3951 89 68 33 57 3988 57 68 26 56 4025.56 67 56 47 4062.47 68 57 53 4098.53 68 29 41 4135.41 68 17 S 88 42 W 5024 17 S 88 20 W 5117 S 87 50 W 5210 S 87 37 W 5303 S 87 19 W 5396 S 87 8 W 5489 S 87 10 W 5581 S 89 1W 5674 S 88 56 W 5768 S 89 10 W 5861 19 09 10 16 12 94 85 12 O7 0 O0 0 O1 0 O1 0 O0 0 O0 0 O0 0 O0 0 O1 0 O1 0 O1 20.83 N 5024 58 W 5024 63 N 89 46 W 18.40 N 5117 58 W 5117 15.31 N 5210 45 W 5210 11 60 N 5303 43 W 5303 7 44 N 5396 46 W 5396 2 97,N 5489 38 W 5489 1 78 S 5582 17 W 5582 4 79 S 5675 05 W 5675 6 42 S 5768.31 W 5768 61 N 89 48 W 48 N 89 50 W 45 N 89 52 W 46 N 89 55 W 38 N 89 58 W 17 S 89 59 W 05 S 89 57 W 31 S 89 56 W 8.02 S 5861.24 W 5861.25 S 89 55 W ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 17-FEB-94 PAGE 3 DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 8000 O0 4240 70 4172 70 67 55 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4278 O0 4314 O0 4350 O0 4386 O0 4422 O0 4459 O0 4496 O0 4533 O0 4569 43 4210 88 4246 99 4282 92 4318 95 4354 85 4391 69 4428 04 4465 90 4501 43 67 57 88 68 49 99 69 2 92 68 57 95 68 38 85 68 8 69 68 49 04 68 31 90 68 30 VERTICAL DOGLEG RECTANGU~R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG MIN S 89 42 W 5953.85 S 89 56 W 6046.46 N 89 32 W 6139.57 N 88 42 W 6232.80 N 87 59 W 6326.04 N 87 26 W 6419.21 N 86 49 W 6511.99 N 87 45 W 6604.79 N 87 59 W 6697.85 N 88 33 W 6790.73 0.01 0.00 9 0.01 9 0.01 7 0.01 4 0.01 0 0.01 3 0.01 8 0.01 11 0. O1 14 8 97 S 5954 03 W 5954 03 S 89 55 W 20 S 6046 O0 S 6139 51S 6232 73 S 6326 89 S 6419 71N 6512 40 N 6605 83 N 6698 80 N 6791 63 W 6046 75 W 6139 99 W 6233 27 W 6326 48 W 6419 30 W 6512 15 W 6605 24 W 6698 16 W 6791 64 S 89 55 W 76 S 89 55 W O0 S 89 56 W 27 S 89 57 W 48 S 90 0 W 31 N 89 58 W 15 N 89 56 W 25 N 89 54 W 17 N 89 53 W 9000 O0 4606 88 4538 88 68 3 9100 92O0 9300 9400 9500 9600 9700 9800 9900 O0 4644 O0 4681 O0 4719 O0 4756 O0 4794 O0 4831 O0 4869 O0 4908 O0 4946 14 4576 14 68 1! 57 4613 57 67 57 09 4651 09 67 56 50 4688 50 67 52 07 4726 07 67 54 88 4763.88 67 43 99 4801.99 67 31 31 4840.31 67 36 47 4878.47 67 22 10000 O0 4985 12 4917 12 66 57 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 5023 O0 5059 O0 5096 O0 5135 O0 5174 O0 5213 O0 5254 O0 5294 O0 5333 47 4955 80 4991 88 5028 10 5067 12 5106 84 5145 80 5186 58 5226 03 5265 47 68 22 80 68 44 88 67 46 10 67 20 12 66 45 84 66 19 80 65 30 58 67 25 03 67 25 11000.00 5368.95 5300.95 70 18 11100.00 5402.85 5334.85 69 52 11200 O0 5439 46 5371.46 67 47 11300 O0 5478 61 5410 61 65 35 11400 O0 5522 02 5454 02 62 35 11500 O0 5569 74 5501 74 60 31 11600 O0 5620 45 5552 45 58 17 11700 O0 5675 10 5607 10 54 50 11800 O0 5734 23 5666 23 52 25 11900 O0 5796 84 5728 84 50 18 S 89 23 W 6883 62 S 88 54 W 6976 S 88 12 W 7069 S 87 44 W 7161 S 87 4 W 7254 S 86 22 W 7347 S 85 41W 7439 S 85 0 W 7531 S 85 42 W 7623 S 85 31W 7715 42 14 8O 48 O4 45 66 75 99 S 84 40 W 7807 96 S 85 56 W 7900 S 86 9 W 7993 S 87 29 W 8085 S 86 42 W 8178 S 89 31W 8270 S 88 44 W 8361 S 88 27 W 8453 N 88 56 W 8544 N 88 56 W 8637 O1 03 79 12 15 92 13 86 14 N 87 33 W 8730 36 N 88 14 W 8824 33 N 88 37 W 8917 32 N 89 24 W 9009 29 S 89 18 W 9099 36 S 88 15 W 9187 23 S 87 22 W 9273 37 S 87 6 w 9357 O2 S 87 I w 9437 58 S 85 53 W 9515 43 0 O1 0 O1 0 O0 0 O0 0 O1 0 O1 0 O1 0 O1 0 01 0 01 o Ol 0 O1 0 02 0 02 0 O1 0 02 0.02 0. O0 0.01 0.02 0 02 0 O2 0 02 0 02 0 02 0 03 0 03 0 03 0 03 0 03 15 20 N 6884 06 W 6884 07 N 89 52 W 13 11 8 3 1 7 15 23 30 79 N 6976 37 N 7069 06 N 7162 92 N 7254 40 S 7347 86 S 7439 44 S 7531 32 S 7623 19 S 7716 85 W 6976 54 W 7069 18 W 7162 83 W 7254 35 W 7347 69 W 7439 84 W 7531 87 W 7623 05 W 7716 86 N 89 53 W 55 N 89 54 W 18 N 89 56 W 83 N 89 58 W 35 S 89 59 W 70 S 89 56 W 86 S 89 53 W 90 S 89 49 W 10 S 89 47 W 38 02 S 7807 94 W 7808 03 S 89 43 W 46 52 57 62 65 66 68 69 67 22 S 7899 19 S 7992 53 S 8085 26 S 8177 44 S 8269 82 S 8361 98 S 8452 03 S 8544 47 S 8636 92 W 7900 89 W 7993 61W 8085 89 W 8178 90 W 8270 66 W 8361 85 W 8453 59 W 8544 89 W 8637 06 S 89 40 W 06 S 89 38 W 81 S 89 36 W 13 S 89 34 W 15 S 89 33 W 92 S 89 33 W 14 S 89 32 W 86 S 89 32 W 15 S 89 33 W 64 39 S 8730 14 W 8730 38 S 89 35 W 60 81S 8824 58 20 S 8917 56 54 S 9009 56 46 S 9099 58 15 S 9187 61 37 S 9273 65.68 S 9356 69.88 S 9437 74.61 S 9515 15 W 8824 16 W 8917 16 W 9009 23 W 9099 08 W 9187 20 W 9273 81W 9357 34 W 9437 15 W 9515 36 S 89 36 W 35 S 89 38 W 33 S 89 38 W 40 S 89 39 W 27 S 89 38 W 4O S 89 37 W O4 S 89 36 W 59 S 89 35 W 44 S 89 33 W COMPUTATION DATE: 17-FEB-94 PAGE 4 ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE Of SURVEY: 30-JaN-i994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12000 O0 5862 14 5794 14 46 42 12100 12200 12300 12400 12500 12600 12700 12750 O0 5931 O0 6001 O0 6071 O0 6143 O0 6215 O0 6287 O0 6358 O0 6394 62 5863 41 5933 96 6003 29 6075 14 6147 04 6219 55 6290 30 6326 62 45 48 41 45 29 96 44 52 29 44 10 14 44 3 04 44 21 55 44 21 30 44 21 S 86 8 W 9590 97 S 85 45 W 9662 N 89 27 W 9734 N 83 51W 9805 N 78 7 W 9874 N 77 10 W 9941 N 76 8 W 10009 N 76 8 W 10077 N 76 8 W 1O11O 78 34 01 O6 77 35 O6 91 0 03 0 O3 0 02 0 O2 0 03 0 03 0 O0 0 O0 0 O0 80 38 S 9590 64 W 9590 98 S 89 31W 85 87 83 72 57 41 24 16 17 S 9662 82 S 9733 67 S 9804 53 S 9873 25 S 9941 43 S10009 67 S10077 29 S10111 41W 9662 94 W 9734 66 W 9805 81W 9874 67 W 9941 40 WlO009 26 W10077 20 W10111 78 S 89 30 W 34 S 89 29 W O2 S 89 31W O8 S 89 35 W 83 S 89 40 W 48 S 89 46W 29 S 89 52 W 21 S 89 54 W COMPUTATION DATE: 17-FEB-94 PAGE 5 ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE Of SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 ET ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/1OO FEET FEET FEET DEG MIN 0 O0 0.00 -68.00 0 0 N 0 0 E 0 O0 N 1000 2000 3000 4000 5000 6000 7000 8000 9000 O0 991.75 923.75 14 59 N 85 12 W 75 O0 1906.53 1838.53 38 22 S 89 40 W 461 O0 2420.82 2352.82 69 22 S 88 3 W 1300 O0 2788.37 2720.37 70 9 N 89 35 W 2229 O0 3148.47 3080.47 68 49 N 87 28 W 3161 O0 3507.25 3439.25 68 57 N 88 39 W 4093 O0 3873.19 3805.19 68 38 S 88 42 W 5024 O0 4240.70 4172.70 67 55 S 89 42 W 5953 O0 4606.88 4538.88 68 3 S 89 23 W 6883 0 O0 19 84 O6 82 90 71 17 85 62 0 O0 0 02 0 02 0 O0 0 02 0 O1 0 O1 0 O0 0 O1 0 O1 5 10 22 37 9 34 2O 8 15 12 N 75 44 N 461 O1S 1299 73 S 2229 99 S 3161 90 N 4094 83 N 5024 97 S 5954 0 O0 E 0.00 N 0 0 E 24 W 75.42 N 86 7 W 95 W 462 07 N 88 42 W 92 W 1300 10 S 89 2 W 57 W 2229 89 S 89 2 W 94 W 3161 96 S 89 49 W 21 W 4094 36 N 89 31 W 58 W 5024 63 N 89 46 W 03 W 5954 03 S 89 55 W 20 N 6884.06 W 6884 07 N 89 52 W 10000.00 4985.12 4917.12 66 57 S 84 40 W 7807.96 11000.00 5368.95 5300.95 70 18 N 87 33 W 8730.36 12000.00 5862.14 5794.14 46 42 S 86 8 W 9590.97 12750.00 6394.30 6326.30 44 21 N 76 8 W 10110.91 0.01 0.02 O. 03 O. O0 38.02 S 7807.94 W 7808.03 S 89 43 W 64.39 S 8730.14 W 8730.38 S 89 35 W 80.38 S 9590.64 W 9590,98 S 89 31 W 16.29 S10111.20 W10111.21 S 89 54 W ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 17-FEB-94 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 68 O0 168 O0 268 O0 368 O0 468 O0 568 O0 668 O0 768 O0 868 O0 PAGE 6 DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR CDORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 O0 68 06 168 06 268 06 368 06 468 06 568 06 668 28 769 29 871 88 0 0 N 0 0 E 0 2 S 16 54 E 0 11 S 37 10 E 0 14 S 36 39 E 0 15 S 34 47 E 0 8 S 36 13 E 1 3 S 82 13 W 5 56 N 85 56 W O0 10 34 N 83 26 W O0 14 41 N 85 41 W FEET FEET FEET FEET DEG MIN 975.41 1078.89 1068 1182.42 1168 1286.69 1268 1392.22 1368 1499.89 1468 1609.66 1568 1719.93 1668 1832.40 1768 1951.57 1868 0 O0 -0 03 -0 17 -0 40 -0 64 -0 85 -0 62 5 51 19 50 42 14 -68 O0 0 O0 100 O0 200 O0 3OO O0 400 O0 500 O0 600 O0 7OO 8OO 968 O0 900.00 15 0 O0 1000.00 14 41 O0 1100.00 15 33 O0 1200 O0 17 23 O0 1300 O0 19 58 O0 1400 O0 23 23 O0 1500 O0 24 50 O0 1600 O0 25 14 O0 1700 O0 , 29 42 O0 1800 O0 36 5 2080.67 1968 O0 1900 O0 42 25 2223 30 2068 O0 2000 O0 48 11 2383 69 2168 O0 2100 O0 54 36 2580 02 2268 O0 2200 O0 64 7 N 85 26 W 68.86 N 84 25 W 95.33 N 83 39 W 121.97 N 84 20 W 151.29 N 88 25 W 184.86 S 89 22 W 224.72 S 88 55 W 269.97 S 88 17 W 316.45 S 88 38 W 367.83 S 89 20 W 432.51 N 89 51W 514.04 S 89 8 W 615.64 S 87 15 W 740.87 S 86 17 W 909.31 DEG/ZO0 0 O0 0 03 0 01 0 O0 0 O0 0 O0 0 01 0 04 0 O5 0 04 0 03 0 01 0 O0 0 01 0 02 0 03 0 03 0 02 0 O2 0 O3 0.03 0.04 0.04 0.05 0 O0 N 0 03 N 0 20 S 0 49 S 0 84 S 1 14 S 1 33 S 1 04 S 0 46 N 2 59 N 0 O0 E 0 03 E 0 17 E 0 40 E 0 65 E 0 86 E 0 63 E 5 50 W 19 50 W 42 17 W 1 1 1 5 19 42 0 O0 N 0 0 E 0 05 N 44 42 E 0 26 S 4O 12 E 0 63 S 39 23 E 06 S 37 48 E 43 S 36 59 E 47 S 25 22 E 60 S 79 17 W 51 N 88 39 W 25 N 86 29 W 4 59 N 6 9 12 15 15 14 13 11 10 68.90 W 69 06 N 86 11W 93 N 95.40 W 95 65 N 85 51 W 68 N 122.07 W 122 45 N 85 28 W 96 N 151.41 W 151 97 N 85 7 W 04 N 185 O1W 185 62 N 85 21W 13 N 224 87 W 225 38 N 86 9 W 40 N 270 11W 270.50 N 86 57 W 32 N 316 58 W 316.86 N 87 35 W 79 N 367 95 W 368.14 N 88 10 W 70 N 432 62 W 432.76 N 88 35 W 10.39 N 514 16 W 514 27 N 88 51 W 10.15 N 615 76 W 615 85 N 89 3 W 5.92 N 740 96 W 740 98 N 89 33 W 4.06 S 909 32 W 909 32 S 89 45 W 2849 3132 3408 3679 3941 4230 57 2368 78 2468 66 2568 72 2668 88 2768 88 2868 O0 2300 O0 69 34 O0 2400 O0 69 4 O0 2500.00 68 19 O0 2600.00 -68 31 O0 2700.00 68 23 O0 2800.00 69 17 4508 08 2968.00 2900.00 68 31 4775 32 3068.00 3000.00 67 51 5053 54 3168.00 3100.00 68 31 5327 56 3268.00 3200 O0 69 34 5608 60 3368.00 3300 O0 68 59 5889 49 3468.00 3400 O0 69 16 6169.43 3568.00 3500 O0 68 47 6439.03 3668.00 3600 O0 67 58 6712.04 3768.00 3700 O0 68 30 6985.75 3868.00 3800 O0 68 44 S 87 35 W 1159.27 S 88 9 W 1424.15 $ 88 10 W 1681.19 S 89 56 W 1933.10 N 89 38 W 2175.40 N 88 48 W 2446.46 N 88 15 W 2704.85 n 87 33 W 2952.37 N 87 7 W 3211.67 N 86 58 W 3466.21 N 87 9 W 3728.33 N 88 6 W 3990.49 N 89 34 W 4251.82 S 88 40 W 4502.18 S 88 6 W 4756.17 S 88 47 W 5010.91 0.02 0.00 0. O0 0.01 0.01 0.01 0 O0 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 16.52 S 1159 26.06 S 1423 34.28 S 1680 39.06 S 1932 38.13 S 2175 34.19 S 2446 17 W 1159 97 W 1424 95 W 1681 82 W 1933 14 W 2175 25 W 2446 29 S 89 11W 20 S 88 57 W 29 S 88 50 W 22 S 88 51W 47 S 89 0 W 49 S 89 12 W 27.75 S 2704.70 W 2704.85 S 89 25 W 18.06 S 2952.32 W 2952.38 S 89 39 W 7.61 S 3211.74 W 3211.74 S 89 52 W 7.05 N 3466.42 W 3466.43 N 89 53 W 21.27 N 3728.68 W 3728 75 N 89 40 W 31.82 N 3990.95 W 3991 08 N 89 33 W 37.51 N 4252.35 W 4252 52 N 89 30 W 35.39 N 4502.70 W 4502 84 N 89 33 W 28.33 N 4756.64 W 4756 72 N 89 40 W 21.13 N 5011.32 W 5011 36 N 89 46 W COMPUTATION DATE: 17-FEB-94 PAGE 7 ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 ET ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 7257 81 3968 O0 3900.00 68 29 7531 7804 8072 8347 8621 8894 9163 9430 9694 09 4068 02 4168 35 4268 40 4368 90 4468 83 4568 86 4668 63 4768 81 4868 O0 4000.00 68 26 O0 4100.00 68 27 O0 4200.00 67 44 O0 4300.00 68 56 O0 4400.00 68 8 O0 4500.00 68 30 O0 4600.00 67 56 O0 4700.00 67 59 O0 4800.00 67 32 S 87 43 W 5263 86 S 87 1W 5518 S 88 55 W 5771 S 89 56 W 6O20 N 88 17 W 6277 N 86 43 W 6532 N 88 27 W 6785 S 88 22 W 70~5 S 86 53 W 7282 S 85 1W 7526 O1 86 86 O1 27 92 65 84 88 0 O0 0 O0 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 13 21 N 5264 20 W 5264 22 N 89 51 W 1 6 9 6 4 14 12 2 15 49 N 5518 48 S 5772 17 S 6021 33 S 6277 86 N 6532 69 N 6786 38 N 7036 42 N 7283 03 S 7527 26 W 5518 04 W 5772 03 W 6021 22 W 6277 59 W 6532 35 W 6786 07 W 7036 18 W 7283 06 W 7527 26 N 89 59 W 05 S 89 56 W O4 S 89 55 W 22 S 89 57 W 60 N 89 57 W 36 N 89 53 W 08 N 89 54 W 18 N 89 59 W 08 S 89 53 W 9956 O0 4968 O0 4900 O0 67 17 10222 10484 10732 10997 11273 11496 11687 11854 12008 53 5068 48 5168 16 5268 19 5368 81 5468 47 5568 56 5668 49 5768 51 5868 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 68 36 O0 66 47 O0 66 3 O0 70 17 O0 66 36 O0 60 33 O0 55 25 O0 51 3 O0 46 26 S 85 7 W 7767 55 S 86' 9 W 8013 S 89 25 W 8255 S 89 21W 8482 N 87 32 W 8727 N 89 10 W 8985 S 88 17 W 9184 S 87 0 W 9346 S 86 29 W 9480 S 86 16 W 9597 99 88 46 72 36 15 81 29 14 0 O1 0 02 0 02 0 O1 0 02 0 O2 0 03 0 02 0 03 0 03 34 41 S 7767 56 W 7767 64 S 89 45 W 53 65 69 64 56 58 65 72 60 S 8013 30 S 8255 55 S 8482 50 S 8727 84 S 8985 05 S 9184 15 S 9346 27 S 9480 80.78 S 9596 83 W 8014 63 W 8255 18 W 8482 50 W 8727 22 W 8985 01W 9184 61W 9346 03 W 9480 80 W 9597 O1 S 89 37 W 89 S 89 33 W 46 S 89 32 W 74 S 89 35 W 40 S 89 38 W lg S 89 38 W 83 S 89 36 W 31 S 89 34 W 14 S 89 31W 12152.20 5968.00 5900 O0 45 47 12294.41 6068.00 6000 O0 44 53 12434.42 6168.00 6100 O0 44 4 12573.46 6268.00 6200 O0 44 10 12713.21 6368.00 6300 O0 44 21 12750.00 6394.30 6326 30 44 21 S 87 50 W 9700 17 N 84 11W 9801 11 N 77 13 W 9897 43 N 76 35 W 9991 39 N 76 8 W 10086 O1 N 76 8 W 10110 91 0 02 0 02 0 03 0 01 0 O0 0 O0 87 29 S 9699 78 W 9700 17 S 89 29 W 84 13 S 9800 75 W 9801 11 S 89 30 W 67 40 S 9897 23 W 9897 46 S 89 37 W 45 85 S 9991 39 W 9991 50 S 89 44 W 22 45 S10086 23 W10086 26 S 89 52 W 16 29 S10111 20 W10111 21 S 89 54 W COMPUTATION DATE: 17-FEB-94 PAGE 8 ARCO ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUP^RUK A GCT LAST READING PBTD 7" CASING DATE OF SURVEY: 30-JAN-ig94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1008' FNL ~ 1622' FEL, SEC2S T13N R8E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5437 O0 12414 O0 12456 O0 12456 O0 12538 O0 12590 O0 12635 O0 12722 O0 12750 O0 3306 58 6153 34 6183 51 6183 51 6242 49 6279 84 6312 07 6374 28 6394 30 3238 58 6085 34 6115 51 6115 51 6174 49 6211 84 6244 07 6306 28 6326 30 12 67 N 7O 64 64 51 43 35 2O 16 50 S 9883 07 S 9911 07 S 9911 42 S 9967 12 S 100O2 56 S 10033 98 S 10092 29 S 10111 3568 69 W 36 W 85 W 85 W 40 W 61W 15 W 19 W 20 W arco ALASKA, INC. 3M-23 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK a COMPUTATION DATE: 17-FEB-94 PAGE 9 DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 1008' FNL & 1622' FEE, SEC2$ T13N R8E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 12414.00 6153.34 6085.34 70.50 S 9883.36 W 12456.00 6183.51 6115.51 64.07 S 9911.85 W 12456.00 6183.51 6115.51 64.07 S 9911.85 W 12538.00 6242.49 6174.49 51.42 S 9967.40 W 12750.00 6394.30 6326.30 16.29 S 10111.20 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12750.00 6394.30 6326.30 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10111.21 S 89 54 W COMPANY ARCO ALASKA, INC. FIELD 3M-23 WELL KUPARUK RIVER COUNTRY USA RUN I DATE LOGGED 30-JAN-1994 REFERENCE 94045 All nterpretations are opinions based on nferences from electrical or other measuremen~ and we cannot, and do not guarantee the accuracy or correctness of any nterpretat ons, and we shall not, except in the case of gross or wilfull negligence on our par'[, be liable or responsible for any oss, costs, damages or expenses incurred or sustained by anyone resulti.ng from any interpretation made by a ly of our officers, agenfs or employees. These interpretations are also subject to our General Terms and Conditions as set out in our current price Schedu e. WELL' 3H-23 (].008' FNL, ].~22" FEL ~ SEC' 25, ~-~,N, RSE, UH) "-'qORIZONTAL PROJECTION NOFITH 8000 6000 40O0 2000 -2000 -4000 -6000 -8000 REF 94045 SCALE = I / 2000 ~N/FT -[2000 -[0000 -8000 -6000 -4000 -2000 0 2000 4000 EAST WELL- 3H-23 (iO08'FNL; 1622~FEL; SEC-25, T'--Z-IN R8E, UN) VERTICAL PROJECTION EAgT -4000 -2000 ' 0 0 2000 4000 6000 8000 10000 12000 "~'FF'i .... F'F'7'"~ F"F"F"i ..... F":"'F": T'F"F'~ ...... F'7'"F"~ F'F"F"~'"F"F';'"~-F"F'r"F"~ ..... '"i'i'"i'i ..... i'"i"!'"i ...... i"i"'i'"i ..... i'"i'"i'"i .... i'"!'-i'"i ...... i'"!"i"i ...... i"'i'"i'"i'"i'"!'"i'"i'"i'"i'";'"i"i ..... !'"i'!"! ..... i"i-'hi ..... i"!'"!''~ ..... i"i'! ...... !"i"!'~'~~ ;:.i;i :i.-.i.: .hL-i.i...;.:-~.i .~.--!~.-i.:.~c6hl..i.i-.:-.i. ii..;}..i..;, i.i.ii .:i.;i:..!:.;..~ ;.:;: :::: ::- ' · ~-~---~-'-~----~--~---~-i ...... ~---~---~-'-~ ...... i--~---?-? 'i'71 ...... i-"i'"i'"i'-~?h?--! ...... i"-i-'-i---i ...... ?"!'"~'-?!"i'--~ ..... ~¥~]'!eat' 'S£e!,[ON!': l iii!.iii! ============================= i:~'i'::"i::i':i::i:':'"i:::i':i::!:~~~; i::i::i":' :i:i'i:i .... i'?i :'ii! : :.:: ::::: ::: ::::: :..: ::: ::::::: ::::::::::::::::::::: ..:i::: ::::::::::: :::::::::::::::::::::: :::::::::' ::: :::::::: ::: ::. ": ::::i:::::: :~ :.~ ~ :::::: ::::::i.:,:::: :::'.:: .::..::.: .i -: : :-:: :.:: :::: :::: :::: :::: .~%.~:: ' ":"'::'": ..... :-':":-': .... :"-:":'-':---!'":--:-":---:--~'~o .... ::": .... ..... :-":--':"':-':':': ..... :':"::'":'":": ::'" :':'ii .... ::..:::%~oo~~ .... : ::i:' ::: ::' :'" ::: :::::': :::::: :::::-::::::::: :::::::::::::::::: :::::::,::::::::::: ::::::::::::::::::::::,:::,:::,:::,:::: :::::::::::: ::: :::'::i: :: ':':,:':::: !::,:: ':':: :i:': ':: ::.::::i::: :',:: ,':. ::_._::.: ' : : - : : : : : : :~ :800Q : : : : : : : : : ' : · : : : : : : : : : : : : I : . : tt ~ , · ............... ":'":'":": ..... :'::'": ...... :'":"':'": ...... :":'"~i'":'":'":"': ...... :'":'":'": ..... :"':'":'": .... :'":'":": ....... :'";"':'": ..... :'":":'": .... :'":":'":"~"':":'": ...... ! ...... ! ........ ::':: .... ::::::::::::::::::::: ...... ::-E~l .... :.-::..:--:.-:i-.: .... i.:..~--:..,i...:,.:: .... :..:.:: ~.:...:: :...:..j.~..::.:: ..i.:~: ..... :::: ..::.:...:.:::...i...:..L..~..:. L..~..i.[,..~.:..:...:..:..:.:...:...i::.~ .:..;..:: :.::: .:::: :.:: .: ....... i!ii~ii.i--i-i-.i---i---i ..... i---!i--!---i--i--i--!--'--i--i--i--i i~i--!--!-:-.i--iii~i-i!---i-!i-i.-i i-i~!i!.i.~ii ~ .... ' : i !-!'i !--i !-i-! i '! i--q-! !.-.:.i-: .... !--!-i'! -!-!'!-!'--'!'i-i'! ! :-} } : : !' : : :'! : : : . : : : i:i; iiii :ili iiil :~pqo iiii iii: i!i!, !ii~--. i;i : :' , ...... :.:..:.::..:..:.:...L.L..i.:.: .... L..L..:..: .... :...:...:...: .... :...:...:..: :..L.;...: .... :..:.:...:...i...::.:...: .:..:...:.: .... ::...: ;:~ ............... :::. ::.: ::::,:::: ::;: :::: :::: ::::;:.. : .:.. ::: ;::;.:..;.;-.;:.::..;..; .... :.:...;.~ .:...:...;...:-..;...:..:.; ..... :.:-4..:. :;.:..;..,;.;.;.; .:.::: .::.;.. ;.,: .... ::-' ::::;::::i:;:: :::: :;:: ;::: i !.! ! .: i..!-.i.i !.i--.i-..! ...... !.!...!.!...!...!..-!.! !..!.!.! .... i-:--.:...:- :.: .... : .i.:..i i : : i i .... i.: .... .................. :: : .................................... ........................... . .... ':'"!'":':"':":'":'": ..... :"7':'": ...... :'"F':"F':]"?"F':'": ..... :'":'":"': ...... :'":'":":'",":":"!': .... :':":'";'['"!":'";": ':":';": .... :':i .... i':_''___~_' .................... ! : i : !'! :--! .... i--i---i---! ...... i--i'--i-'i ..... i-'-!---:-:- -'!---i---i'-: :--!--:---i- -: :'i':', !'-:":--: .... i-': : : ': : : : . : I .... : : i i i : i i i i i i ~t4000 : : : i ! :': i ": i : : .... ' ' ' ' ' ' -- ............... ::: :::: :::: -:: :::: ::.: :::: ::.: :.:: .:: .:. -.-~-.t,::::: ::~: :::: :;:: :::: ,~,~ ~:,, :.,~: :::: :::: ::::-~,, ,, . · i!:i i'ii! '??i"i .... ¢"i?i 'i-i!'iI i"i"i"i .... !'i~i'i !i'ii 'iii"i i-i!i :'!!! :::~ : ....... : : ~ : : : : : : : : : ~ _: : : : : : : : : : : : : : : -: ,i' 1 ....... ' PROJECTION ON VERTICAL PLANE EAST - WES"r SCALED IN VEFfT'ICAL DEPTHS HO¢IIZ SCALE = I / 2000 IN/FY ARCO Alaska, Inc. Date: March 04, 1994 Transmittal #: 9020 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. . Please acknowledge receipt and q¥-~.-~'~ 3M-23 ~"~- ~t'~ 3M-26 c~,~-c~ 3M-25A ~ %.-~1% 3M-24 Receipt Acknowledged: Directional SurveyS'- i~"t¢~c 01-30-94 Directional Survey c~- ~-s 01-30-94 Directional Survey ~- ~ t-z. 01-29-94 Directional Survey b--iz.~t~ 01-30-94 ~./~_~/_,,'~.. ~C~ Date: DISTRIBUTION: D&M State of Alaska (2 copies) 94045 94043 94042 94044 ARCO Alaska, Inc. Date: January 11, 1994 Transmittal #: 9000 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3M-25A 3M-26 3M-23 3M-24 3M-26 3M-25A 3M-23 3M-24 ¢'Ultrasonic Imager-USIT Cement & Corrosion '/Ultrasonic imager-USIT Cement & Corrosion ~/Ultrasonic Imager-USIT Cement & Corrosion ~'Ultrason Cement v- Cement ,/Cement /Cement ,,/Cement ic Imager-USIT & Corrosion Bond Log (CBT),," Bond Log (CBT) Bond Log (CBT) Bond Log (CBT) 01-29-94 6, t 01-29-94 01-29-94 ~,t 01-29-94 Ik~ Please acknowledge 7886-9-450 ~-8785 5 7300-12606 5" 1 0600-1 2356 12-20-93 ~,~ 7800-9421 5" 12-20-93 ¢,t 6900-8756 _5 12-20-93 ¢,~ 7300-12577 12-20-93 ~,~ 10600-12327 Receipt Acknowledge: Drilling State of Alaska(+sepia) NSK Date: u ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10,1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If ! may be of any assistance, please call me at 279-1433. Yours very truly, Robert P Crandall Sr Petr Geologist encl jo/A: R PC:\drlstats .11o¢194 OPERATOR ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INC ARCO ALASKA ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 93-01~3-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189~0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193~0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIY UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2E-05 2E-06 2E-07 2~- 08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 ALASKA OIL AND GAS CONSERVATION CO~I~IISSION December 3, 1993 WALTER J. HICKEL, GOVERNOR 300! PORCUPINE DRIVE ANCHORAGE, ALASKA gg501-31g2 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit ~M-23 ARCO Alaska, Inc. Permit No: 93-187 Sur. Loc. iO08'FNL, 1622'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. ll02'FNL, 1250'FEL, Sec.27, T13N, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 given by contacting the Commission petroleum field inspector on the North Slope. pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS OONSERVATION GOMMIS$iON PERMIT TO DRILL 20 AAO 25.005 la. Type of Work Drill X Redrill E] 'lb Ty~e'of Well E~(ploratory Fi ' Stratigral~hJc [~ Develol~m~r~t Oil X' Test Re-Entry E] Deepen F'] Service r-] Development Gas ~'] Single Zone X Multiple Zone r"] 2'_ Name of Operator ' ' ' 5. Datur~ Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Add~'ess 6. Property De;si'gnation Kuparuk River Oil Pool P. O. Box 100360,. Anchorage, AK 99510-0360 ADL 25524, ALK 2655 '4. Location of well at surface 7. Unit or property Name 11. Type'Bond (see 2o AAC 25.025) 1008' FNL, 1622' FEL, SEC. 25, T13N, RSE, UM .Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) '8. Well number Number 1100' FNL, 1030' FEL, Sec. 27, T13N, RSE, UM 3M-23 #U-630610 At total depth 9. Approximate spud date Amount 1102' FNL,. 1250' .FEL, Sec. 27, T13N, RSE, UM 12/1 0/93 $200,000 12.' Distance to nearest 13. Distance to nearest Well 14. Number of acres in propertY/ 15. Proposed depth (MD a~c~ TVD) property line 3M-12 12745' MD 1030' @ TD feet 8.4' @ 520' MD feet 1 920 6328' TVD feet 16. To be completed for deviated wells' 17. Anticipated pre~,sure (~ee 20 AAC 25.035(e)(2))' Kickoff depth 600 feet Maximum hole angle 68.34° Maximum surface 1946 psig At total depth (TVD) 3346 psig 'i'8.' Casing program S.ettin~ Depth size Specifications ' Top Bottom Quantit)/ of cement Hole ca~ing W'eight ~rade Coupling Length MD TVD MD TVD '' (i.'nclu.de s!age data.) 24" 16" 62,5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF , , , , 12.25" 9.625" 47.0# L-80 BTC 2837' 41' 41' 2878' 2375' 570 Sx Arcticset III & ,, , HF-ERW 720 Sx Class G --~-9-¢6'¢5~ 3',--6 0# J-55 BTC ~473' 2878' 2375' 5~51' 3288' HF~ERVV 8.5" 7" 26.0# L-80 BTCMOE 12704 '41' 41' 12745' 6328; 150 SxClassG HF-ERW Top 500' above' Ku~)aru. k 19. To be completed ~or Redri[I, Re-er~try, 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 de pt_h-, ,,T~= '~'eCical depth Structural R E( EIWU Gonductor Surface Intermediate Production Liner [~, ~.) V 75 (.') true vertical ~.. Anchorage 20. Attachments Fil~n~l fee ')~ Property plat E] BOP'Sketch X Di~eder Sketcl~ X Drilling program X" Drilling fluid program X Time vs deplh plot E] Refraction analysis r-J Seabed report E] 20 AAC 25.050 requirements X 2'1. I hereby certify that the fore'going is 'true and correct to the' best o! my knowledge Signed b/~'~ ~.~ Title Area Drillincj En~lineer Date ft/g~/~._~ ' ' COmmissiOn Use ~)~ly " =, , Number number Ap'~roval te I APl 50-O~ ~.._ ~.,~ ~.~ ~ J / :¢ ~.%f? _ .~:..~..~ [SeeotherCOVerrequirementsletler ,~r Conditions of abproval Samples required E] Yes ~ No Mud Icg required E] Yes ~ No Hydrogen sulfide Bi Yes ~ No Directional survey required ~ Yes E~ No measures Required working pressure for BOPE E] 2M ~, 3M r-] 5M E] 10M r-1 15M Other: Original Signed By by order of Cppro.v~ed._b.y_ David W, J0hrlstorl ,C,ommissioner the commission Date Form 10-401 Rev. 7-24-89 Submit triplicate , , o 10. 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M -23 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5351')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12745') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 3M-23 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 5O-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1946 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-23 is 3M-12. As designed, the minimum distance between the two wells would be 8.4' @ 520' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. E(.TEIVEb 0 ALASKA, YiC. Structure : Pad 3M __ _ Well: 2..3 ;Creoted by ' jones For: $ BRADI~¥ Field : Kuparuk River Unit Location : North Slope, Alaska. Date plotted - 22-Nov-95 L . . Plot_ Reference is £5 Version #3. Coordinates ore in feet reference Blot #23. True VerUcal DepU~s are reference wellhead_ Baker Hughes INTEQ < - - W e s t sco, 2 o.oo 10500 lOOO0 9500 9000 8500 8000 7500 7000 6500 6000 5500 50('*0 4500 4_0005500 .30002500 2000 1500 I000 5C,0 0 500 ' ] I I I I ' I I I I ' I I f I I I I I I I i I J I I I I I I I I ' I I I J ' I I J ' I I t10~'i500 ' o ..-.. = o . -o ~ 0 / I 200 V TD LOCATION: 1102' FNL, 1250' FEL SEC. 27, T13N, RBE ITARGET LOCAl)ON: I 1100' FNL, 1050' FEL SEC. 27, T13N, RBE TARGET. T¥D= 6108 TMD= 12433 DEP=9969 SOUTH 95 WEST 9969 S 89.47 DEG W 9969' (TO TARGET) ESTIMATED SURFACE LOCATION: 1008' FHL, 1627 FEL SEC. 25, T13N, RSE oO 500 ] c.! o a RKB ELEVATIO'J 68' "J KOP TVD o00 TMD 600 DEP 0 c~ 500 ~ I 600 - - lOOO ~ 12.00 BUILD 3 DEG / 100' 18.00 ~, 24.00 x 30 O0 "%., .3'600 B/ PERfv~FROST 'P,/D=1643 TMD=1705 DEP=310 ~ ~2.00 OC TVD=2375 TMD=2878 DEP= 1205 .....~W SAK SNDS i'VD=2768 TMD=5943 DEP=2194 / W SAK SNDS TVD=3088 TMD=4810 DEP=5000 -~%~. 9 5/8" CSG PT TVD=3288 TMD=5351 DEP=3504 ~ '"'---...~-10 WD=3393 TMD=5656 DEP=5768 Cons. Ooirlmissjon AJ-mhora.q~ MAXIMUM ANGLE 68.34 DEG ~....~ TVD=4788 TMD=9415 DEP=7280 BEGIN ANGLE DROP TVD=5471 TMD=11266 DEP=9001"~'""'"'---.~ 55001 ~ 66 b/~TJ_O 0 "-~.. 5800 DROP 2 BEG / I00' '-%. 54,00 50.00 ~0~ot TARGET ANGLE T^R6~ - T/ ZONE C (EOD) ~D=6108 TMD=I2433 DEP=9969 '"', 46.00 45 DEG ~/ ZONa A WO=6I B/ KUP SNDS ~D=61~7 TMD=12545 DEP=10048 65~ TD / 7" CSG PT ~'D=63a8 TMD=Ig745 DEP=I0189 / I I I I I I I I I I I i i I I I I I I f I I i [ I I I I I I I J I I I I i I I I I~~'~ 5~ 0 500 l~O i5~ 2000 2500 3~ 35~3'4C~0 45~3 50~ 5500 6~ 6500 7~0 7500 80~ Scole1 : 250.00 VeMicdlSection on 269.47ozimuth withreference 0.00 N,0,00E from slot~23 < Wesf Scale 1' 50.00 500 450 400 350 300 250 200 150 1 O0 50 0 50 PROPOSE~ ~ ~ ~ 0 A R C 0 ALAS KA, I n c. ~~ ~oo k oo ~lru~:~'url : Pod 314 Well : 25 ~ ~ field : Kuporuk River Unit Location : North Slope, AJcmka 150 lO0 5O 0 5O _ lO0 _ 150 Z 0 0 I I V West 1050 1000 950 900 850 800 750 700 Scale 1 ' 50.00 650 600 550 500 PROPOSED 150 _ lO0 _ 50 0 _ 100 _ 150 A I I Z I I V < West s~o,~ ~. ~o.oo 1600 1550 1500 1450 1400 1550 1500 1250 1200 1150 11 O0 1050 lO0 .o 50 b 150 ~200 2250 2200 2150 21 O0 2050 West 2000 1950 19OO Scale 1 · 50.00 1850 1800 1750 -_ 7600 PROPOSED lO0 oo _ 50 .o 0 _ I I '~oov _ 150 _ 200 Casing Design / Cement Calculations 23-Nov-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice · Production Csg Choice: Production Casing Frac. Pressure 3M-23 5,636 ft 3,288 ft 12,745 ft 6,328 ft 3,943 ft 12,433 ft 6,108 ft 3225 psi ?:.;.1~i?:?:~iii~i~ii?:i::ii?:?:?:i::?:?:?:?:~!?:?:i~i::iii~?:?:ii~i?:?:?:?:?:i::?:i~!::i::i::~?:?:?:?:~::?:?:~::?:?:~i~i~ ~ **For See Casing Page Choices 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,288 ft {(13.5'0.052)-0.11}*TVDshoe =[ 1,946 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,225.0 ppg 6,108 ft 150 psi 10,6 PPgl Surface lead: Surface tail: Top West Sak, TM D Design lead bottom 500 ft above the Top of West Sak Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required = 3,943 ft = 3,443 ft = 0.3132 cf/If = 1,078 cf = 15% = 1,240 cf = 2.17 =t 570 = 5,636 ft = 687 cf = 80 ft = 0.4110 cf/If = 33 cf = 720 cf = 15% = 828 cf = 1.15 =l 720 sxl Casing Design / Cement Calculations 23-Nov-93 Production tail: TM D = 12,745 ft Top of Target, TMD = 12,433 ft Want TOC 500' above top of target = 11,933 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 142 cf Length of cmt wanted in csg - 80 ft Internal csg volume = 0.2148 Cmt required in casing - 17 cf Total cmt = 159 cf Excess factor = 15% Cement volume required = 183 cf Yield for Class G cmt - 1.23 Cement volume required =[ 150 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(_is)=l.$ Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) - Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 1086000 lb 5,636 ft 47.OO Ib/ft 264892.0 lb 42221.8 lb 222670.2 lb 4.91 1161000 lb 5,636 ft 47.00 Ib/ft 264892.0 lb 42221.8 lb 222670.2 lb 5.21 604000 lb 12,745 ft 26.00 Ib/ft 331370.0 lb 53106.3 lb 278263.7 lb 2.21 667O0O lb 12,745 ft 26.00 Ib/ft 331370.0 lb 53106.3 lb 278263.7 lb Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure -- Net Pressure = Design Factor =i COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000'-I'VD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 23-Nov-93 687O psi 1946.5 psi 3.5J 7240 psi 6997 psi 2929 psi 4068 psi 1.8J 4750 psi 0.553 Ib/ft 881 psi 5.4J 5410 psi 0.553 Ib/ft 3497 psi 1.5J Casing Design/Cement Calculations 23-Nov-93 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 b 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 b 4320 psi Burst 7240 psi 4980 psi ,.UPARUK RIVER UNI', 20" DIVERTER SCHEMATIC I 5 4 3 rC'r-m DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH 'TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION EDF 3/10/g2 J J 7 6 5 4 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSi AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO-FFOM PIPE RAMS. TEST BO'I rOM RAMS TO 250 PSi AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee , (2) Loc z[~ thru 8] (3) Admin ~/-, [910~&'thru 13 ]/~,~ [ 13] [14 thru 22] [23 thru (5) BOPE thrd 31' ] (6) Other /-- [3~] (8) Addl ~ \2~' ~, geology' engineering' DWJ-~ ~ RAD~ ~2-" I RP .CA~ ~ B~E~ JDH~j~3 ' TAB~9$ ~ rev 6/93 jo/6.011 Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated $ is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES NO REMARKS Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... ~ Uq- Will cement cover all known productive horizons ..................... _~ Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... _~_ _~ Is old wellbore abandonment procedure included on 10-403 ............. ~_~ Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ (J~/~ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~-~ psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... . . Is presence of H2S gas probable ...................................... ~ ./ FOR EXPLORATORY & STPd~TIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nL[nber of contact to supply weekly progress data ...... '-cZ ~-~O 33. Additional requirements ............................................. ~ Additional remarks' INITIAL GEOL I UNIT ON/OFF POOL CLASS STATUS AREAI SHORE UM X MERIDIAN' SM WELL TYPE' Ex~.~.)X' Inj Red ri 11 Rev 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 simpl.ify finding informatiOn, informati;3n 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. * Ab~SKA COMPUTING CENTER * ****************************** *----m.------ SCHI, UMBERGER ****************************** RECEIVED MAY 0 9 1994 Alarm Oil & Gas Cons. gom.missio~ COMPANY NAME : ARCO ALASKA, INC. WELb NAME : 3M-23 FIEDD MA~E I KUPARUK RIVER BOROUGH : NORTH S60PE STATE : AbASKA API MU~BER ~ 50-0~9'2~4~6-00 PEFEREMCE MB I 94018 IS Tame Veri(iication Listino chlumherger AlasKa Computlnq Center 25-APR-1994 15:36 SW~RViCE N.~MF, : EI)IT DIkTF : q,~ / (.)4 !~5 O~IGIN : wbIC CONTItqU~TIOU ~ : P~EVIOUS ~EEL : CO~4~EMI : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, ]N-23,50-0~9-22426-00 SERVICE N~ : DATF : 94104/25 OPI~IN ~ FbIC TAPF NA~E : 0401~ CONTINUATIO~ # : ~ PREVIOUS TAPE CO~ENT : ARCO ALASKA, INC,,~UPA~UK ~iVE~ TAPE NEADER KI.'PbRUK RIVER MWD/MAD bOGS ~FLL NA~E: API OPERATOr: LOG~I~G T~PF CREATION JOb DATA JOB bOGGING ENGINEER: OPERATOR WITNESS: SURVACE bOCATIO~ SECTION: TOwMSHIm: F N b FSb: FEb: ELEVATION(ET FRO~ ~SL O) KELLY BUSHINg: DE~R!C~ FbO0~: GROUND bEVML: W~bl, CASING RECORD BlT RUN 1 9401. ST. a~oua !ST ST~I~G 3M-23 500292242600 ARCO ALASKA, INC. SCHLUMBERGER ~Ebb SERVICES 21-APR-94 BIT RUN 3 25 8E 1008 1622 68,00 68,00 27,00 OPEN HOLE CI$ING DRILbERS BIT SIZE fiN) SIZE (iN) DEPTH (FT) 8.500 9,625 5437.0 PAGE: IS ~ane Verification l..,istlnq 25-AP~-1994 15:36 chlumberqar Alaska Comp~tInq Center 3RD STRING D~OD!~CTION RGS ~P TO BIT: 68.72 FT NDS RP TO BIT: 1~9.06 FT RES TO BIT: 65.55 FT G~ TO B~T: 75.97 FT ~N TO ~IT: 129.06 FT ~qFUT TO ~SIT: 136 04 FT D~I[.,LEQ INTERVAL 54~7 - 7659 FT (RU~ 1) D~I!,t, FD I~TF.~VA[, 8697 - 12100 FT (~UN 3) RGS RP TO BIT: 37.66 FT NDS KD TO BIT: 96.70 FT ~._S TO RIT: 34.~1 FT G~ TU SIT: 44.83 FT DEN 'i, 0 niT: 9~.00 FT ~EUT TU 6IT: 104.99 E~ D~ILLED INTERVAL 7659 - 8697 ~T ***********RU~': ********************** RGS RP wO BIT: !9.16 FT NDS RP TO ~!T: 41.70 FT RES I giT: 15 99 FT GR TU BI'T: 26.41 FT DEN TO BIT: 43.01 FT NEUT TO BIT: ,~g q9 FT DRILLED INTERVAL 1~100 - 12750 FT MAXIMUM HOLE ANGLE = 70,26 DEL AT 10972.34 FT TD WtlI~L AT 09:32 DEC ~7, 1993 LIS FORMAT DATA PAGE: **** FILE }~EADER **** FTLE NAME : EDIT ,00i SFRVICE : FL!C YFRSION : O01C01 DATE : q~/04/25 MAX REC S!Z~; : 1024 FIL~ wYPE : !.,Li LAST FII~E Depth sb~ted and clipped curves; all bit runs merged. DEPTH IUC~E~EUT: 0.5000 FILE SUMM~HY LDWG TOOL CODE START DEPTH STOP DEPTH IS Tane Verificat~on Listing chlumberger AlasKa Com~?utlO~ Center 25-APR-1994 15:36 PAGE: C D R CD~ # CURVE SHIFT ~ASE[.INE DFPTH 1~507 0 12422~0 ~2414,O I235~,~ 1234~, !2321,~ !2124,0 !.2!04,5 12n90 5 i2075:5 2065n 1 70:o 11941 5 !.1R42,0 11664.5 11557,0 1421 5 ~1404 5 !137~,0 1216,0 106g,O ~0966,0 10~93 5 10702' !059~'5 · ..5 1050~,5 0405,5 ~0218,5 !005~,5 996~.0 9794 5 9505 5 9366 5 9~81 0 9!48,5 8981.5 8819.5 8770,5 53~0.0 5320.0 FOR SHIFTS: GR (MEASURED DEPT~) .......... FOIIIVALE~T 88R82.~ ~250!,0 12415.5 !2408,5 12350.0 12341,5 1.2332,5 1.2116,5 12097,5 12083.~ 12072,~ 1206~,0 11966,0 1193g,0 11904.5 ~1840,0 11815,5 ~1719.5 t166~,5 11565,5 11429'5 11419,5 1.1400.5 11370,5 11213,0 11066,5 !.0965,0 10~9~.5 ~069a,0 10595,5 10500,5 10405.5 10332,5 ~.0216,5 10051'5 996~,5 9363.5 9~77.5 9~46,0 8~76,5 8~7~,0 8816,0 8775,5 12750.0 12750,0 U~!5HIFTED DMPTH ...... ---- IS Tape Veriti. catlon Listino chlumberger AlasKa Compt]ttno Cemter 25-APR-!994 15:36 8311,0 7773.5 7703.5 7522.0 731a,0 100,0 MFRCED ~ATA S~U~C~ LDWG TOOL CODE 8]06.5 7773,0 7698.5 751R,5 97.0 BIT ~UM ND, ~E~GF TOP ME~GE BASE 1 5380,0 7659.0 ~ 765~.0 8697.0 ~ 8697,0 12100.0 4 12100,0 12750.0 1 5320.0 765g.0 ~ 7659,0 8697.0 ~ 8697,0 12100,0 ~ ~2100,0 12750.0 TF~E D~PTH ADdUSTMENTS S.~OWN ABOVE REFLECT TME MWD GR OF TH~ CBT/~R DATED 29-JAN-1994. ALL (}THER MWD CURVES ., r..lNs T~IE ~ERE CARRIED ~iTH T~T S~iIFT. T~IS FILE CON' ~ VFRY FNUANCED (}~[} P~OCESSFD RESISTIVITY DATA WITH 2' AVERAGE. rile GR,C}~T IS INCLUDED Ih~ T~IS FILE, LIS FORMAT DATA PAGE: ** ~ATA FORMAT SPECIFICATION REC£)~D ** i 66 0 2 66 0 3 73 68 4 6~ 1 5 66 6 73 7 65 8 68 0,5 9 65 ~T 1~ 66 1,5 17 68 13 66 0 1~ 65 FT 15 66 68 t6 66 1 IS Tape Yerlfi..cation bistln~ chlUmber~er Alaska Computlna Center 25-APR-~994 15:~6 PAGEt .mmmmmmm#m~mm,~mmmm, mmmmm,~mmmmmmmmmmm 0 66 0 m, ....,~,ml.~....... .......mm--..... ** SET '''NAME ....... S~R ~''~'~'~'~I E ..... E AP i'';~ .............................. I AP1 APT FILE NUMB NUMB ~i~"~'";"~RO ss ..... ID ORDE~ # LOG TYPE CLASS ~OD NUMB SA~P ~LEM CODE (HEX) D~PT FT 5905~8 00 000 00 0 1 ! ~. 4 68 0000000000 R~O~ ~wD G/C3 590588 O0 000 00 0 DmSO ~w~ G/C3 599588 00 o00 00 0 PEF ~W9 BNtF 599588 00 000 00 0 C~L'~ ~D IN 590588 O0 000 00 0 NPHT ~Wn PI)-S 5905~8 00 000 00 0 R~ "~D OHM~ 599598 00 000 00 0 RP ~,Wn O~W 599598 00 000 00 0 DER ~WD O~M~ 5995~8 00 000 O0 0 VPP ~D OHN~ 599588 O0 000 O0 0 V~A ~D OHM. 5995~ O0 000 O0 0 R~P uw~ FPHR 599588 O0 000 O0 0 GP uW~ GAPI 599588 00 000 00 0 NCNT ~wD CPS 599588 00 000 00 0 FCN? ?~WD CPS 5995~8 00 000 00 0 FET ~WD HR 599588 O0 000 O0 0 G~CN CET GAPI 5995~8 00 000 00 0 I ~ I 4 68 0000000000 1 1 ) 4 * 68 0000000000 1 1 ! 4 68 0000000000 i 1 t 4 68 0000000000 1 ! 1 4 68 0000000000 1 1 I 4 68 0000000000 1 I 1 4 68 0000000000 1 1 I 4 68 0000000000 1 I 1 4 68 0000000000 1 !. 1 4 68 0000000000 1 1 1 4 68 0000000000 I ~. 1 4 68 0000000000 I ! 1 4 68 0000000000 1 ! 1 4 68 0000000000 1 1 1 4 68 0000000000 1 1. ~ 4 68 0000000000 ** DA'"A ,[ . * · DEPT. 1~743.500 RHOB. ~W[) -999 250 DRNO,~WD -999,250 PEF.~WD DE~'~W~ -~99.250 V~P.NWD 1000 000 V~A MWD 000 000 ROP G~,~WD - 99'250 NCMT,MWD 12750 000 FC G~C",C "~ 9 250 .... E r - 99' DEpT 120n0,O00 PHO6.MW'D 2.443 DRHO,MWD 0,068 P~:F MWD C~bN:~WD 9,273 NPH!.~iWD 50,710 RA,:MWD 3,666 RP~WD DE~P, ~WD 3. 765 VRP. MWD 4,084 VRA,~%WD 4. 181 ROPiMWD GP MWD 269,625 NCNT,MWD 12004,146 FCNT,MWD 4,685 FET.~WD GRC[;:CET 154.050 MpT. 1J000.000 RBOB MWD 2,453 DRHO.iqWD -0 009 PEF.MWD ~LN,M~D 8.500 NP~!~MWD 35,361 RA.MWD 4 39! RP,~WD DE~.~W~ 4.472 VPP'i~WD -999,250 V~A.~WD -999 250 ROP,~D GR, M~D 113.623. NC[IT . ~WD 11002 . 01 8 FCNT';MWD 6 143 FET,MWD'~ GRCW,CET 62.873 DEPT 10000.000 RHOB,MWD 2 425 DRMO.MWD 0,027 PEF MWD .~. ' MWD 28~400 RA,MWD 4.531 RP,~WD C~bS~*~ND 8.500 NP~qi. ' ' *. ~WD 4.491 V~P,MWD '990,250 VRA'MWD -099,250 ROP,~WD GR.~ 101.230 "CMT ~iWD I0001 789 Fc~!r,awD 7.93o FET.~WD -999 250 -999 250 ~9 5O9 -999 250 44,443 0;506 3, .479 4,513 323'516 0,244 2,963 4'475 39~.312594 IS Tape Verti~cation Listinq chlumberqer A!asKa Computln~ Center GPCN.C~T 57.201 DFPT. gO00.O00 PHOO.MWO CaLN,~wD 8.767 NPHI,MWD DE~.MwD 4,0]7 VPP.~WD G~.~w~> 118.306 MC~T.MwD GPC~.CET 76.2~9 DEPT. ~000.000 PHOB.MMO C~LW.MgD 8.794 ~P~I,~wD G~.~WD 138'0~4 NCNT,MWD G~CU.CET ~2.606 DFPT. 7000.000 PHOB,MWD CaLN,~wD 8,633 NPMI.MWD DEP,M~D 5.609 VPP,MWD GP,~D R9,8~9 NCMT,MWD GPC~.CET -999.250 DEPT 5305 000 ~HOB.~tWD C..~LN:?tWD -999;250 NPMI,MWD .D.E~. ~'WD 999,250 VRP G~.~WD :999,250 NCNT.MWD G~CM,CET -999.250 ** END OF DATA **** FILM TRAI!,ER **** FILE NAME : EDIT ,001 SERVICE ~ FLIC VERSION : 00~C01 DaTE : 94104/25 M~X REC 5IZ~ : 10~4 FILE TYPE : LO 25-aPR-1994 15:36 2.44~ DRMO.MWD 35.692 RA.MWD -999.250 VPA.MWD 9005,154 FCNT,MWO ~.350 DRHO.MWD 43.]3! RA.MWD -999,~50 VRA MWD @002,702 FCNT$MWD ~,390 DRHO,MWD 34,600 PA,MWD -999,250 V~A.~WD 7003,500 FCNT.MWD 2.2~3 DR~O,~WO 37,150 RA,MWD -999,~50 VRA.MWD 6003.500 FCNT,MWD -999.250 DRMO,MWD -999,250 RA,MWD -999,2,50 VR~.MWD 5309.000 FCN ]~'.MWD 0.015 3.937 -999.250 6,317 0.010 2 785 -999:250 4.886 0,000 4.J55 -999.250 6.122 -0.008 5.257 -999.250 5.670 -999.~50 -999,~50 -999,1~50 -999,~50 PEF.~wD RP.~WD RoP.~D FET,~WD PEF.~WD RP.~WD ROP.~D FET,~WD PEF.~WD RP,~WD ROP.MWD WET.~WD PEF.~WD RP.~WD ROP.~WD FET.~wD PEF.NWD RP.~WD ROP,~WO FET,~WD 2,863 4,090 251.491 0.298 2.995 3,587 116.285 0,275 3.t48 6,159 112,532 0.337 3.003 898 0o2~2 999'250 999,250 -999,250 -9 9 9,2 5 0 IS Tame Verlficatlon chlumberger Alaska Computing Center 25-APR-1994 i. 5:36 PAGE: **** FILE HEADER **** FILF ~AuE : EDIT .002 SFRV!C5 : FblC V~RSIO~ : O01CO1 DaTE : q4/04/25 S~X RFC SIZE : 10~4 FTLF TYPE ! 1,0 LaST FILE : FILF_ FILF ~,3 U~ BER 2 Curves and log header data for each bit run in separate BIT R~N NUt, AEC: 1 D~PTH INC~EMENT: 0.5000 F~LF SU~ARY !,DWG TOOL CODE START DEPTH STOP . 5. ... 7659,0 CD" 5308.0 7659,0 LOG HEADER DATA ~ATE LOGGED: 28-DEC-93 SOFTWARE: SURFACE 50FTWARE VErSIOnal: FAST 2.4 DOWNHObE SOFTWARE VERSION: DATA TYP~ (N~E~ORY or R~L-TIME): MEMORY TD [)~ILL,~R (FT): ~.2750 9 TOP LOG TNTERV~h (FT): 5320.0 gOTTO~ LOG I~TERVA[,, (FT): ~2750.0 BIT POTATI~{G SPEED gOLE I~,}CLINATION (~EG) HAXI~U~] ANGL~: 70.3 TOO[, STRir,~G (TOP TO BOTT[,J~) VENDOP TOOL CODE TOOL TYPE .......... ..... . ca D. RESISTIVITY Cr) N NEUTRoN/POROSITY BORENO[,E AND CASIk~G DATA OPEN !{OLg BIT $IZ~ DRIL[.,ERS Ch$11NG DEPTH MUD TYPE: NUD DENSITY (LB/G): TOOI~ N[IMBER R(;S022 NDS049 ..5O 1 1,30 files. Tame Verification List. lng chlu.{berger AlasKa ComputinQ Center 25-APR-19Q4 15:36 PAGE{ ~UD VI$CUSIT¥ MUD CMLO~D~5 FLUID LOSS ~AXIMUM ~CORDED TEUPERATUR~ (DEGF): R~SISTIVITY (OH~M) AT TEMPErATUrE ~UO AT MFASURED TEMPRR~TURE (MT): ~UD AT MAX CIRCU~,ATI~!G TEMPERATURE ~UD FIi,TRATE AT ~UD CAKE AT TOOL MATRIX: ~ATRIX DENSITY: CORR~CTIQ~,~ (IN): 150.0 2.140 1.640 # SANDSTONE 2.65 TOOL STANDOFF 1 , 000 RUN I DRII,LFD INTERVAL 5437-765g FT RUN 2 D~I[,L~D INTERVAL 7659-8697 FT RUN 3 D~ILLKD INTERVAL 8697-1~100 FT RUN 4 DRILLED INTERVAL ~2100-12750.g .FI HOLE ANGL~ AT ~, = 45 75 DEG ~AXTMUM HOLE AN~L~ = ~0,26 DEG AT 10972,34 FT TD WELL AT 9:32 DEC 27, 1993 S L~S FORgAT DATA 7~.0 70.0 ** DATA FORUAT SPE:CIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1,1 66 16 i~ 68 13 ~6 0 14 65 FI 15 6b 68 16 66 I 0 66 IS Tare Yel"If!cation [,ist~nn chlumberoer Alaska Compt]t~nq Center 25-APR-1. 994 15:]6 PAGE% mmmmmmmm.~w m mmm.mmmmmmmmWm'mmm SET ~YPE - CNAM * nRD~ ~ m..mmmmmmmmmmmmmmmmmmmmm.m mmm FT 590588 OOO G/C3 5905~8 000 PU 599588 000 G/C3 599588 BN/E 599588 I~' 599588 PU 59~5~8 000 OgN~ 599588 000 O~M~ 5995~8 000 OMM~ 59958~ 000 F/M~ 599588 000 GAPI 5995~8 000 CPS 5995~8 000 CPS 599588 000 HP 59~58~ 000 HR 5995~8 000 DEP? RWO~ Lw DPHT PEF DCA[~ TNP~ L~ ATR PSR D~R ROpE LW G~ I.,W HEN~ HFFA LW bOG Isms,II,j. O0 00 0 2 O0 00 0 2 O0 O0 0 2 O0 00 0 2 O0 O0 0 2 O0 O0 0 2 O0 O0 0 2 O0 O0 0 2 O0 00 0 2 O0 O0 0 2 00 00 0 2 O0 O0 0 O0 O0 0 O0 O0 0 2 O0 O0 0 O0 O0 0 mmmmmmmm. API API API FILE NU~{B NUmB S ZE TYPE CLASS MOD NUmB SA~P ELEM C mmmmmmI!m .#mmmmmmmmmmmi-- I 1 4 68 I 1 4 6~ ! I 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 1 4 6~ i 1 4 68 1 1 4 68 1 I 4 68 1 I 4 68 1 1 4 68 1 I 4 68 I 1 4 6~ 1 1 4 68 1 1 4 68 mm.m~mmm~mmm.mmmmmmmmmmmm~mmmmm ODE (HEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 7658 DFP LW!. -909 HFNn.LWi 7659 7000 PSP.L'~'I 4 HEN!.I,~,~! 7000 DEPT. 6000 PEw. LW ! 2 PS~. I~W1 5 H~Na. t,W i11 6000 .500 RFiOB.LWl -999.250 DPHI.L, W1 .250 DCAh. LN1 -999 ~50 TNPH'bW1 .250 DER.LWl -999:250 ROPE,LW1 .000 HEFA.I, WI -999.250 TAB,I, WI 000 RHOB.bW1 2.272 DPHi,LWi 808 DC~,b,LWl 0.016 TNPH LWl P" :' .589. DER.LWI 4'484 RO E,LW .500 HEPA*LWI 5.288 TAB,hW 000 RF{OB.LW'i 2,231 DPHI,LWI :9~5 DCAL bWl 0,016 TNPH.DWl ,0t6 DE:R:LWl 5'087 ROPE,LW~ ,500 HEPA.LW1 5.610 TAB'LWi ** EjND OF DATA ** -999.250 91.043 -99~.250 22,950 40.550 106 189 0 35O 25400 38i050 587 739 0.244 -999. 250 -999.250 -999'250 -999,250 DRHO.LWl ATR.LW! GR.LWl TABD,LWl DRHO.I, Wl AT~,L~I GR.LWl TABD.L~I DRHO.bW1 DRhO.SWl -999..250 -999,250 -999.250 -999.250 -0,004 4,164 105.960 0,586 '0.020 5.230 111.406 0,488 9'250 -999,250 -999,250 Tape verlf{~catlon Y,ist{,no chlumberqer Alaska ComputinO Center 25-aPR-1994 15:36 PAGE: 10 **** FILE T~It.,ER **** F!bF NA~E : EDIT .002 SERVICE VFRSIO~ : 001C01 D~TF : 94/04/25 MAX RFC SIZE FTLF TYPE : LO L~S· FILE : **** FTLE WEADER **** FILF NA~E : FDIT .003 SFRVICE : FLIC VFR$ION : 001C01 D~T~ ~ 04/04/25 N~X RFC SIZE : 10~4 FILF TYPE : LO LAS· FILE : FILF HEADER FILE NUMBER R~W MWD Curves and log header data 1or each bit run ~n separate BIT RUN NUMBER: DKPTH INCREMENT: 0,5000 FTLF SU~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ' '"' o LOG HEADE~ DATA DATE bOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DO~MHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or ~EAL-TI~E): TD DRILLER TOP LOG INTERVAL (MT): ~OTTOM bOG INTERYAL RIT ROTATING SPEED ~OL5 INCLINATION {DEG) MINIMUM ANGLE: ~.~XIMU~ A~GLE: 70,3 TOOL STRING (TOP TO ~OTTOM) V~NDOR TOOL COD~ TOOL TYPE CON NEUTRON/POROSITY ~8'DEC-93 FAST 2,4 ~E~ORY ~.2750,9 5320,0 12750,0 TOOL NUMBER ~GS022 NOS049 files. IS Ta~e Vmrtf~.cation List~.nq cblumberger Alaska Comput~mq Center 25-APR-1994 15:36 ~O~EHOLE AND CASING DATA OPEN HOLE BIT DRILl,ER8 CA~ING DEPTH BO~EHOLE CUNDIT1ONS ~UD TYPE: ~UD DENSITY ~U~ VISCOSITY ~!~D C~bOR?DE$ FLUID LOSS (C3): ~AXIMIIM RECORDED RESISTIVITY {OH.Si AT TEMPERATURE MUD AT ~EASU~ED T~PERATURE MUD ~T ~AX CIRCULATING TEMPEPATURk ~UD FILTPATE AT MUD CA~E AT (MT): RNG$O09 8,50 5437?0 ~*E!!TRON TOOL MATRIX: MATRI× DENSITY: HnLM CORRECTIOD (IN): # TOOL STANDOFF (IN): ~WR FREQUENCY (HZ): 11,30 150.0 2,140 1.640 SANDSTONE 2.65 1,000 RUN I DRILLED INTERVAL 5437-7659 FT RUN 2 D~ILbED INTERVAL 7659-8697 FT RUN 3 DRILLED INTERVAL 8697-1~100 FT RUN 4 D~ILLED ~NTERVAL ~,2Z00-~2750.g FT HOLE ~NGbM AT T~ = 45 75 DEG M,~X. IMUM HOLE ~NGLE = ~0.26 DEG AT 10972.34 FT TD WELL AT 9:32 DEC 27, 1993 $ LIS FORMAT DATA 72.0 70.0 PAGE: 11 ** DATA FnR~AT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REP~ CODE ¥'~LUE ! 66 0 2 66 o 3 73 64 4 66 5 66 6 73 IS WaDe Vertflcatlon Listtna cblumberg~r AlasKa Computinq Center 15:36 PAGE: 12 mmmmmmmmmmm,lmmmmmlmmm~mmmmmmmmmm 7 65 8 68 0,5 9 65 FT !1 66 16 12 68 13 66 0 14 65 FI' 15 66 68 !6 66 0 66 m#mmmmmmm#mmmmmm#mmmmmmmmmmmmm ** SET TYPE - CNAN ** mmemmm mmm m mm mmm mm m mmmmmmmmmemmmmmmmmmmmmemmm '"'"'"'" ...... ...... '"""' ............... ['" .... "'"'"'"'"'"'"" ooo oo o 4 oooo oooooo G/C] 5~588 O0 0~0 O0 0 3 1 1 4 68 0000000000 RMOR LN2 DPHI' l.,w2 PU 59q588 O0 000 O0 0 3 1 1 4 68 D~HO LW2 G/C3 590588 00 000 00 0 3 I 1 4 68 PFF L~2 BN/~ 599588 00 000 O0 0 3 1 I 4 68 DCAL LW2 iN 599588 00 ()00 00 0 3 1 I 4 68 TNP~ LW2 PU 599588 00 000 00 0 3 1 I 4 68 ATR L~2 ONM~ 5995~8 00 000 00 0 3 1 I 4 68 PSR I.,~2 OMM~ 599588 O0 O00 00 0 3 1 1 4 68 D~R LW~ OHN~ 599588 O9 000 00 0 3 1 I 4 68 ROPF 1,~2 F/H~ 590588 O0 000 O0 0 3 I 1 4 68 GR b~2 GAPI 599588 00 000 O0 0 3 I 1 4 68 H~NA Lw2 CPS 599598 00 000 00 0 3 i I 4 68 H~FA LN2 CPS 599588 00 000 00 0 3 1 1 4 68 T~B LW2 HR 599588 00 000 00 0 3 i 1 4 68 T~BD [!N2 HR 599588 00 000. O0 0 3 1 ! 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATa DEPT. 8000.000 9HOO:.bW2 :344 DPHI,D.~ 2 PEW I,W2 2'965 DC~.L.I[.~W2 ~237 TNPH',IaW2 ~S~ ~[,W2 3.227 DER'~w2 2,953 ~OPE,LW2 H~N~.[~O'2 ~000.500 ~Erh.bw2 5.064 T~B.SW2 D~PT. 7659,000 ~?i06. bw2 2,1,89 DPHI.LW2 PEw LL~2 1,703 . CAb h~2 t. 275 TNPH.DW2 vS~.I,,N2 23,547 D~R,bW2 2~.752 ROPE,LW2 H~N~.I~W2 7659,500 HFjFA' l,~W 2 0.38! T,AB. bW2 18.550 DRHO..LW2 3'650 ~,TR't, W2 124; 19! GR.LW2 0,275 TAB[),LN2 19.750 225 167 GR.I,~2 I ~299 TA:BD 0,061 3,503 122,097 0,854 0,016 2,628 140,556 0,929 0.022 17'736 44' 646 !.633 IS ?Hoe Verification [,ist~no chlumberqer AlasKa Computing Center 25-AFR-~gg4 15:~6 PAGE: 13 END OF DATA V~R$10~ : O01CO1 D~T~ : 04/04/25 ~AX REC S~ZE : 10~4 FILr TYPE : LO LaST FILE : **** FILE ;~EaDER **** FILE NA~E : EDIT ,004 SERVICE : FLIC VERSIO~ : O0~CO1 D~T? ~ 04/04/25 ~X REC SIZF : !.0~4 FILE TYPE : LO L~ST FILE FILE ~EaDER FILE NUMBER 4 RAW ~WD Curves and log Seader data for each bit run Jn separate BIT RUN NUMBER: 3 DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOk, C~DE START DEPTH 8697'0 CDN 8697,0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHObE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG !NTE~VAL (FT): ~OTTOM LOG INTERVAL BIT R[)TATING SPEED MOLE INCLINATION (DEG) ~INIMUM ANGLE: ~AX!MU~ ANGLEr STOP DEPTH 12100,0 28-DEC-93 FAST 2,4 ~E~ORY ~2750,9 5320,0 12750,0 70.3 files. iS Tape Verification Listing chlumberger Alaska Comps]ting Center 25-APR-1994 15:36 PAGE: 14 TO[iL STRING (TOP TO BOTTOM) VFNDOR ~OO6 CODE TOOI TYPE RESTSTI¥ITY NEUTRON/POROSiTY OPEN MOLE !~IT $IZF (I~.~): DRILl,EPS CASING DEPTH (ET); TOOL NUMBER ~GS 22 NOS049 ~NGS00g BOREHObE CONDITIONS MIlD TYPE: D~NSITY {LB/G): VTSCOSITY (S)~ pH: CHLOR!DE8 (PP~)~ FI, UID LOSS M~XIMUM RECORDED TE"P~RATI.!RE (DEGF): RESISTIVITY (OMEN) ~T TEMPEPATURE (D~G~): MUD AT MEASURED TEMPERATURE ~UD AT M~X CIRCULATING TEMPERATURE : ~UD FII,TRATE AT (~T): ~UD CAKE AT [MT): NEUTRON TOOL M~T~iX: MATRIX DENSITY: HOLE CORRECTION (IN): # REMARKS: TOOB STANDOFF (IN): EW~ FREQUENCY (HZ)~ 8.500 5437,0 11,30 150,0 2.140 1,640 SANDSTONE ~.65 t.000 RUN 1 DRILLED INTERVAL 5437-7659 FT RUN 2 DRILLED INTERVAL 7659-8697 FT RUM 3 DRILLED I~TERYAL 8697-1~100 FT RUN 4 DRILLED INTERVAL 12100-12750,9 FT HOLE ~NGLE ~T 'rD = 45 ~5 DEG MAXIMUM HOLE ~NGbE = ~u.26 DEG AT 10972.34 FT TD WELL AT 9:32 DEC 27, 1993 $ bls FORMAT DATA 72.0 70.0 IS Ta~e Verification l.istinq chlumberger AlasKa Computin~ Center 25-APR-~994 15:36 ** OATA FORNAT SPMCIFICATTON RECORD ** ** SET TYPE - 64gE ** vypE R~P~ CODE ~AbUL I ~6 0 2 66 0 3 v3 6~ ~ 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1~ 66 ~6 lP 68 1] 66 0 14 65 FT 15 66 68 i6 6B 0 ~6 m~m~mmmmmmmmm~mmm~mmmmmmmm~mmm ** SET TYPE - CgAM ** V UN T ~RV E APl API AP1 API FILE ~ B UMB SIZE REPR PROCEg ~D ORDER # bOG TYPE CLASS ~OD NUMB SAMP EbM~ CODE (HEX) DEPT 8 0 000 O0 0 4 4 68 000000000 RHOg [,N3 G/C3 5995~8 O0 000 O0 0 4 1 1 4 68 DPH! LW3 PI] 599588 O0 000 O0 0 4 1 1 4 68 DRHn LN3 G/C3 599588 00 000 O0 0 4 I I 4 68 PFF [,,w3 BN/E 590588 O0 000 O0 0 4 1 i 4 68 DCAL b~] !N 599588 00 000 00 0 4 1 1 4 68 T~P~ L~3 pU 599588 00 000 00 0 4 1 i 4 68 ATR ~,W3 OHM~ 59g588 00 000 O0 0 4 I I 4 68 PSR Lb3 OHM~ 599588 00 000 O0 0 4 ! 1 4 68 DFR LN3 O~MM 590588 O0 000 O0 0 4 1 1 4 68 ROP~ LW3 F/HR 599588 00 OO0 00 0 4 1 1 4 68 G~ !,W3 GAPI 599588 00 000 O0 0 4 1 1 4 68 HEN~ LW3 CPS 590588 00 000 00 0 4 1 i 4 68 H~FA !,W3 CPS 599588 00 000 O0 0 4 1 I 4 68 TAB LW3 HR 599588 00 000 00 0 4 1 I 4 68 TA~D LW3 H~ 590588 O0 000 00 0 4 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~m~mmm~mmmmmmmmmmmmmmm~mm~mmmmmmmm~m~mMmmmm~m~mm~mmmmM~mmmmmmmmmm~Mmm~m~m~mm~ PAGE: 15 ** DhTA ** DEPT, DEF,LW3 H~Na,LW3 12100,000 RHOB.bN3 14.615 DCaL,LW3 2.167 DER.LW3 12100.500 HEF~.LW3 187 DPHI.bW3 458 TNPH,LW3 2,159 ROPE,LW3 4,645 TAB.LW3 28.100 DRHO LW3 .48 100 ATR LW3 1.87!394 GR LW3 12 556 TABD I..,W3 0,026 2.148 196, 75 13,238 I$ Tape Verification bistlnfl chlumberger AlasKa Computino Center D~PT. 12000.000 RHO~.LW3 PEV.L~3 2.005 DCAL.LW3 PS~.I.,W3 3.374 WFR.Lw3 HFN~.L~] 12000.500 MEFA.LW3 DFPT. 11000.000 ~HOB.LW3 DEW.LW3 3.564 DC~b. LW3 PS~.L~3 4.529 D~R.LW3 ~FN~.[,~ 1~000,500 ~EFA.LW3 DFpT. 10000.000 RHOt~.LW3 PEF.t, n3 2.957 DCAL.LW3 PS~.LW3 4.492 ~R.LW3 HFNA.I,~3 10000.500 ~EFA.bW3 DFPT. 9000.000 RHOO,LW3 PEF.I,~3 2.B&O DCAL.LW3 PS~.I,~3 4.050 DER.LW3 HFN~.LW3 0000.500 HEFA.LW3 D~3PT. ~697.000 ~HOB.LW3 PEF.L~3 2,864 DCAI~.LW3 PS~ LW3 5.6~4 DER,LW3 HFN~ ~,w3 ~g7.500 UEFA.LW3 E:N[) OF DATA **** FILE TRAILER FILF NA~E : E~IT ,004 SERVICE : FDIC V~R$ION : 00~C01 D~T~ ~ 04/04/~5 ~AX R~C SIZE : F!LK TYPE : bAST FILE **** FILE FILM NAME : MDIT ,O05 SERVICE : FDIC VFRSION : O0~COi DATE : 94/04/25 M~X REC SIZE : !0~4 FTLF TYPE : L~ST FILE FTb~ FILM 25-AP~-1994 !5:3b 2.300 DPMI.hW3 0.887 TNPH,LW3 3.377 ROPE.LW3 4.636 TAB.LW3 2.453 DPMI.bW3 0.000 TNPt~.DW3 4.479 ROPE.LW3 6.475 TAB.LW3 2.432 DPHI.LW3 0.000 TNPH.LW3 4.541 ROPE.LW3 7.484 TAB.LW3 2,419 DPBI.LW3 0.267 TNPH.DW3 4.009 ROPE.LW3 6.456 TAB.LW3 2.479 DPHI,LW3 0.777 TNPH.LW3 5.092 ROPE.LW3 5'054 T~B.bW3 21.200 46.100 45.714 0.607 12.000 35.300 318.405 0.243 13.200 28.700 384.526 0.593 14,000 33.750 273.707 0.300 10.350 42.200 865 387 0~422 DRHO.Lm3 ATR,Lw3 GR.Lw3 TABD.LW3 DRHO.LW3 ATR.Lw3 TABD.LW3 DRHO.LW3 ATR.LW3 GR.Lm3 TABD.Lw] DPHO.LW3 ATR.LW3 GR.Lw3 TABD.LW3 DRHO.L~3 ATR.LW3 GR.LW3 TABD.LW3 PAGE: 16 0.127 3,384 197.986 0.262 -0,011 115,557 0,819 0.027 1.79 0.922 0.010 3 929 121:407 0,615 0 061 122,097 0.854 IS Tape VerJflcatlon List!,nq chlumberger AlasKa Computing Center 25-APR-~q94 15:36 PAGE: 17 R~w MWD Curves and loq r~eader data for each bit run ~n separate BIT RUN NUMBER: 4 [)FPTH INCRE~E~7': 0,5000 FILm SUmmARY LDWG TOOL CODE START DEPT~ T T; T; .... 12100.0 $ # LOG HEADER DATA hATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOGE SOFTWARE VERSION: mATA TYPE (MEMORY or REA[,-TIME): TD DPI[,,LER (FI): mop LOG INTERVAL (FT): ~OTTO~ LOG INTERVAL (FT): PIT ~OTATIMG SPEED ~OLE INCLINATION ~!NIM~!M ANGbE: ~AXIMU~ ANGLE: TOOL STNING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR Ty CDN STOP DEPTH 12750.0 ~2750,0 NEUTRON/POROSITY BO~EHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLEP$ CASING DEPTH (FT): ROREHOLE CONDITIONS MUD TYP~: MUD DENSITY (LB/G): M~D VISCOSITY MUD MUD CgLORIDES (PPM): FLUTD LOSS M~XIMUM RECORDED TEMPERATUR~ (DEGF): RESISTIVITY (O~M) AT TEMPERATURE (DEGF): ~UD AT MEASUPED TE~PERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE : ~UD FILTRATE AT (MT): ~UD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: 28-DEC-93 FAST 2,4 ~E~ORY 12750.9 5320.0 ~2750.0 70.3 TOOb NUMBER riGS022 NDS049 PNG$o0g 5OO 11.30 150,0 2,140 1,640 SANDSTONE 2.65 files. 72,~0 70.0 Tape Verlf~catlon bistlno chlumMerger AlasKa ComputinO Center 25-APR-1994 ]5136 HOLE CORRECTION TOOL STANDOFF (IN): R~R FREOUE~CY (HZ): 1 , R~N 1 DRILLED INTFRVAb 5437-7659 VT KUN 2 D~ILLED INTFRVAL 7659-8697 FT RUN 3 D~ILLED INTERVAL 8697-i2100 FT RUN 4 D~ILLRD INTERVAL ~2100-~2750.g FT HOLE ~NGLE AT TD : 45.75 PEG MAXIMUM HOLE A~4G~ L~ = 70, 26 PEG AT 10972.34 FT TP WELL AT ~:~2 DEC 27, ~993 $ LT$ FORUAT DATA PAGE: 18 ** DATA FORMAT SPECIFICATION PECURO ** ** SET TYPE - 64ER ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0 5 9 65 11 66 16 12 68 13 66 0 14 65 ~T 15 66 68 !6 66 0 66 ** SET TYPE - CHAN *~ N~ME SFRV UNIT S~RVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) DEPT FT 599588 O0 000 O0 0 5 1 1 4 68 RHOR L~4 G/C3 599588 O0 000 O0 0 5 ! I 4 68 DPH~ LW4 PI.! 599588 O0 000 O0 0 5 I 1 4 68 DPHO 1,~4; G/C3 5905~8 O0 000 O0 o 5 l 1 4 68 PEF L~4 BN/E 599588 O0 000 O0 0 5 1 1 4 68 DCAI., b~4 IN 5995~8 O0 000 O0 0 5 ! I 4 68 TNP~ l, Wa PU 599588 O0 000 O0 0 5 I. I 4 6~ 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TmDe Verification [,istlnq chlumberger AlasKa Computln(: Center 25-aPR-1994 15:]6 PAGEt 19 NA F E , IT f VICE APi APT AP1 AP! FIL M_. N M EPR PROCESS TD ORDER ~ LOG TYPE CLA~S MOD NO~B SAMP ELEM CODE (HEX) ...... .... ................. ' ..... ' .... ' ............... 2 ...... ' .......... """ ATR ..W ~ 99588 O0 000 O0 0 5 1 1 68 0000000000 OHMM 599588 O0 OOO O0 0 5 1 1 4 b~ 0000000000 PSR 5~4 DER b~a OHN~ 599588 O0 000 O0 0 5 ~ I 4 68 0000000000 ROP~ LW4 F/H~ 590588 O0 000 O0 0 5 1 1 4 68 0000000000 G~ LW4 G~PI 59~588 O0 000 O0 0 5 1 1 4 68 0000000000 H~N~ L~4 CPS 5995R8 O0 000 O0 0 5 1 1 4 68 0000000000 HFFa I.,~4 CPS 59~598 O0 000 O0 0 5 1 I 4 68 0000000000 T~ LW4 H~ 599588 O0 000 O0 0 5 1 1 4 68 0000000000 TAB~ 1,~4 HP 5995~8 O0 000 O0 0 5 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmm-mm~mmmmmmmmmmmmMmm-mmm#mmmmmm~mmmmmmmmm-mmmmmmmmmmmm~mmm#m- ** DATA ** DEPT. 12749.500 nEF.L~ -999.250 DCAL,bW4 PS~.LW~ -999.250 DER.LW4 HEN~.LW4 12750.000 HEFA.LW4 D[PT 12100.000 ~HOB.LW4 . EW:L~4 ~4.615 DCaL'LW4 mS~. [..,~ 4 2,167 DER. LW4 HENa.LN4 12100.500 HEPA.LW4 ** END OF DATA ** -999.250 DPHI.LW4 -999 250 TNPM.LW4 -999!250 P{]PE.LW4 -999.~50 TAB.LW4 187 DPH! bW4 ~:458 TNP":5W4 159 ~OPE.LW4 ]:645. T~8.bW4 -g99.250 DRHO.LW4 -999. so 29.509 GR:[,,~4 -999.250 T~BD,LW4 28 100 DRHO LW4 48:.100 ~,,TR :LW4 187 ]94 GR.LW4 1~:556 IABD.L~4 -999.250 -999 250 -999:250 -999.250 0,026 2,148 196.175 13,238 **** FTLM TRAILER **** FILE NA~E ~ EDIT ,005 SERVICE : ~L!C VERSION : O01COt DATE ~ 04/04/25 MAX REC SIZE : 1024 F?LF TYPE : LO **** TAPE TRAILER **** SERVICE NANE : EDIT DBTE : 94104/25 O~I~IN : FLIC T~P~ MA~E : 94018 CONTiNUhTION # : 1. PPEVlOUS TAPE COMMENT : ARCO A{,ASKA, INC.,RUPARUK RIVE~ UNIT, IS Tame veri~icatlon f, ist.fno chlumberger AlasKa Computing Center 25-APR-1994 15:36 2O **** RME[, TRAIl. ER **** SERVICE DATE : ~4/Q4/25 CnNTINUaTIOM # PnEVlOUS REEL : COM"ENT : ARCO A!.,ASK~, INC,,KU~ARU~ RIVER UNIT, 3M-23,50-029-224~6-00
