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Home My WebLink About179-043MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, April 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-02 PRUDHOE BAY UNIT WGI-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/12/2024 WGI-02 50-029-20379-00-00 179-043-0 N SPT 7541 1790430 3700 1215 1686 1674 1672 103 102 102 102 REQVAR P Adam Earl 3/14/2024 MIT-IA tested as per AIO 4G.015 to 3700psi max Ant. Inj. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT WGI-02 Inspection Date: Tubing OA Packer Depth 530 3793 3785 3785IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240320103818 BBL Pumped:7.5 BBL Returned:4 Friday, April 12, 2024 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Date:Wednesday, March 16, 2022 10:12:10 AM Attachments:image002.png image004.png image003.png From: Wallace, Chris D (OGC) Sent: Wednesday, March 16, 2022 10:11 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Ryan, We have received the AA request and you are approved for continued gas injection while we process this. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793- 1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, March 16, 2022 9:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) passed AOGCC witnessed MIT-IA on 03/13/22. An AA request has been submitted. With permission, we would like to extend the UNDER EVALUATION period and keep the well on gas injection as needed until the AA request has been reviewed by the AOGCC. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Thursday, February 17, 2022 5:27 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) has been found to have probable slow IAxOA communication. OA pressure trends with IA pressure / temp rate swings but also has a buildup rate of ~5 psi / day. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: PPPOT-IC; OA re-pressurization test 2. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 22, 2020 9:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com> Subject: OPERABLE: Gas Injector WGI-02 (PTD #1790430) TxIA mitigated with oversized packing on SSSV Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) was made Under Evaluation on 07/03/20 to address TxIA communication. On 07/12/20 Slickline replaced the A1 Injection Valve with oversized-Freudenberg packing to mitigate communication through the control and balance lines. Follow up monitors confirm the TxIA has been mitigated and the well is now re-classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Friday, July 3, 2020 6:31 PM To: Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Jennifer Blake <Jennifer.Blake@hilcorp.com>; John Menke <jmenke@hilcorp.com>; George Ivie <givie@hilcorp.com>; David Bjork <David.Bjork@hilcorp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Patrick Bixby <Corey.Bixby@hilcorp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector WGI-02 (PTD #1790430) Slow Tubing x Inner Annulus Communication All – Injector WGI-02 (PTD #1790430) has been found to have slow tubing x inner annulus communication. IA pressure was bled on 7/1/20 from 730 psi to 290 psi and subsequent monitoring indicates ~40 psi / day build up rate with steady injection rate and temperature. The well is now classified as Under Evaluation and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Flush control / balance lines and pump GX Sealant 2. Downhole Diagnostics: Monitor IA re-pressurization 3. Well Integrity: Additional corrective action as required. A 90 day injection rate / pressure and TIO plot have been included for reference however it does not show the most recent bleed event due to network outage. Please call with any questions or concerns. Ryan Holt Hilcorp Well Integrity / Compliance 907-659-5102 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictlyprohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or useof this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Gas Injector WGI-02 (PTD #1790430) AA granted for continued gas injection Date:Monday, March 21, 2022 3:41:33 PM Attachments:image002.png image003.png AIO 4G.015.pdf image004.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 21, 2022 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Gas Injector WGI-02 (PTD #1790430) AA granted for continued gas injection Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) now operates under AA AIO 4G.015 for continued gas injection with known IAxOA communication. The well is now classified as OPERABLE. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 18, 2022 1:36 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace – Please see attached 10-426 for AOGCC MIT-IA conducted on WGi-02 03/13/22. Thanks, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, March 18, 2022 10:04 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Ryan, Please provide the mentioned MITIA of 03/13/2022 on the Form 10-426, to the distribution list, so we may add to our database and progress the admin approval for this well. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793- 1250 or chris.wallace@alaska.gov. From: Wallace, Chris D (OGC) Sent: Wednesday, March 16, 2022 10:11 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Ryan, We have received the AA request and you are approved for continued gas injection while we process this. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793- 1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, March 16, 2022 9:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) passed AOGCC witnessed MIT-IA on 03/13/22. An AA request has been submitted. With permission, we would like to extend the UNDER EVALUATION period and keep the well on gas injection as needed until the AA request has been reviewed by the AOGCC. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Thursday, February 17, 2022 5:27 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) has been found to have probable slow IAxOA communication. OA pressure trends with IA pressure / temp rate swings but also has a buildup rate of ~5 psi / day. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: PPPOT-IC; OA re-pressurization test 2. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 22, 2020 9:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com> Subject: OPERABLE: Gas Injector WGI-02 (PTD #1790430) TxIA mitigated with oversized packing on SSSV Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) was made Under Evaluation on 07/03/20 to address TxIA communication. On 07/12/20 Slickline replaced the A1 Injection Valve with oversized-Freudenberg packing to mitigate communication through the control and balance lines. Follow up monitors confirm the TxIA has been mitigated and the well is now re-classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Friday, July 3, 2020 6:31 PM To: Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Jennifer Blake <Jennifer.Blake@hilcorp.com>; John Menke <jmenke@hilcorp.com>; George Ivie <givie@hilcorp.com>; David Bjork <David.Bjork@hilcorp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Patrick Bixby <Corey.Bixby@hilcorp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector WGI-02 (PTD #1790430) Slow Tubing x Inner Annulus Communication All – Injector WGI-02 (PTD #1790430) has been found to have slow tubing x inner annulus communication. IA pressure was bled on 7/1/20 from 730 psi to 290 psi and subsequent monitoring indicates ~40 psi / day build up rate with steady injection rate and temperature. The well is now classified as Under Evaluation and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Flush control / balance lines and pump GX Sealant 2. Downhole Diagnostics: Monitor IA re-pressurization 3. Well Integrity: Additional corrective action as required. A 90 day injection rate / pressure and TIO plot have been included for reference however it does not show the most recent bleed event due to network outage. Please call with any questions or concerns. Ryan Holt Hilcorp Well Integrity / Compliance 907-659-5102 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If youare not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carryout such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictlyprohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or useof this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4G.015 March 21, 2022 Mr. Bo York PBE Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: AIO-22-008 Request for Administrative Approval to Area Injection Order 4G; Gas Injection Prudhoe Bay Unit (PBU) WGI-02 (PTD 1790430), Prudhoe Oil Pool Dear Mr. York: By emailed letter dated March 14, 2022, Hilcorp North Slope, LLC (Hilcorp) requested administrative approval to continue gas injection with a known inner annulus by outer annulus (IAxOA) pressure communication. In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS, subject to conditions, Hilcorp’s request for administrative approval to continue gas injection in the subject well. Hilcorp reported a potential IAxOA pressure communication to AOGCC on February 17, 2022, while the well was on gas injection. On February 10, 2022, Hilcorp performed additional diagnostics including a passing state-witnessed mechanical integrity test (MIT) of the inner annulus (to a test pressure of 3,722 psi which is greater than the anticipated gas injection pressure of 3,700 psi). This indicates that WGI-02 exhibits at least two competent barriers to the release of well pressure. Hilcorp maintains live transmitters on the inner and outer annulus and alarm functions in the Supervisory Control and Data Acquisition (SCADA) system that create layers of protection from an over-pressure event. AOGCC believes Hilcorp can safely manage the IAxOA communication with periodic pressure bleeds by maintaining the inner annulus to a pressure not to exceed 2,100 psi and the outer annulus not to exceed 1,000 psi. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 4G.015 March 21, 2022 Page 2 of 2 AOGCC’s approval to continue gas injection in PBU WGI-02 is conditioned upon the following: 1)Hilcorp shall record wellhead pressures and injection rate daily; 2)Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3)Hilcorp shall perform a MIT of the inner annulus every two years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 1,500 psi; 4)Hilcorp shall limit the well’s inner annulus operating pressure to 2,100 psi and the outer annulus operating pressure to 1,000 psi. Audible control room alarms shall be set at or below these limits; 5)Hilcorp shall monitor the inner and outer annulus pressures in real time with its SCADA system; 6)Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7)After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8)The next required MIT shall be completed before or during the month of March 2024. DONE at Anchorage, Alaska and dated March 21, 2022. Jeremy M. Price Jessie L. Chmielowski Chair, Commissioner Commissioner 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, 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 AOGCC 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 AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Date:Tuesday, February 22, 2022 9:38:11 AM Attachments:image001.png image002.png image004.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 17, 2022 5:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector WGI-02 (PTD #1790430) IAxOA communication Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) has been found to have probable slow IAxOA communication. OA pressure trends with IA pressure / temp rate swings but also has a buildup rate of ~5 psi / day. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: PPPOT-IC; OA re-pressurization test 2. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 22, 2020 9:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com> Subject: OPERABLE: Gas Injector WGI-02 (PTD #1790430) TxIA mitigated with oversized packing on SSSV Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) was made Under Evaluation on 07/03/20 to address TxIA communication. On 07/12/20 Slickline replaced the A1 Injection Valve with oversized-Freudenberg packing to mitigate communication through the control and balance lines. Follow up monitors confirm the TxIA has been mitigated and the well is now re-classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Friday, July 3, 2020 6:31 PM To: Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Jennifer Blake <Jennifer.Blake@hilcorp.com>; John Menke <jmenke@hilcorp.com>; George Ivie <givie@hilcorp.com>; David Bjork <David.Bjork@hilcorp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Patrick Bixby <Corey.Bixby@hilcorp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector WGI-02 (PTD #1790430) Slow Tubing x Inner Annulus Communication All – Injector WGI-02 (PTD #1790430) has been found to have slow tubing x inner annulus communication. IA pressure was bled on 7/1/20 from 730 psi to 290 psi and subsequent monitoring indicates ~40 psi / day build up rate with steady injection rate and temperature. The well is now classified as Under Evaluation and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Flush control / balance lines and pump GX Sealant 2. Downhole Diagnostics: Monitor IA re-pressurization 3. Well Integrity: Additional corrective action as required. A 90 day injection rate / pressure and TIO plot have been included for reference however it does not show the most recent bleed event due to network outage. Please call with any questions or concerns. Ryan Holt Hilcorp Well Integrity / Compliance 907-659-5102 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictlyprohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or useof this message and any attachments will not adversely affect its systems or data. 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'650*5'(& SVL '/% JLC 1/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.04 14:51:47 -09'00' RBDMS HEW 1/5/2022 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗t'/ͲϬϮ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϯϳϵͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶ ϭϵƚŚ͕ϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽ ƌŝůůEƵŵďĞƌ͗ϭϳϵͲϬϰϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ΕϮϯϳ͕ϬϬϬ DƐĐĨͬĂǇ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϲϯϱ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ;ƐƚŝŵĂƚĞͿ͗ϯϮϱϬ ƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ t'/ͲϬϮ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚǇ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞ ϮϬϬϱ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚǇĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďǇ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ '/% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ '/% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ '/% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, July 22, 2020 9:30 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York; Aras Worthington; Oliver Sternicki; Travis Smith - (C) Subject: OPERABLE: Gas Injector WGI-02 (PTD #1790430) TxIA mitigated with oversized packing on SSSV Mr. Wallace, Gas Injector WGI-02 (PTD # 1790430) was made Under Evaluation on 07/03/20 to address TxIA communication. On 07/12/20 Slickline replaced the Al Injection Valve with oversized -Freudenberg packing to mitigate communication through the control and balance lines. Follow up monitors confirm the TxIA has been mitigated and the well is now re- classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 m: Alaska NS - PB - Field Well Integrity Sent: iday, July 3, 2020 6:31 PM To: Bo Yo<b orkhilcor .com>; Stan Golis <sgolis@hilcoro.com>; Jennifer Blake <Jennifer.Blake Co) hilcoro.com>; John Menke <imen hilcor .com>: George Ivie <givie@hilcoro.com>; David Bjork <David.Biork@hilcoro.com>; chris.wa[lace @alas ov' <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver. rnicki hilcor .com>; Aras Worthington <Aras.Worthington@hilcoro.com>; Patrick Bixby <Corev.Bixbv@hilcoro.com>; 'jim. g@alaska.gov' <iim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector Wq 02 (PTD #1790430) Slow Tubing x Inner Annulus Communication rJIC Injector WGI-02 (PTD #1790430) has been found to have slowtubing x inner annulus communication. IA pressure was bled on 7/1/20 from 730 psi to 290 psi and subsequent monitoring indicates —40 psi / day build up rate with steady injection rate and temperature. The well is now classified as Under Evaluation and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Flush control/ balance lines and pump GX Sealant 2. Downhole Diagnostics: Monitor IA re -pressurization 3. Well Integrity: Additional corrective action as required. A 90 day injection rate / pressure and TIO plot have been included for reference however it does not show the most recent bleed event due to network outage. Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, July 3, 2020 6:31 PM To: Bo York; Stan Golis; Jennifer Blake; John Menke; George Ivie; David Bjork; Wallace, Chris D (CED) Cc: Oliver Sternicki; Aras Worthington; Patrick Bixby; Regg, James B (CED) Subject: UNDER EVALUATION: Injector WGI-02 (PTD #1790430) Slow Tubing x Inner Annulus Communication All — Injector WGI-02 (PTD #1790430) has been found to have slow tubing x inner annulus communication. IA pressure was bled on 7/1/20 from 730 psi to 290 psi and subsequent monitoring indicates -40 psi / day build up rate with steady injection rate and temperature. The well is now classified as Under Evaluation and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Flush control / balance lines and pump GX Sealant 2. Downhole Diagnostics: Monitor IA re -pressurization 3. Well Integrity: Additional corrective action as required. A 90 day injection rate / pressure and TIO plot have been included for reference however it does not show the most recent bleed event due to network outage. Please call with any questions or concerns. Ryan Holt Hilcorp Well Integrity/ Compliance 907-659-5102 SB{1 t :IYM) IALl 1601+ 260 J_lXyl'r �� • af:d '� � Lilsmcl iC4> 1 Nox a 80p ♦ ., Lva L' a exon MAN ♦!- MAN IA a 4CK} MAN [Sa ♦ MAN O� Iu%) GOU 400 - 2Ua: SB{1 360 IALl 260 �� • af:d '� � Lilsmcl 1 Nox 1�0 ,_ ♦ ., Lva L' MAN ♦!- MAN IA MAN [Sa ♦ MAN O� 40 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Friday, July 13, 2018 i'� P.I. Supervisor !� , -7' ( 7 I I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. WGI-02 FROM: Guy Cook PRUDHOE BAY UNIT WGI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry is -Z -- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-02 API Well Number 50-029-20379-00-00 Inspector Name: Guy Cook Permit Number: 179-043-0 Inspection Date: 7/6/2018 Insp Num: mitGDC180706145431 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well �- WGI-02 Type Inj G ' TVD 7541 Tubing 3426 3426 3423 3422 PTD - 1790430 (Type Test SPT ITest psi 1885 IA 748 2498 2469 2472 ` BBL Pumped: 21 BBL Returned: 2.1 OA 77 77 79 80 Interval] aYRTST p/F P Notes: A triplex pump and bleed trailer were used for testing. - SCANNED AUG U 9 LWb Friday, July 13, 2018 Page 1 of 1 Well Name PRUDHOE BAY UNIT WGI-02 API Well Number 50-029-20379-00-00 Inspector Name: Matt Herrera Permit Number: 179-043-0 Inspection Date: 7/5/2018 Insp Num: mitMFH180705145822 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-02 Type In G 'TVD 7541 Tubing 338384 3383 3383 3408 -- ---------- — PTD 1790430 Type TBst� SPT Test psi 1885 IA 27 i 2499 2473 2488 2520 l-_ --- 4 B4 OA 69 67 70 71 BBL Pumped__BL Returned: 3. 71 _. _ ---� --- i- — - � Interval 1 4YRTST JP/F 1 Notes: IA tested to 2500 PSI Per operator Unable to obtain conclusive test on IA due to unstable injection rates and possible gas in IA SCA, rWDAUG 1W10 Thursday, July 05, 2018 Page 1 of I • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, July 05, 2018 P.I. Supervisor�f5 �► �'► J SUBJECT: Mechanical Integrity Tests // BP EXPLORATION (ALASKA) INC. WGI-02 FROM: Matt Herrera PRUDHOE BAY UNIT WGI-02 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry �J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-02 API Well Number 50-029-20379-00-00 Inspector Name: Matt Herrera Permit Number: 179-043-0 Inspection Date: 7/5/2018 Insp Num: mitMFH180705145822 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-02 Type In G 'TVD 7541 Tubing 338384 3383 3383 3408 -- ---------- — PTD 1790430 Type TBst� SPT Test psi 1885 IA 27 i 2499 2473 2488 2520 l-_ --- 4 B4 OA 69 67 70 71 BBL Pumped__BL Returned: 3. 71 _. _ ---� --- i- — - � Interval 1 4YRTST JP/F 1 Notes: IA tested to 2500 PSI Per operator Unable to obtain conclusive test on IA due to unstable injection rates and possible gas in IA SCA, rWDAUG 1W10 Thursday, July 05, 2018 Page 1 of I STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMM! REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 179-043 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20379-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU WGI-02 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: q Total Depth: measured 9655 feet Plugs measured feet 1 y E D true vertical 8667 feet Junk measured 9556 feet Effective Depth: measured 9607 feet Packer measured 8277 feet DEC 10 2015 true vertical 8628 feet Packer true vertical 7544.33 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 82 20"94#H-40 32-113 32-113 1530 520 Surface 2703 13-3/8"72#N-80 31 -2734 31-2734 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1304 7"29#N-80 8349-9653 7606-8666 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker FB-1 Packer 8277 7544.33 true vertical depth) 7"Camco WRDP-2 SSSV 2199 2198.95 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: O FEB08A T, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 200340 200 3505 Subsequent to operation: 220141 60 3531 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ a SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 12/9/15 t RBDMS 1kt; Form 10-404 Revised 5/2015 v T L 1Z/23//5 `U 1 5 2015 /� _ // �/ Submit Original Only ' (r72ge , • • a) Q 0 0 0 0 0 0 0 0 R N N- CO CD N .- CO O CD O N- O t N Lf) 0 N LO V N- Ln O N- U 0 0 0 0 0 0 0 0 Va. CO CO L() N- CO d' V' co Lf) O CO c- N N N- 00 CO Mc CO co CD N- CO CO00 CD LO LO CO N I- CO N- r` H CD f� N CA <- O N- CO CO CO CO N CO CD N 10 L1) N r-- (1) -a, ch d" ,- Lf) M CO LO Cy,N- CO CD CO N N CO N N CO O) CO CO CO a jN m 1 1 1 I +J O Q _ ,- CD (p LO N O) N- CD O) CO CO N CO CO N N N _ N CO CO CO \ ac0 O O i (b O O QO Do vZOZaoco J -� asI (NI* 4t C O QO 00 CV (N1 CV CV O CO 00 lC) I i c-- O) L +-. CO N Vr N Cr)N O CO CD O V N- CA C CO N- N CO CO N N (A J N N O N- CO L.1.1 w — — Cw 0 0 •NUUww U o w c D n Z Z Z Z w w w m m E O D H H Z » J U (/) ZZ7HHH • • m . 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O co e * « m m I ! — o 2 to r \ / \ \ � \ \ TREE= 6-3/8"01W SF*NOTES: ViELL REQUIRES A SSSV ***NEEDED AELLJ-EAD= GRAY WGI-02 ERGENCY FIELD FUEL GAS ACTUATOR= BAKER C B_EV= 49' f3F.REV= "K-CiP 31-00 Max Angie= 37 9000' 2199' H7'CAM SAL-0 SSSV NIP,0=5.937" I *.d, Datum MD= NI A Datum TVI3= 8800'SS 13-3/8'CSG,72#,N-80,0=12.347" H 2731' Minimum ID = 3.725" @ 8380' 4-1/2" OTIS XN NIPPLE 7"TBG-PC,26#,L-80,.0383 bpf,U=6.276" H 7583' 8265' —171X 5-1/21 X0, =4.892" 6, 7'TBG,29#,N-80,.0371 bpf,ID=6.184' H 8265' WI BKR LOCATOR SUB 5-1/2 TBG, 17#,L-80 AB-M, 8273' 827T 1-17.5'SEAL BORE EXTENSION, =6.00" .0232 bpf,ID=4.892' 8286' H7-5/8"MLLOIJT IXTENSION, =7.00 8292' —7-5/8"X 4-1/2"XO, =3.958' TOP OF 7"LNRH 8346' 111 I I 8379' —14-1/2"OT TS XN N13,13=3.725" 8390' —14-1/2"BKR SHEAROUT SUB,ND=4.125' 4-1/2'TBG,12.6#,L-80 BTC, —1 8391' 8391' H4-1/2"TUBING TAL,13=3.958- .0152 bpf, =3.958" H ELMO TT NOT LOGGED 9-5/8"CSG,47#,N-SO,C=8.681" H 8671' —4 PERFORATION SUMVARY FEE LOG:CH 04_ON 08/31/79 ANGLEAT TOP PEW:37 @9056 Note:%fer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE For Perforation Data,see page 2 — EP STFFEWR RUBBER(-1"X In ( PB1D H 960T 06/19/15) 7"LNR,29#,N-80,.0371 bpf,ID=6.184" 9650' DATE FEV BY COMMENTS DATE REV BY COMMENTS FRUDI-CE BAY UNIT 09/03/79 ORIGINAL COMPLETION 06/04/15 PJC TREE CORRECTIONS WELL: WGI-02 05/15/89 RWO 07/02/15 DJS/JMD SET FISH(06/19/15) PERMIT No: '1790430 11/03/01 RNITP CORRE-CTIONS 12/03/15 CJS/TLH PEW(11/09/15) AFC: 50-029-20379-00 11/19/07 DSM/PJC 114EL CORRECTION SEC 11,711N,R14E,376'FPI_& 1184'Fa 04/02/10 DC/M) SAFETY NOTE UPDATE 02/11/11 143/JMID A DOED SSSV SA FEI Y NOTE BP Ex ploratim(Alaska) • WG 1-02 # r • L PERFORATION SiARY REF LOG:CH GtL ON 08/31/79 ANGLE AT TOP PERF:37 @ 9056' Note:Refer to Roduction DB for historical perf data . . SIZE SPF t1TB AL Opn/Sqz SHOT SQZ 33/8" 4 9056-9076 0 08/12/80 I I 3-3/8" 4 9082-9092 0 05/26/87 3-3/8" 4 9096-9106 0 08/12/80 3-3/8" 4 9126-9146 0 08/12/80 3-3/8" 4 9146-9166 0 05/26/87 / 3-3/8" 4 9166-9196 0 08/12/80 3-3/8" 4 9196-9216 0 05/26/87 3-3/8" 6 9206-9296 0 11/09/15 3-3/8" 4 9216-9246 0 08/12/80 3-3/8" 4 9246-9266 0 05/26/87 3-3/8" 4 9266-9296 0 08/12/80 I k 3-3/8" 4 9310-9316 0 05/26/87 3-3/8" 4 9324-9344 0 08/12/80 3-3/8" 4 9344-9364 0 05/26/87 3-3/8' 4 9364-9384 0 08/12/80 3-3/8" 4 9384-9410 0 05/26/87 3-3/8" 4 9410-9430 0 08/12/80 3-3/8" 4 9430-9442 0 05/26/87 3-3/8" 4 9454-9484 0 08/12/80 ..2.1.12.111il.rxi 3-3/8" 4 9492-9497 0 05/26/87 3-3/8" 4 9502-9512 0 08/12/80 ATE FEV BY COM ENTS DATE REV BY OOMIVB'ITS PRtDHOE BAY LII 09/03/79 ORIGINAL COMPLETION 06/04/15 PJC I Fd E CORRECTIONS S WW WGI-02 05/15/89 FANO 07/02/15 DJS/JhD SET ASH(06/19/15) F$?MT No: '1790430 11/03/01 IWP CORRECTIONS ECT10t' 12/03/15 CJS/TLH PERF(11/09/15) AR No: 50-029-20379-00 11/19/07 DSM/PJC TREE CORRECTION SEC 11,T11N,R14E,376'RC&1184'FEL 04/02/10 DC/JM) SAFETY NOTE(JtTE 02/11/11 MB/JM) ADDED SSSV SAFETY NOTE BP Exploration(Alaska) 1 OF Ty, ,,w��\\1%%i ,v THE STATTE Alaska Oil and Gas w.+-�s _ � of/�, i\ SIIKj\ Conservation Commission • tiV _- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 { 20'6 Anchorage, 907 279,1 433 OF ALAS‘'' C© OMFax. 907.276 7542 S`AR� www.aogcc alaska gov Spencer Morrison �/`'j�Petroleum Engineer lin- " BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-02 Sundry Number: 315-247 Dear Mr. Morrison: 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, , /-.(4,0/1"`— Cathy . Foerster Chair DATED this4day of May, 2015 Encl. RECEIVED APR 2 3 205 ' • STATE OF ALASKA CJS 5164/)•S ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request. Abandon El Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program CI Suspend Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Water Wash 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 179-04.3-0 • 3.Address 'Stratigraphic ❑ Service 0• 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20379-00-00 • 7.If perforating: 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-02 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028302 • PRUDHOE BAY,_PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9655 . 8667 • 9607 8628 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20"94#H-40 31.75-113.25 31.75-113.25 Surface 2703 13-3/8"72#N-80 31.25-2734 23 31.25-2734.18 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1304 7"29#N-80 r 8348.99-9653.25 r 7605.6-8665.64 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft). See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0. 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/10/15 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. WINJ ❑ GINJ 0. WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Spencer Morrison Email Spencer.Morrison@BP.Com Printed Name Spencer Morrison Title Petroleum Engineer Signature $2 •-----191-- - Phone 564-5773 DateLi/2_271s_ Prepared by Gany Catron 564-4424 � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I C - 2-14-1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No R/ Subsequent Form Required. X —46 `[ APPROVED BY _ Approved by: � COMMISSIONER THE COMMISSION Date. rc-'4- -t S at/fir-7 4/30`i,5" Form 10-403 Revised 10/2012 O R IAGotep AL is valid for 12 months from the date of approval. Submit Form and Attac ments in Duplicate RBDMSX MAY - 6 2015 , yY22 /,3 10 0 0 0 0 0 0 0 0 co q w 0 Oo Oo CO CO CO Ur S Z O Z Z J J J a) Q 0 0 0 0 0 0 0 (B N CO 00 N N- — O CO —• , r O O Co Cf) N t 10 r N L0 N- CO U ) 0 0 0 0 0 0 0 0 () N- Cf) CO CO 't CO "Cr 3 Ln CO — — 6) N m N— CO co co N- CO N- a) (n (6 co — Co V N- O m • N s— CO CO CO NY CO CO r) CO co Co co N- N 00 N H CZ o S CO O H CV (A 0 N— N- CO CO O CO CO N CO CO C Cf) Ln H (B N E O a) ThIm N 10 r) co CA 0) co 0 ' co N 0)) N 100 00 CO � p 2 C J •— (z 0 (a H N x O v I— o 10 U a (h CO N 00 CO N N N N CO CO 00 O O C i CO CO ) 0 CO O ' O J co OC° Zoo a) S 4 W Z N J ( *k CA O ' OO N M N N N tl) ~ r) 11) (A V d) N V CO N ZT N CO CO O O d' C) N- C CO CO N CO N- N 0) N a) CO N N CO W W Q Q C• H 0 W (7) U W W U O o c c 1 Z Z Z Z W W W iX m m m O H Z D D D D U Z Z J U) H H H Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base WGI-02 8/12/80 PER 9056 9076 8186 8202 WGI-02 5/26/87 APF 9082 9092 8207 8215 WGI-02 8/12/80 PER 9096 9106 8218 8226 WGI-02 8/12/80 PER 9126 9146 8242 8258 WGI-02 5/26/87 APF 9146 9166 8258 8274 WGI-02 8/12/80 PER 9166 9196 8274 8298 WGI-02 5/26/87 APF 9196 9216 8298 8314 WGI-02 8/12/80 PER 9216 9246 8314 8338 WGI-02 5/26/87 APF 9246 9266 8338 8354 WGI-02 8/12/80 PER 9266 9296 8354 8378 WGI-02 5/26/87 APF 9310 9316 8389 8394 WGI-02 8/12/80 PER 9324 9344 8400 8416 WGI-02 5/26/87 APF 9344 9364 8416 8432 WGI-02 8/12/80 PER 9364 9384 8432 8448 WGI-02 5/26/87 APF 9384 9410 8448 8469 WGI-02 8/12/80 PER 9410 9430 8469 8485 WGI-02 5/26/87 APF 9430 9442 8485 8495 WGI-02 8/12/80 PER 9454 9484 8505 8529 WGI-02 5/26/87 APF 9492 9497 8535 8539 WGI-02 8/12/80 PER 9502 9512 8543 8551 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top WGI-02 PACKER 8221 7" Baker SB-2 Packer 7497 WGI-02 PACKER 8277 7-5/8" Baker FB-1 Packer 7544 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: WGI-02 Well Type: Gas Injection Well API Number: 50-029-20379-00 Well Activity Conventional 4 Classification: Activity Description: Water wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: Other regulatory AWGRS Job Scope: TUBING WASH/PICKLE None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Spencer Morrison Contact numbers: (907) 564-5773 (713) 557-281 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Chris Stone Contact numbers: (907) 564-5518 (907)440-401 Date Created: April 6, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injectic Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 4/5/2015 215,805 3,524 Current Status: Operable Flowing Inclination>70°at Depth (ft) Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 37° 9,000' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 5° 3,000' MD Reservoir pressure(date, psig) 3,400 psi Minimum ID and Depth 3.725"Q 8,380' Reservoir Temp,F 130° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity None Currently. Passing PPOT T and IC on 8/7/14. Passing MITxIA to 2500 psi on 7/6/14. problems(specifics) Last downhole operation (date, operation) 8/6/2014 Caliper to TD, Sample of schmoo Most recent TD tag (date,depth, 8/5/2014 9,557' MD 3.5"Centralizer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, WGI-02 had an unsuccessful water wash on 6/06/2005 where 614 bbls of FW at 140E with .02% F-103 background information, surfactant at a rate of 5 BPM.The injectivity plot pre and post wash can be seen at the end of this etc: program. It has been nearly 10 years since this wash,there is likely an organic buildup since the last intervention. i nis wE. _.so naa a caliper on oio/Lu i4. in me caliper report we perrorauons are aescnoea as naving'grit to heavy deposits in some areas restricting the ID to 4.87". This summer there will be an NGI restoration project that will include significant down time for the NGI wells. I have included the tentative schedule below.To reduce the impact of having the NGI wells shut in for work,water washes are needed on good candidates on AGI and WGI. NGI Restoration schedule: 1.Well lateral line work starts April 15 when we will take 2 NGI wells down at a time for repairs lasting 7-9 days per set. We will start with wells 13/14 and work south until complete with pre-TAR scope. 2. Starting on June 26th we will take down NGI wells 1-12 to support blinding and repairs in the vicinity of FV6302/6203 for 9 days-This is outage one. 3. Following outage one and roughly on July 4th we will restart NGI wells 8-12 (13 and 14 were already on line)and wells 1-7 will remain down for approximately 30 days for outage 2. 4. Following completion of outage 2 we will restart wells 1-7 and take down NGI wells 8-14 and begin repairs on the north end of NGI headers/laterals. This is outage 3 and duration is roughly 30 days. 5. Following outage 3 we will need to restart NGI wells 11-14 and take down NGI wells 1-10 to allow for blind removal at FV6302/6203. This is outage 4 and I estimate 2 days for this outage. 6. Finally we then will restart all of the NGI pipelines and wells that were down for blind removal and be back to normal with repairs in place. This is the base schedule and if we find additional corrosion damage the extends our scope of work then we could have some wells off line for longer duration. If the water washes go to plan, we will improve injectivity by dissolving salts and possibly asphaltenes in v the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectivity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1 Pump Water Wash as per attached template 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= 6-3/8"CIW SI(NOTES: WELL REQUIRES A SSSV. WELLHEAD= GRAY WGI-02 fI-O2 -. _JED FOR EMERGENCY FIELD FUEL GASB'** ACTUATOR= BAKER KB.ELEV= 49' BF.ELEV= KOP= 3100' JI Max Angle= 37 @ 9000' 2199' —17"CAM BAL-O SSSV NIP, ID=5.937" Datum MD= N/A Datum TVD= 8800'SS 13-3/8"CSG,72#,N-80, ID=12.347" —i 2731' Minimum ID = 3.725" @ 8380' 4-1/2" OTIS XN NIPPLE 7"TBG-PC,26#,L-80,.0383 bpf, ID=6.276" —I 7583' X 8265' --17"X 5-1/2"XO, ID=4.892" 7"TBG,29#,N-80, .0371 bpf,ID=6.184" —I 8265' 8273' 19-5/8"X 5-1/2"BKR FB-1 PKR,ID=6.00" w/BKR LOCATOR SUB 5-1/2 TBG, 17#,L-80 AB-M, — 8273' 8277' —17.5'SEAL BORE EXTENSION,ID=6.00" .0232 bpf,ID=4.892" $286' 7-5/8"MILLOUT EXTENSION, ID=7.00 8292' —17-5/8"X 4-1/2"XO,ID=3.958" TOP OF 7"LNR — 8346' ' ' 8379' H4-1/2"OTIS XN NIP, ID=3.725" l 8390' —14-1/2"BKR SHEAROUT SUB, ID=4.125" 4-1/2"TBG, 12.6#,L-80 BTC, —I 8391' I / 8391' —14-1/2"TUBING TAIL, ID=3.958" .0152 bpf,ID=3.958" —ELMD TT NOT LOGGED 9-5/8"CSG,47#,N-80,ID=8.681" —I 8671' PERFORATION SUMMARY REF LOG:CH CNL ON 08/31/79 ANGLE AT TOP PERF:37 @ 9056' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sqz I DATE For Perforation Data,see page 2 , PBTD —I 9607' ' 7"LNR,29#, N-80,.0371 bpf, ID=6.184" —I 9650' *00000004 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/03/79 ORIGINAL COMPLETION WELL: WGI-02 05/15/89 RWO PERMIT No: 1790430 11/03/01 RN/TP CORRECTIONS API No: 50-029-20379-00 11/19/07 DSM/PJC TREE CORRECTION SEC 11,T11 N, R14E,4027.88 FEL 3816.97 FNL 04/02/10 DC/JMD SAFETY NOTE UPDATE 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) f WGI-02 . 1 PERFORATION SUMMARY REF LOG:CH CNL ON 08/31/79 ANGLE AT TOP PERF:37 @ 9056' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9056-9076 0 08/12/80 3-3/8" 4 9082-9092 0 05/26/87 3-3/8" 4 9096-9106 0 08/12/80 3-3/8" 4 9126-9146 0 08/12/80 II III 3-3/8" 4 9146-9166 0 05/26/87 ' ' 3-3/8" 4 9166-9196 0 08/12/80 3-3/8" 4 9196-9216 0 05/26/87 3-3/8" 4 9216-9246 0 08/12/80 3-3/8" 4 9246-9266 0 05/26/87 / 3-3/8" 4 9266-9296 0 08/12/80 3-3/8" 4 9310-9316 0 05/26/87 3-3/8" 4 9324-9344 0 08/12/80 3-3/8" 4 9344-9364 0 05/26/87 3-3/8" 4 9364-9384 0 08/12/80 3-3/8" 4 9384-9410 0 05/26/87 A , 3-3/8" 4 9410-9430 0 08/12/80 3-3/8" 4 9430-9442 0 05/26/87 3-3/8" 4 9454-9484 0 08/12/80 3-3/8" 4 9492-9497 0 05/26/87 I 3-3/8" 4 9502-9512 0 08/12/80 I I I I I I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/03/79 ORIGINAL COMPLETION WELL: WGI-02 05/15/89 RWO PERMIT No: r1790430 11/03/01 RN/TP CORRECTIONS API No: 50-029-20379-00 11/19/07 DSM/PJC TREE CORRECTION SEC 11,T11N, R14E,4027.88 FEL 3816.97 FNL 04/02/10 DC/JMD SAFETY NOTE UPDATE 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 25, 2014 TO: Jim Regg p SUBJECT: Mechanical Integrity Tests ,c� f� t/�(� P.I. Supervisor ( f BP EXPLORATION (ALASKA) INC WGI-02 FROM: Johnnie Hill PRUDHOE BAY UNIT WGI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry --J_r5f_— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-02 API Well Number 50-029-20379-00-00 Inspector Name: Johnnie Hill Permit Number: 179-043-0 Inspection Date: 7/6/2014 Insp Num: mitJWH140706162335 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-02 Type Inj C' TVD 7541 - IA 131 2510 - 2494. 2486 - PTD i -- 1790430 Type Test Test p�85 O A 107 120, 129 133 - — — nterval 4YRTST P/F P TUbin 3494 3495 3493. 3494 - -- --- 1885 OA g - - -- Notes: 3.8 bbls meth used SCANNED OCT 3 0 2014 Friday, July 25, 2014 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg Z� '1 DATE: Wednesday, August 21, 2013 P.I. Supervisor 5 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-02 FROM: Jeff Turkington PRUDHOE BAY UNIT WGI-02 Petroleum inspector Src: Inspector ReviewedB P.I. SuprvJtp-- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-02 API Well Number 50-029-20379-00-00 Inspector Name: Jeff Turkington Insp Num: mitJAT130816095351 Permit Number: 179-043-0 Inspection Date: 8/15/2013 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-02 Type Inj G TVD 7541 IA 159 2518 2526 2532 2530 PTD 1790430 Type Test SPT Test psi 1885 OA 7 5 8 10 12 - Interval 4YRTST P/F P Tubing 3475. 3509 3508 3506 3507 - --- - Notes: 8.7 bbl methanol to fill. Wednesday, August 21, 2013 Page 1 of 1 Brooks, Phoebe L (DOA) PTD tk 1 Z2&3o From: Brooks, Phoebe L (DOA) Sent: Tuesday, August 20, 2013 11:48 AM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Packer TVD PRUDHOE BAY UNIT WGI-02 PTD #1790430 Will you also do the same for PRUDHOE BAY UNIT AGI -02 PTD #1921200? Thanks, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Brooks, Phoebe L (DOA) Sent: Tuesday, August 20, 2013 11:46 AM To: 'AK, D&C Well Integrity Coordinator' Subject: Packer TVD PRUDHOE BAY UNIT WGI-02 PTD #1790430 Laurie/Jack, Can you send me the schematic for this well? I received a report from Jeff Turkington that included a different Packer TVD then we had in our database so I wanted to check the figures. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 SCANNED 0 C T 1 3 2014,' 1 TREE = 6-3/8" CIW MEL HEAD - ACTUATOR -= GRAY B BAKER KB. ELEV = 49' BF. REV= 8273' 9-5/8" X 5-1/2" BKR FB -1 PKR, ID = 6.00" KOP = 3100' Max Angle = 37 @ 9000' Datum MD = Datum TV D-- N/A 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" 2731' Minimum ID = 3.725" @ 8380' 4-1/2" OTIS XN NIPPLE 7" TBG -PC, 26#, L-80, .0383 bpf, ID = 6.276" 7583 W G' _0 2 SAFETY NOTES: WELL REQUIRES A SSSV. ... NEEDED FOR EM ERGENCY FIELD FUEL GAS*** w 99' ri 7" CAM BAL-O SSSV NIP, ID = 5.937" TOP OF 7" LNR I—I 8346' 8379' —i4-1/2" OTIS XN NIP, ID = 3.725" 8390 4-1/2" BKR SHEAROUT SUB, ID - 4.125" 4-1/2" TBG, 12.6#, L-80 BTC, 8391' 8391 4-1/2" TUBING TAIL, ID = 3.958" .0152 bpf, ID = 3.958" ELMD TTNOT LOGGED 9-5/8" CSG, 47#, N-80, ID = 8.681" I—{ 8671 PERFORATION SUMMARY REF LOG: CH CNL ON 08/31/79 ANGLE AT TOP PERF: 37 @ 9056' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sqz I DATE For Perforation Data, see page 2 u—I 9bUT 7" LNR, 29#, N-80_0371 bpf, ID = 6.184" 9650 DATE REV BY 8265 —�7" X 5-1/2" XO, ID = 4.892" 7" TBG, 294, N-80, .0371 bpf, ID = 6.184" $265' 8273' 9-5/8" X 5-1/2" BKR FB -1 PKR, ID = 6.00" 05/15/89 w / BKR LOCATOR SUB 5-1/2 TBG, 17#, L-80 AB -M, 8273' RN/TP 8277 7.5' SEAL BORE EXTENSION, ID = 6.00" .0232 bpf, ID = 4.892" DSM/PJC TREE CORRECTION 82$6' 7-5/8" MILLOUT EXTENSION, ID = 7.00 DC/JMD I SAFETY NOTE UPDATE $292' 7-5/8" 74-1/2- XO, ID = 3.958" TOP OF 7" LNR I—I 8346' 8379' —i4-1/2" OTIS XN NIP, ID = 3.725" 8390 4-1/2" BKR SHEAROUT SUB, ID - 4.125" 4-1/2" TBG, 12.6#, L-80 BTC, 8391' 8391 4-1/2" TUBING TAIL, ID = 3.958" .0152 bpf, ID = 3.958" ELMD TTNOT LOGGED 9-5/8" CSG, 47#, N-80, ID = 8.681" I—{ 8671 PERFORATION SUMMARY REF LOG: CH CNL ON 08/31/79 ANGLE AT TOP PERF: 37 @ 9056' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sqz I DATE For Perforation Data, see page 2 u—I 9bUT 7" LNR, 29#, N-80_0371 bpf, ID = 6.184" 9650 DATE REV BY COMMENTS DATE I REV BY COMMENTS 09/03/79 ORIGINAL COMPLETION 05/15/89 RWO 11/03/01 RN/TP CORRECTIONS 11/19/07 DSM/PJC TREE CORRECTION 04/02/10 DC/JMD I SAFETY NOTE UPDATE 02/11/11 MB/JMD I ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: WGI-02 PERMIT No: Pl790430 API No: 50-029-20379-00 SEC 11, T11N, R1 4E, 4027.88 FEL 3816.97 FNL BP Exploration (Alaska) WGI-02 PERFORATION SUMMARY REF LOG: CH CNL ON 08/31/79 ANGLE AT TOP PERF: 37 @ 9056' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9056-9076 O 08/12/80 3-3/8" 4 9082-9092 O 05/26/87 3-3/8" 4 9096-9106 O 08/12/80 3-3/8" 4 9126-9146 O 08/12/80 3-3/8" 4 9146-9166 O 05/26/87 3-3/8" 4 9166-9196 O 08/12/80 3-3/8" 4 9196-9216 O 05/26/87 3-3/8" 4 9216-9246 O 08/12/80 3-3/8" 4 9246-9266 O 05/26/87 3-3/8" 4 9266-9296 O 08/12/80 3-3/8" 4 9310-9316 O 05/26/87 3-3/8" 4 9324-9344 O 08/12/80 3-3/8" 4 9344-9364 O 05/26/87 3-3/8" 4 9364-9384 O 08/12/80 3-3/8" 4 9384-9410 O 05/26/87 3-3/8" 4 9410-9430 O 08/12/80 3-3/8" 4 9430-9442 O 05/26/87 3-3/8" 4 9454-9484 O 08/12/80 3-3/8" 4 9492-9497 O 05/26/87 3-3/8" 4 9502-9512 O 08/12/80 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/03/79 ORIGINAL COMPLETION 05/15/89 RWO 11/03/01 RN/TP CORRECTIONS 11/19/07 DSM/PJC TREE CORRECTION 04/02/10 DC/JMD I SAFETY NOTE UPDATE 02/11/11 MB/JMD I ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: WGI-02 PERMIT No: 1790430 API No: 50-029-20379-00 SEC 11, T11N, R1 4E, 4027.88 FEL 3816.97 FNL BP Exploration (Alaska) MEMORANDUM To: Jim Regg `~j~ P.I. Supervisor ~ ~ ~ "~ I3~~.u ~' FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC WGI-02 PRUDHOE BAY UNIT WGI-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: i, P.I. Suprv J~ Comm Well Name: PRUDHOE BAY UNIT WGI-02 API Well Number: s0-029-20379-00-00 Inspector Name: Bob Noble mitRCN1008091633s2 Insp Num: Permit Number: 179-043-0 Inspection Date: 8/s/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well wGI-oi Type Inj. I G TVD 7sal IA aso zsoo - ( zsoo zsoo P.T.D I79oa3o TypeTest SPT Test psi zsoo ~ OA zto zao zao zao I Interval aYRTST p~F P ~ Tubing 3330 3330 3330 3330 Notes: ~ i ~ ~-~ ~ ~~ -~2 S~' 1 `~v'~5 ~ r Tuesday, August 10, 2010 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ."-' i /~/ 1,/-"/,,,,]· r(é /) j i,., /)1 ·<-If yo. -I .~, -..... DATE: Tuesday, August 01,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI·02 PRUDHOE BAY UNIT WGI·02 a ,ot.i'3 \1 \ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ?'~1r P.I. Suprv._J ,:;;¡¿- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT WGI-02 Insp N urn: mitCS06080 I 06 I 722 Rei Insp Num Permit Number: 179-043-0 Inspector Name: Chuck Scheve Inspection Date: 7/31/2006 API Well Number 50-029-20379-00-00 Packer Depth Pretest Initial 15 Min. Well i WGI-02 ¡Type Inj. ! G I TVD '~;7545!~-~'I25ï(): P.T. , 1790430 ¡TypeTes! I SPT I Test psi;. 1886.25 I OA I 700 I 740 . /' T b' I 3500 ¡ 3500 Interval 4YRTST P/F P </ U mg; 2520 30 Min. 45 Min. 60 Min. 2520 I I I '--~---r--~~-- 740 740 3500 3500 J._~_ Notes Preteat pressures were observed and found stable. Well demonstrated good mechanical integrity. "'f"o~ ~1Jl.1!":.'T ~VI~i ~r·~'¡:;;"·1 "" ~~¡ G ¡ . Tuesday, August 0 I, 2006 Page I of I MEMORANDUM TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 1, 2002 SUBJECT: Mechanical Integrity Tests BPX WGI 02,03,05 & 08 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI WGI-02 I Type,ni.I ~ I~'v'o' I 7545 JTubingl 3550l 35501 3550l 3550 I lntervall 4 P.T.D.I 1790430 ITypetestl P ITestpsil 1887 I CasingI 470 I 2490 I 2475 I 24~0 I PIE I _.P Notes: 'we,I w~,-o~ ~'ni-! G !~'~'D' I~ I~u~,n~ I~° I ~ I' ~0 I ~0 I,n~e~a,I ~ P.T.D.I 1790490 Typetestl ' P IT~tpsii 1814 I Casingl 350 I 2190 I 2175 I 2175 I P/F I _~ Notes: Monitored ~ressure for one hour to confirm stabilization. we,,I WG,-05 Type,nj.I G. I T.V.D. 17800 J Tubingj3550 13550 I ~550 I ~o I,nterva, I 4 P.'I:.D.I 1900250 TypetestI .P ITesti~sil 19,50 I Casingl 220 I 206O I 2O6O I 20O0 I PIE I -~ Notes: Monitored }ressure for 45 minutes to confirm stabilization. WellI WGI-08 Type lnj.I G J T.V.D. I 7660 I Tubin~ll 3550 I 3550 I ~0 I~0 I lntervall 4 P,.T.D.I 1900490 TypetestI P, ITestpsil 1915 I CasingI 400 I 2560 I 2550 I 2540 I PIF I g Notes: Insignificant pressure loss of 20 psi. after 30 minutes. WellI I~,,e,nj. J I ~.v.o. IITubingI I I I I lntervall P'T'D'I ITypetestl , ITestpsil I casing l 'I ' I , I IP/FI Notes: Type INJ. Fluid Codes F = FRESH WATER tNJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field to witness MIT's on WGI Pad. WGI-03 had starting pressure of 2550 psi. The first 20 minutes of 03's test the pressure dropped from 2550 to 2320 psi. The last 10 minutes of03's test the pressure dropped from 2320 psi to 2190 psi. The Operator asked ifI wanted to increase pressure back to 2500 psi on 03. I requested the Operator to monitor 03% test for another 30 minutes, w/o re-pressuring, to verify stabilization. The test pressures are recorded on the test form above. I witnessed no change on 05 until I tapped on the gauge after 30 minutes. I verified stabilization by witnessing no change in 05's pressure fi'om 30 to 45 minutes. M.I.T.'s performed: 4 Attachments: Number of Failures: _0 Total Time during tests: ,3 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU WGI 06-01-02jcl.xls 614/02 Alaska Oil and Gas COnservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field WGI Pad Separator psi: LPS HPS 1/15/01 3400 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE WGI-01 1790310 3400 2900 2440 P P P GINJ WGI-02 ~!'.1790430 3400 2900 2650 P P P GINJ WGI-03 1790490 3400 2900 2350 P P P GINJ WGI-04 1790500 3400 2900 2350 P P P GINJ WGI-05 1900250 3400 2900 2500 P P P GINJ WGI-06 1900300 3400 2900 2460 P 4 9 GINJ WGI-07 1900400 3400 2900 2480 P P P GINJ WGI-08 1900490 3400 2900 2620 P P P GINJ Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% [390 Day Remarks: WGI-07 Shut in untill repaired & re-tested. I /1 Oft'Il D,-,t~ta I ,-,,C 1 q'lq DT:tT T XXIF'.T Parl 1_1 q_(~li~- MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission Julia Heusser, '~- DATE: January 15, 2000 COmmissioner Tom Maunder, P. I. Supervisorb\, - FROM: SUBJECT: John CrisP~ Petroleum InsPector Safety Valve Tests Prudhoe Bay Field WGI Pad January 15, 2001' I traveled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad. BP representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a Safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valVes failed to hold DP. This well was shut in until rePaired & re-teSted, The AOGCC test report is attached for reference. I inspected Wellhouses on WGI Pad during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 wells, 24comPonents tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspected. Attachments: SVS PBU WGI Pad 1-15-01jc cc; NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-01jc.doc ARCO Oil and Gas Company Instructions: Prepare and submit the "ll~lflll liel~d" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ' Daily District ICounty. parish or borough Auth. or W.O.['ln~.. Operator Spudded or vv~b~.~"gun IDate I Date and dep~'*'''''~' Complete record for each day reported as of 8:00 a.m. AUDi 4 IStat I Well no. w.o. 04/30/89 TD= 9655 PB: 9607 SUPV:BB 05/01/89 ( /q:): 9655 PB: 9607 SUPV:BB 05/02/89 ( TD: 9655 PB= 9607 SUPV:BB 05/03/89 ( :) TD: 9655 PB: 9607 SUPV:BB 05/04/89 ( TD: 9655 PB: 9607 SUPV:RJB The above ia correct Signature, S. ~,, ~ ~or [arm preparation and distribution, sac Procedures Manual, Section ,Drilling. Pages 86 and 87. PREP TO KILL WELL MW:10.8 CACL MOVE RIG FROM 9-38 TO WGI-02. ACCEPT RIG 0 0230 HRS 04/30/89. RO CHOKE AND KILL LINES TO TREE AND TEST TO 5000 PSI. DAILY:S35,201 COM:$35,201 ETD:S35,201 EFC:$1,012,000 RU E-LINE ~MW: 8.9 NACL TEST SURFACE LINES AND RU LUBR. PULL BPV. SITP - 2000 PSI, SICP - 2800 PSI. BLED ANN TO 0 PSI. BULLHEAD 500 BBLS SEAWTR DOWN TBG. POMPED 50 BBL TEMBLOK PILL AND DISPL W/SEAWTR. SAW PHESS INCR FROM 200 TO 275 PSI WHEN PILL HIT PERFS. WAIT 2 HRS F/PILL TO SET UP. SITP INCR FROM 0 TO 525 PSI. PMPD 50 BBL TEMBLOK AND DISPLACED W/9.2 PPG NACL. WELL ON VACUUM. REDUCE BRINE WT TO 8.9 PPG. POMP 100 BBL TEMBLOK PILL AND DISPLACED W/8.9 PPG NACL. HESITATE SQZ PILL INTO PERFS. OBSERVE WELL. RU WESTERN ATLAS. DAILY=S73,907 CUM=$109,108 ETD=S109,108 EFC~$1,012,000 CIRC SEAWATER MW: 8.5 SEAWATER RU ATLAS WL. RIH W/JET CUTTER AND CUT 7" TBG 0 8095' WLM. POOH, RD ATLAS. BULLHEAD 8.9 PPG NACL DOWN TBG AND ANN. SHUT DOWN, BOTH SIDES ON VACUUM. OBSERVE WELL. ANNULUS STABLE AND TUBING PRESS - 500 PSI. PUMP 200 BBLS SEAWATER DOWN TUBING FOLLOWED BY 100 BBLS TEMBLOK. SHUT DOWN, BOTH SIDES ON VACUUM. POMPED 210 EBLS SEAWATER DOWN TUBING FOLLOWED BY 310 BBLS SEAWATER DOWN ANNULUS. OBSERVE WELL. BOTH SIDES ON VACUUM. ESTABLISH CIRC DOWN TBG 8 5BPM LOSING' 120 BBLS/HR. DAILY=SS2,672 CUM=$191,780 ETD=S191,780 EFC=$1,012,000 NU BOP MW: 8.5 SEAWATER CIRC 8.5 PPG SEAWATER LOSING 120 BBLS/HR. SHUT DOWN, WELL STATIC. BRK CIRC, TOOK 7 BBLS TO GET RTNS. RU ATLAS WL. RIH W/5.75" GR/JB TO 8210'MD. WELL FLOWING UP TBG, CIRC BTMS UP. RIH W/7" CIBP ON WL AND SET BP @ 8175' MD. POOH, RD ATLAS WL. TEST BP TO 1000 PSIi CIRC BTMS UP. SET BPV, ND TREE. TST 13-3/8" PACK-OFF TO 2000 PSI. NU BOP. DAILY=S43,960 CUM=$235,740 ETD=S235,740 EFC=$1,012,000 POOH W/7" TBG MW: 8.8 NACL NO BOP'S AND TEST SAME TO 5000 PSI. ENGAGE 7" TBG HNGR AND PU SAME. PULL HNGR FREE W/225,000 LBS. PU TO 300,000 LBS AND 7" TBG PARTED AT CUT ~ 8095'. PRESS TST 9-5/8" TO 500 PSI. DISPLACED TBG AND ANN W/8.8 PPG NACL. LD LNDNG JT AND TBG HNGR AND POOH W/7" TBG. LD 53 JTS 7" IJ4S AND 87 JTS ABMOD TBG AT REPORT TIME. DAILY:S29,071 CUM=$264,811 AR3B-459-1-D ETD:~264.811 ~FC;S1.012.000 ?,!a ~a Oil · ' remission ~ ~ & GaS C0nse C0 /Number all daily well histow f ........culively iPage no. ARCO Oil and Gas Company '~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach 'description of all Cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when liiled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until complelion. District Field Date and deptll as of 8:00 a.m. I County or Parish ARCO ALASKA INC. { NORTH SLOPE [ I Lease or Unit PRUDHOE BAY { WGI-02 Complete record for each day while drilling or workover in progress AUDI 4 05/05/89 ( TD: 9655 PS: 9607 SUPV:RJB 05/06/89 ( TD: 9655 PB: 9607 SUPV:RJB 05/07/89 ( TD: 9655 PS: 9607 SUPV:RJB 05/08/89 ( TD: 9655 PS: 9607 SUPV:RJB 05/09/89 ( TD: 9655 PB: 9607 SUPV:RJB 05/10/89 ( TD: 9655 PB: 9607 SUPV:RJB The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 JSIBI;i~K CIRC OUT GAS BUBBLE MW: 8.9 NACL FINISH LD 7" TBG. RU TO RUN 3-1/2" DP. MU SPEAR W/CIRC SUB AND RIH ON 3-1/2" DP. ENGAGED 7" STUB @ 8179' MD. SHEAR SEAL ASSEMBLY FROM PBR W/100,000# OV~R PU WGHT. TOOK 11BBL KICK. SHUT WELL IN. SIDPP = 220 PSI, SICP - 300 PSI. STABBED SEAL ASSEMBLY BACK INTO PKR. CIRC GAS OUT OF WELL ON CHOKE. DAILY:S30,704 CUM:$295,515 ETD:S295,515 EFC:$1,012,000 RIH W/MECH CUTTER MW: 8.9 NACL CIRC GAS OUT OF WELL. WELL STATIC. PULL SEAL ASSY OUT OF PBR AND OBSERVED SIDP = SICP = 200 PSI. BULLHEAD 172 BBLS 8.9 PPG NACL DOWN ANN AND DP. WELL ON VACUUM. CIRC LOSING 3 BPM. SPOTTED AND SQZD 100 BBLS TEMBLOK. LOSS RATE 2 BPH. POOH 700' AND BRK CIRC. CIRC BTMS UP. LOSS RATE INCR TO 4 ~PH. POOH W/FISH.LOSS RATE 5 BPH. MU MECH CUTTER ON DP AND RIH. DAILY:S167,912 CUM:$463,427 ETD:S463,427 EFg:$1,012,000 POOH W/MECH CUTTER MW: 8.9 NACL RIH W/MECH CUTTER. LOSS RATE INCR TO 3 BPM. SPOTTED AND SQZD 75 BBL TEMBLOK PILL. MONITOR LOSS RATE OF 2 BPH. TAGGED PBR W/CUTTER AND CUT PBR @ 8208'. POOH W/CUTTER. LOSS RATE 2.5 BPH. DAILY:S86,400 CUM:$549,827 ETD:S549,827 EFC:$1,012,000 MIX BRIDGESAL PILL MW: 8.9 NACL POOH, LD MECH CUTTER. MU SPEAR AND RIH. LOSS RATE INCR TO 2.5 BPM. MIX AND SQS 55 BBL BRIDGESAL PILL. LOSS RATE DECR TO 2 BPH. SPEAR PBR AND POOH. RECOVERED 6' OF PBR BARREL. MU 8-1/2" PKR MILL AND RIH. LOSS RATE INCR TO 3 BPM MIX 75 BBL BRIDGESAL PILL. DAILY:S92,200 CUM:$642,027 ETD:S642,027 EFC:$1,012,000 LD FISH MW: 8.9 NACL MIXED AND PUMPED 75 BBL BRIDGESAL PILL. DISPLACED PILL W/15 BBL NACL AND 53 BBL 8.9 PPG NACL. PILL BRIDGED OFF AND HELD 180 PSI. BLEED OFF PRESSURE AND TAG PKR. MILLED OVER PKR. CBU. POOH, DID NOT RECOVER PKR. RIH W/SPEAR. TAG PKR @ 8325' MD. POOH, RECOVERED PKR. WELL STATIC. DAILY:S111,900 CUM:$753,927 ETD:S753,927 EFC:$1,012,000 REPLACE 9-5/8" PACKOFF MW: 8.9 NACL PU 9-5/8" RTTS AND RIH. SET RTTS @ 2544' MD AND TEST 9-5/8" CSG TO 2000 PSI F/30 MIN W/NO LEAK OFF. REL RTTS AND POOH. MU HALL REP BELOW RTTS AND RIH ON DP. SET RBP @ 8326' MD AND RTTS @ 8263' MD. PRESS TST 9-5/8" CSG TO 4000 PSI F/30 MTN W/NO ~AK OFF. REL RTTS AND POOH 2 STNDS. M~ Tille ~,~-.~ ~ Drilling SupL IWell no. AR3B-459-2-B RECEIVED 0]/& Gas Cons. Comudssion Anchorage INumber all daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnferim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oit string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ICounty or Parish IStat ARCO ALASKA INC. I NORTH SLOPE L I tease or Unit PRUDHOE BAY I WGI~02 Comp[eta record for each day while drilling or workover in progress AUDI 4 RTTS ~q~ND STOt~/~IVALVE ARD ~T SA.-~E U' ~ELOW TBGklD. FULL WEAR BSHNG. ATT TO PULL UPPER 9-5/8" PACKOFF W/OUT SUCCESS. ND BOP, TBGHD. PULLED AND REPLACED LOWER 9-5/8" PACKOFF. PREP TO NU TBGHD AND REPLACE UPPER 9-5/8" PACKOFFF. DAILY:S58,600 CUM:$812,527 ETD:SS12,527 EFC:$1,012,000 Date and depth as of 8:00 a.m. 05/11/89 ( TD: 9655 PB: 9607 SUPV:RJB 05/12/89 ( TD: 9655 PB: 9607 SUPV:BRB 05/13/89 ( TD: 9655 PB: 9607 SUPV:BRB 05/14/89 ( TD= 9655 PB: 9607 SUPV:BRB CIRC BTMS UP MW: 8.9 NACL ATT TO REMOVE TOP 9-5/8" PACKOFF FROM TBGHD W/O SUCCESS. SEND TBGHD TO MACHINE SHOP. NU BOPS WHILE WAIT ON TBGHD. ND BOP AND INSTALL NEW TBGHD AND TOP PACKOFF. TST PACKOFF, TBGHD AND BOPS TO 5000 PSI. ATT TO TST ANN BOP W/O SUCCESS. CHNG ANN BOP RUBBER AND TST ANN BOP TO 2500 PSI. RETRIEVE STORM PKR AND RTTS. RIH AND RELEASE RETRIEVABLE BRIDGE PLUG AND CIRC BTMS UP. NO GAIN OR LOSS WHILE CIRC. DAILY:S61,914 CUM;$874,441 ETD:S874,441 EFC:$1,012,000 CIRC POLYMER SWEEP MW: 8.9 NACL CIRC BTMS UP. POOH, LD RETRIEVABLE BRIDGE PLUG. RIH W/6" BIT. WASHED THROUGH BRIDGESAL PILL FROM 9079' - 9528'MD. WASHED FILL FROM 9528' - 9597'MD CIRC 100 BBL HEC PILL. RECOVERED 90 BBL BRIDGESAL AND POLYMER. POOH TO TOP OF 7" LINER. CONTINUE CIRC HEC SWEEP. LOSS RATE - 40 BBLS/HR. DAILY:S55,637 CUM:$930,078 ETD:S930,078 EFC:$1,012,000 LAY DOWN DP MW: 8.9 NACL CIRC POLYMER SWEEP. LOSS RATE - 42 BPH. RIH AND TAG FILL @ 9592'. LOSS RATE @ 74 BPH. POOH TO TOP OF 7" LINER. LOSS RATE = 60 BPH. MIX AND PUMP 50 BBL TEMBLOK PILL. LOSS RATE AFTER PILL IN PLACE = 22 BPH. POOH. MU BAKER FB-1 PKR ON DP AND RIH. SET PKR @ 8266' MD. TST PKR TO 1500 PSI. POOH, LD DP. DAILY:S91,938 CUM:$1,022,016 ETD:S1,022,016 EFC:$1,012,000 RUNNING 7" TUBING MW: 8.9 NACL POOH, LD DP. CHANGE PIPE RAMS TO 7" AND TST TO 5000 PSI. MU BAKER SEAL ASSEMBLY ON 7" 26#, 29~ L-80 ABMOD 8RD, AND 7" 269 L-80 AB IJ4S TUBING AND RIH. (CAMCO 'BAL-OS' SSSV @ 2199', BAKER 'FB-i' PKR @ 8273', & TT @ 8391') DAILY:S226,726 CUM:$1,248,742 ETD:S1,248,742 EFC:$1,012,000 no. For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ]Title Drilling Supt. AR3B-45~2-B RECEIVED ';lasi-a 0ii & Gas Cons. '~ ' t~f~j~jjSSj0j, Ancl~orage 'Number all daily well hislory torres conseculively las hey are prepared for each well. IPage no. ARCO L,,! and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length ol time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" Iorm may be used for reporting the entire operation if' space is available. I Accounting cost cenler code District ~--~,,.,v ~ '~"""' ICounty or I~'Z'H, ~[,OF~- ~State ~ I / Field ~D[~ ~' ~L ...... U~z-U2 ~Well no. Auth. or W.O. no~'~2807 [Title~O~OV~ Operator Spudded or W.O'~'.%~'g~n Date and depth ! Complet ..... ~Of~a~ day reported as of 8:~ a.m. '05/15/~ ( ~' TD: 9655 [~' PB: 9607 SUPV:BRB Old TD Released rig IA.R.Co. W~.'0000 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our 0:2300 IPrlor status if a W.O. ~ ~a~ MW: 8.5 SEAWATER FIN RIH W/7" TBG. STING INTO PKR AND VERZFY W/500 PSI. SPACE OUT AND INSTALL GRAY GEN II TUBING HNGR. DISPLACE TBG AND CSG W/8.5 PPG SEAWATER. FREEZE PROTECT TOP 2350' OF TBG AND CSG W/DIESEL. LAND TBG HNGR AND RILDS. TST ANNULUS TO 4000 PSI F/30 MIN. TST TBG TO 3000 PSI F/30 MIN. SET BPV. ND BOP, NU 7" 5MTREE. TST TREE VALVES AND FLANGES TO 5000 PSI. PRESS TBG TO3600 PSI AND OBSERVE - NO BLEED OFF. PRESS TBG TO 4000 PSI AND SHEARED SHEAR OUT SUB IN PKR TAILPIPE. SITP = 500 PSI. SET BPV. RELEASE RIG @ 0230 5/15/89. DAILY:S41,873 CUM:$1,290,615 ETD:S1,290,615 EFC:$1,012,000 New TD Classifications (oil, gas, etc.) Producing method Potential test data PB Depth IK nd of rig IType completion (single, dual, etc.) Official reservoir name(s) Date Well no. Date Reservoir Producing Inlerval Oil or gasTest time Production Oil on lest Gas per day Pump size, SPM X length Choke size T.P. C.P. Waler % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution see Procedures Manual, Section 10, Drilling, Pages 86 and BT. AR3B-459-3-C RECEI?ED Oil& Oas Cons,~ ' · - uu~iiSI0~ Ar~ch0rage Drilling Supt. Number all daily well history forms consecuflvely as they are prepared rot each well. Page no. Dlvll~on ol AtlsnllcRIchfieldCompany ALASKA ulL AND GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION REPOilT'A I "OG 1. Status of Well Classification of Service Well Gas Injection OIL '~ GAS [~] SUSPENDED ~J ABANDONED '~] SERVICE d 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-43 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-20379 4. Location of well at surface 376' FNL, 1184' FEL, Sec.11, T11N, R14E, UN At Top Producing Interval 1194' FSL, 1484' FWL, Sec. 2, T11N, R14E, UN At Total Depth 1463' FSL, 1249' FWL, Sec. 2, TllN, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 49' 6. Lease Designation and Serial No. ADL 28302 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number WGI-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/08/79 J 08/27/79 09/03/79* N/A feet MSL 1 17. Total Depth (MD+TVD) 118.Plug Back Depth(MD+'I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9655'MD/8667'TVD1 9607'MD, 8628'TVD YES [] NO [] 2199' feet MDI 1900' (approx.) . 22. Type Electric or Other Logs Run GR/CNL/CCL, D IL/SP, FDC/CNL/CAL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 13-3/8" 9-5/8" 7" 72.0# 47.0# 29.0# MN -80 S00-95/N-~ N-80 SETTING DEPTH MD TOP BOTTOM Surf 7~; ' Surf 2731 ' ~0 Surf 8671 ' 8346' 9650' 24. Perforations open to Production (MD+TVD of Top and Bottom and Perforated w/4 spf interval, size and number) 9056'-9076'MD/8186'-8202'TVD 30" 17-1/2" 1 2-1 8-1/;~" 330 sx AS nm~ 4~2S sx AS II 405 sx Class C 25. TUBING RECORD SIZE 7"/4-1/2" 9082'-9092'MD/8207'-8215'TVD 9096'-9106'MD/8218'-8226'TVD 9126'-9296'MD/8314'-8378'TVD 9310'-9316'MD/8389'-8394'TVD 9324'-9452'MD/8400'-8495'TVD 9454'-9484'MD/8505'-8531'TVD 9492'-9497'MD/8535'-8539'TVD AS ! DEPTH SET (MD) 8391 ' PACKER SET (MD) 8273' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. 9502 ' -9512 'MD/8543 ' -8551 'TVD N/A PRODUCTION TEST Date First Production Date of Test Flow Tubing' Press. Hours Tested Casing Pressure JMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR TEST PERIOD I~ CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF 28. CORE DATA WATER-BBL WATE R-B B L ICHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Previously Submitted *Note: Perforated well 08/12/80 & 5/26/87. Workover performed 5/15/89. Form 10407 044/WC6 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate FORMATION TESTSL ~ . - ~ .~. :, ~- ~ ~ ~:.!:. ;~-: :. · .- NAME Include interval tested, pressure data, all fluids reCovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · . Top 5ad1 erochit 9045' 8177' N/A Base 5ad1 erochi t 9542 ' 8576' · . 31. ~l/~r OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~. ~ Title Regional Drilling EngrDate ,~--/2JO~/ / 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 inter~als 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 (ELF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~o~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown ~ Stimulate__ Plugging Pull tubing ~ Alter casing ~ Repair well __ Perforate Other _/~ Workover 2. NameofODerator ARCO Aqaska, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 376' FNL, 1184' FEL, Sec.11, TllN, R14E, UM At top of productive interval 1194' FSL, 1484' FWL, Sec. 2, TllN, R14E, UM At effective depth 1393' FSL, 1308' FWL, Sec. 2, TllN, R14E, UM At total depth 1463' FSL, 1249' FWL, Sec. 2, TllN, R14E, UM 6. Datum elevation (DF or KB) RKB 49' 7. Unit or Property name Prudhoe Bay Unit 8. Well number W61-2 (23-2-11-14) 9. Permit number/approval number 79-43/8-964 10. APl number 50-- 029-20379 11. Field/Pool Sadl erochi t feet 12. Present well condition summary Total depth: measured 9655 ' MD feet -/ true vertical 8667 ' TVD feet 9607 'MD Effec!ive depth: measured 8628 'TVD feet true vertical feet Plugs (measured) None Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 73' 2682' 8622' 1304' 20" 330 sx Arctiset 73'MD 13-3/8" 4425 sx AS II 2731 'MD 9-5/8" 500 sx Class G & 8671 'MD 375 sx AS I 7" 405 sx Class G 8346'-9650'MD measured true vertical 9056'-9076', 9082'-9092', 9096'-9106', 9126'-9296', 9310'-9316' 9324'-9452', 9454'-9484', 9492'-9497', 9502'-9512' 8186'-8202', 8207'-8215', 8218'-8226', 8314'-8378', 8389'-8394' 8400'-8495', 8505'-8531', 8535'-8539', 8543'-8551' Tubing (size. grade, and measured depth) 7"/4-1 '2" tbg w/tail ~ 8391 ' Packers and SSSV (type and measured depth) Camco 'Bal-OS' SSSV @ 2199' & Baker 'FB-I' pkr @ 8273' 73'TVD 2731'TVD 7792'TVD 7603'-8663'TVD 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure AlaSka Oil & oas Coho. Ancho~'age 14. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._¢_ 16. Status of well classification as: Oil ~ Gas __ Suspended Service Ga~ I nj~.t:nr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed %~' ~*Wo Title Regional Drillinq Enqr, Form lO-404RevO6t15/88 rkover Well History (DAM) SW04/039 SUBMIT IN DUPLICATE ARCO ALAi.*KA., INC~ F'. 0 ~ BOX t ,:7.,(.)366, ANCHORAGE, ALASKA 995i ':-] DATE · ~-~ ~'~-8°,- F;:F-FERENCE' ARCO CA~ED HOLE FINAL£ t-t9 5--i -89 PRODUCTION PROFILE ,,.."~ .-'~ t5-4-89 C 0 L L A R / F' E R F _,~'-'3 5.-5-89 COLLAR/F'ERF' '7'-ii 4-1 5-89 i:'RODUCTION PROF'ILE 7- i 4 4-¥,3-89 COLLAR/PERF 9-S 4-28-89 PRODUC'rIoN PROFILE 9-6 4-29-89 PRODUCTION PROFILE 9-7 4- S'."~- 89 F'RODUCTION PROFILE 9--9 4-27-89 F'RODUCTION PROFILE 't i - ~ 4-29-89 COLLAR/PERF i~-26 4-26-89 FLOWMETER TEMP 'SURYEY t S.-~S 4.-26-89 FLOWMETER 'i'EMP :~URVEY t 7-8 S-27-89 COLLAR/F'ERF' WGI-'2 5-2-89 PFC PLEASE ~IQN AND RETURN THE ATTACHED COPY A~' RECEIPT iii- R UN i, 5" RUN t, .5" RLIN i , 5" RtJN t, 5" RUN i , ...,."," I;:UN t, .5" F;.: LJN i , ...,";'" RUN i , ..,":"" RUN i, ~" RUN i, ~" RUN i, ~" RUN t , D" RUN t, 5' RUN I, ~' DATA. C A M C' 0 ATLAS' Al' L.A._? CAMCO A 'f' L.A ~-: CAMCt] C A r.i L'.'~'j C A i"i C t] C A M L: u A-I" L A ,~,," CAt.ICO CAMCO I.-I1..~'. ATLAS* RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 DISTRIBUTION CEN'FRAL FILES CHEVRON D & M EXTEN~'I ON EXPLORATION EXvON MARATHON MOBIL F'14ILLIF'$ F'B WELL FILES R & D BPX eTA'YE OF ALASKA IEXACO · ' .~,~;,a Oil & Gas Cons. ! D: W W ! TEL NO: 9~072634600 · . . · r...¢.,'I ~' ... ~ I..~'! ,' STATE OF ALASF~ I~ASKA OIL & CAS CONSERVAT10N COI.~[ISSION fl.0.~,E, Inspection Report ~023 PO! permit ~..?~- ~/-~, ......... _ ..~ Casing Set @_ ntative ACCUHULAIOR SYSIEB! Full Charge Pressure Hud Sys..t em. s_ .Visu.a,,~ .... Trip Tank ~tc ~auge .... --- . . Gas Detectors ~,,-- i Audio u L BOPE Stack , A~xnular Preventer~._J?_ Blind Rams. ___.~2.,~-.. ~_ Choke Line Velvet II.C.R. ~1i Line Valves Check Valve . Test Pressure ,, Pressure After Closure .......... psig=/_~~..... _.. Pump /ncr. clos. p~es. 200 psig ....... min,~sec. Full Ci, a~$e ~res,ur, Attained: ~2..-mtn_.cl~ec. .... zg~¢a --- Remote ~l/nds switci) cover ~'~ .... .... ~._ Kel_l~__ and Floor Safecy Valves -. Upper Kelly_. / Test Pressure ...... Lower Kelly /.~Test Pressure. Ball Type. ....... .Test Pressure ..... Inside BOF~_~..~.Tesc Pressure , .~00 '.CP__ __ ' · Choke l'IaTiifO~it ~:;est Pressure .( ~~ ~ ~o, v.l~, .... ~, ~_. ~.~o/~/~__:, ~... ~__? ........ AdjusBabl~ Chokes / ........ llv~t~utcall ,er~d choke ........ /,...q .. ~~.~ Repair or Replacement 'of failed equipment to be made within, days .and Inspect,Or/ f , · Commission office notified. Distribution orig. - AO&OCC cc - Opera,or cc - Supervisor In,p~ctcr RECEIVED MAY - .Oil~-~as'Cons.-Cc-;nmlssma': ..... '"'" ;', Anchorage STATE OF ALASKA Ab,dKA OIL AND GAS CONSERVATION COMMIssION APPLi TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Pull tubing ~ Variance __ Perforate __ Other 2. Name of Operator 5. Type of Well: 6. ARCO Alaska, Inc,, Development__ Exploratory __ 3. Address Stratigraphic ~ 7. P. 0. Box 100:360, Anchorage:, AK 99510-03,60 Service.2~_ 4. Location of well at surface 8. 3,76' FNL & 1184' FEL, Sec 11, TllN, R14E, UM At top of productive interval 1194' FSL & 1484' FWL, Sec. 2, TllN, R14E, UM At effective depth 13,93,' FSL & 13,08' FWL, Sec. 2, T11N, R14E, UM At total depth 1463,' FSL & 1249' FWL, Sec. 2, TllN, R14E, UM Datum elevation (DF or KB) 49' RKB Unit or Property name Prudhoe Bay Unit Well number WGI-2 (23,-2-11-14) 9. Permit number 79 -43 10. APl number 50-0'29-2O379 11. Field/Pool Sadlerochit feet 12. Present well condition summary Total depth: measured 9655 true vertical 8667 feet Plugs (measured) feet Effective depth: measured 9607 /-' true vertical 8628 feet Junk (measured) feet Casing Length Structural 7:3 ' Conductor Surface 2682 ' Intermediate 8622 ' Production Liner 1304 ' Perforation depth: measured Size Cemented Measured depth ~uevedicaldepth 20" 3,3,0 sx Arctiset 73,' 73' 13,-3/8" 4425 sx Arctiset 2731' 273,1' 9-5/8" 500 sx Class G Cmt 8671' 7792' true vertical 7" 405 sx 83,46' - 9650' 7603,' - 8663,' 9056'-9076', 9082'-9092', 9096'-9106', 9126'-9296', 9310'-9316', 9324'-9452', 9454'-9484', 9492'-9497', 9502'-9512' 8186'-8202', 8207'-8215', 8218'-8226', 8314'-8378', 8389'-8394', 8400'-8495', 8505'-853,1', 8535'-853,9', 8543'-8551' Tubing (size, grade, and measured depth) 7", 26#, L-80 ~ 0-2219'/7", 29#, N-80 @ 2219-8209'MD Packers and SSSV (type and measured depth) Baker SAB-2 Packer (~ 8217 'MD/0T IS SSSV ¢ 21~§'MD 13. Attachments Description summary of proposal 14. Estimated date for commencing operation 02-01-89 16. If proposal was verbally approved Name of approver Date approved Detailed operations program 15. Status of well classification as: BOP sketch Oil__ Gas__ Suspended__~,~C 1 9 ~,988 Service Gas Injector ....... "" & Gas Cons. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed %/? ~ Title Regional D~illing Engineer FOR COMMI~;SION USE ONLY Conditions of approval: Notify Commission sq representative may witness Plug integrity __ BQP .Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ,~/,.:, z/.. Anchorage Date /2//~ ~/~r~ I Approval No. OC:~,,_ Approved by order of the Commissioner ,;:... :N.,','L SIGNED "~ :.-O~NIE C. SMITH Form 10-403 Rev 06/15/88 0 38/SA4 Commissioner Date /¢7..-,~4~ ~ SUBMIT IN TRIPLICATE PRUDHOE BAY WGI-2 WORKOVER PROCEDURE SUMMARY 1) 2) 3) 4) 5) 6) 7) 8) 9) RU slickline. Pull SSSV. Set BPV. MIRU workover rig. Bullhead seawater followed by Temblok 120 pill. The kill pill should be displaced wi th 9.2 NaCl. RU E-line. RIH with jet cutter and cut 7" tubing at -+ 8110'. Displace well with 9.2 NaC1. Set BPV. ND tree and NU BOPE and test. POOH LD 7" tubing. PU 3-1/2" D.P., RIH with spear, shear PBR and recover 7" fish and seal assembly. RIH with mechanical cutter and cut PBR barrel from the top of SAB-2 packer. 10) RIH with spear and recover cut-off PBR barrel. 11) RIH with PRT, mill and recover SAB-2 packer. 12) RIH with RTTS test packer and closing fingers and test 9-5/8" casing to 3000 psi. Change out 9-5/8" packoff. 13) RIH with 6" bit, clean out to PBTD of 9607' MD. 14) RU wireline. RIH with 8.5" GR/JB to ±8340'MD. RIH with 9-5/8" permanent packer. Set packer at ±8300' MD. 15) Test packer and casing to 3000 psi. 16) RIH with 3-1/2" D.P., POOH LDDP. 17) RIH with 7" completion assembly. 18) Space out, displace well to inhibited seawater and freeze protect. 19) Land tubing, test tubing to 4000 psi, test tubing annulus to 3000 psi, bleed off. 20) Set BPV, ND BOPE, NU tree and test. Shear out sub. 21) Set BPV. Release rig. Anticipated bottomhole pressure: 3715 psi Workover Fluid: 9.2 PPG brine 029/LWK RECEIVED DEC 1 9 1 88 Nask,~ Oil & Gas Cons. Commissior~ Anchorage ANNULAR PREVENTER § PIPE RAMS 5 BLIND RAMS TUBIN6 HEAD 1. 13-3/8" CASING HEAD 2, 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4, 13-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI ANNULAR RECEIVED DEC Alaska Oil & ~s Cons. CommiSSion Anchorage 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 ARCTIC DIESEL. 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. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9, OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 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 5000 PSI, 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 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. dG NOVEMBER 21, 1986 STATE Of ALASKA '~'"'" ALASKA oil AND GAS CONSERVATION COMMI~_,iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program D Plugging [] Stimulate'~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of we'll at surface 376' FNL & 1184'FEL, Sec. 11, T11N, R14E, UN At top of productive interval 1194'FSL & 1484' FWL, Sec. 2, T11N, R14E, UM At effective depth 1393'FSL & 1308' FWL, Sec. 2, T11N, R14E, UM At total depth 1463'FSL & 1249' FWL, Sec. 2, T11N, R14E, UH 5. Datum elevation (DF or KB) 49' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-2 (23-2-11-14) 11. Present well condition summary Total depth: measured true vertical 9655 feet 8667 feet Effective depth: measured 9607 feet true vertical 8628 feet Casing Length Size Conductor 73 20" Surface 2682' 13-3/8" Production 8622' 9-5/8" 8. Permit number 79-43 9. APl number 50-- 029-2(137q 10. Pool Sadlerochit Plugs (measured) ~-; r. ¥;'': 'F~. Junk (measured) , S ; .... . Cemented Measured depth,t.~:.'::t. ~ ,TrU~rhcar 'depth 330 Sx Arct~cset 73' 73' 4425 sx A~ct~cSet 273[' 273[' 500 sx CZ ass G Cmt 867[' 7792' 8346'-9650' 7603'-8662 Liner 1304' 7" 405 sx Perforation depth: measured 9056-9076' 9082-9092' 9096-9106' 9126-9296' 9310-9316' 9324-9452', 9454-9484' 9492-9497' 9502 9512' true vertical 8186-8202' 8207-8215' 8218-8226' 8314-8378' 8389-8394' 8400-8495' 8505-8531' 8535-8539' 8543-8551' Tubing (size, grade and measured depth) 7" 29# N-80 @ 8209 'MD Packers and SSSV (type and measured depth) Baker SAB-2 Packer @ 8217'MD/Otis SSSV @ 2196'MD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] February 1988 13. Estimated date for commencing operation Date approved 14. If proposal was verbally approved Name of approver 15. I hereb~,)certify that the foregoing is true and correct to the best of my knowledge Signed ~/'r~ ,~,~P ~ Title Conditions of approval Operations Engineerin~ Manager Date ~/,/~~' Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI No. L/~-- "~ 7 Approved Copy Returned ORIGINAL SIGNED BY LONNIE C. RMITH Commissioner WGI-2/Stat16 J. M. Vitucci (265-6358) Approved by Form 10-403 Rev 12-1-85 by order of the commission Submit in triplicate ~.~ WGI 2 AND WGI 3 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. proposes to perform the following mud acid matrix acid stimulation on Wells WGI 2 and WGI 3: 1. MIRU slickline unit. , GIH w/gauge ring and perform a tag run to PBTD to ensure all perforations are clear of fill. POH and RD. 3. MI and RU pump trucks, transports, and N2 unit. 4. Stimulate the well as follows: A. 600 gals of xylene nitrified w/1000 SCF N2/bbl B. 3000 gals of 12% HCI w/additives C. 2500 gals of 12% HCI-3% HF w/additives D. 2500 gals of 2% NH4CI water E. 100 bbls of foam consisting of 35 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water F. 600 gals of xylene nitrified w/1000 SCF N2/bbl G 1500 gals of 12% HCI w/additives H. 2500 gals of 12% HCI-3% HF w/additives I. 2500 gals of 2% NH4CI water J. 100 bbls of foam consisting of 35 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water K. 800 gals of xylene nitrified w/1000 SCF N2/bbl L. 1500 gals of 12% HCl w/additives M. 3200 gals of 12% HCI-3% HF w/additives N. 3200 gals of 2% NH4CI water 128 bbls of foam consisting of 45 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water P. 800 gals of xylene nitrified w/1000 SCF N2/bbl 1500 gals of 12% HCI w/additives R. 3200 gals of 12% HCI-3% HF w/additives S. 3200 gals of 2% NH4C, I water T. 128 bbls of foam consisting of 45 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water U. 1200 gals of xylene nitrified w/1000 SCF N2/bbl V. 2500 gals of 12% HCl w/additives W. 4800 gals of 12% HCI-3% HF w/additives X. 150 bbls of 50/50 methanol/water 5. RD and release equipment. Return well to injection immediately. 6. Test well for new injection Capacity. D~TE- REFERENCE' ARCO £ASED IqnI.F FIWAI., 6-22-R7 A-.?.O-R7 6-20-87 R-i %-R7 R-i 4- P,, 7 R-P4-R7 5-4-97 5-Z- .R7 5-~-g7 ~.--P-R'7 ./ ,:. ~- _ ! '~-2Z-~'7 5-24-87 5-24- .R7 ..~' ,:_ _.~ m ! £O! I AR'/F'tTRFRRA'f'TON COl I. £131_I..AR' Crll. I AR'/PFR'FflR'T T fin COl..I_. AR'/F'ERFORAT T_ ON. £FII...I. P, rll..I AR'/F'F'R'F'flRAT I ION CRI...I. AR'/F'FR'FRR'A T T F1N COl _1... A R'/PERF OR'A T I ON Rrll !. AR'/F'F-.R'Ff'IK'ATTON Cf]l...I.. A R'/F'ERFORAT T COl .I.. AR'./P F R'F [1R A T 'r .C..OI .I AR/PF]R'FORAT.TON COI. i AR/F'FRFRRATTON C.n~..!._ AR/F'ERF[!RAT T. ON R'IJN RI IN R'! IN R'I IN RIIN R'I IN R'I IN F,'I IIg R'IIN I-'~ !.IN ~'! IN RI IN F,'I IN RI.IN R'! IN F'E~GY BENNETT ATO-4~oo TRANY ~NRO,,5 APPROVED D]'%T~TRI.ITTDN 5" 5" 5" .2 DR'~XF'R ,--~ -, DIFFUSER' " F'H ]:1 I_.. 'r F'.? ~ . . F'P,, L,JFI.I FTI F,q - ~AF'F'. '~ t-'TATF' FIF AI.A,?KA ARCO Alaska, In, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 24, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: WGI-2 (23-2-11-14) Permit No. 7-229 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/MRO/jp Attachment cc: Standard Alaska Production Company P1 (WOI-2)W1-3 RECEIVED AUG 2 6 ;Naska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALA~.,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 49' RKB Feet 3. Address 6. Unit or Property name Post Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 376' FNL & 1184'FEL, Sec. 11, T11N, R14E, UM At top of productive interval 1194'FSL & 1484' FWL, Sec. 2, T11N, R14E, UM At effective depth 1393'FSL & 1308' FWL, Sec. 2, T11N, R14E, UM At total depth 1463'FSL & 1249' FWL, Sec. 2, T11N, R14E, UN 7. Well n~b_e~ (23-2-11-14) 8. Approval number 7-229 9. APl number 50-- 029-20379 10. Pool Sadl erochi t 11. PreSent well condition summary Total depth: measured true vertical 9655 feet Plugs (measured) 8667 feet None 9500' - Fill Effective depth: measured 9500 feet Junk (measured) true vertical 8542 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 45' 20" 330 sx Arcticset 72.5' 72.5' Surface 2703' 13-3/8" 4425 sx Arcticset 2731' 2731' Production 8643' 9-5/8" 500 sx Class G Cmt 8671' 7792' Liner 1304' 7" 405 sx 8346'-9650' 7603'-8663 9056-9076' 9082-9092' 9096-9106' 9126-9296' 9310-9316' Perforation depth: measured 9324-9442r, 9454-9474' 9474-9484' 9492-9497' 9502-9512' true vertical 8186-8202' 8207-8215' 8218-8226' 8314-8378' 8389-8394' 8400-8495' 8505-8521' 8521-8529' 8535-8539' 8543-8551' Tubing (size, grade and measured depth) 7" 29# N-80 ABM 8rd to 8209 'MD Packers and SSSV (ty_p.e and measured depth) 9-5/8" x 7" Baker SB-2 Hydroset Packer @ 8221'MD/Otis SSSV @ 2199'MD 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation 5/29/87 RECEIVED Al!f-' e ~-.~,-, na & ~n~ Cons. C0mmisslol~ Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Oasing Pressure Tubing Pressure 5/22/87 -- ~4g06g .... 3878 -- ~54800 .... 38g0 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1'85 MR0 (265-6810~ Submit in Dupli.cate/~. WGI-2 ADD PERFS Daily Report of Well Operations 5/25/87 PT lub/rams to 4000 PSI. OK. Pul 1 SSSV. RIH w/Bailer, TTL & Dummy Gun. Tag bottom @ 9533 'MD. POH. PT hardline to 4000 PSI. OK. Pump in diesel/xylene wash - spot across perfs. PT l ub/rams to 4000 PSI. OK. RIH w/ 12' & 5' select fire gun #2, 3-3/8", 4 SPF, 120° phasing. Shoot 9492-9497' (5'). Shoot 9430-9442' (12'). POH - all shots fi red. PT l ub/rams to 4000 PSI. OK. RIH w/ 26' gun #3, 3-3/8", 4 SPF, 120° phasing. Shoot 9384-9410' (26'). POH - all shots fired. PT l ub/rams to 4000 PSI. OK. RIH w/ 6' & 20' select fire gun #4, 3-3/8", 4 SPF, 120° phasing. Shoot 9344-9364' (20'). Shoot 9310-9316' (6'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. RIH w/6' & 20' select fire gun #5, 3-3/8", 4 SPF, 120° phasing. Shoot 9246-9266' (20'). Shoot 9086-9092' (6'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. 5/26/87 RIH w/4' & 20' select fire gun #6, 3-3/8", 4 SPF, 120° phasing. Shoot 9196-9216' (20'). Shoot 9082-9086' (4'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/ 20' gun #7, 3-3/8", 4 SPF, 120° phasing. Shoot 9146-9166' (20'). POH - all shots fired. PT equipment to 4000 PSI. RIH w/SSSV and set @ 2173' WLM. POH. Test w/350 PSI differential pressure. OK. RECEIVEI) AUG 2 6 lS J/ Alaska Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ~--' ALAS, OIL AND GAS CONSERVATION COM~...JSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ..~ Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 376' FNL & 1184'FEL, Sec. 11, TllN, R14E, UN At top of productive interval 1194'FSL & 1484' FWL, Sec. 2, T11N, R14E, UM At effective depth 1441'FNL & 1268' FWL, Sec. 2, T11N, R14E, UM At total depth 1463'FSL & 1249' FWL, Sec. 2, T11N, R14E, UM 5. Datum elevation (DF or KB) 49' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-2 (23-2-11-14) 8. Permit number 79-43 9. APl number 5O-- 029-20379 10. Pool Sad]erochit 9607' - Cement feet 11. Present well condition summary Total depth: measured true vertical 9655 feet Plugs (measured) 8667 feet Effective depth: measured 9607 feet Junk (measured) true vertical 8628 feet None Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 45' 20" 330 sx Arcticset 72.5' 72.5' Surface 2703' 13-3/8" 4425 sx Arcticset 2731' 2731' Production 8643' 9-5/8" 500 sx Class G Cmt 8671' 7792' Liner 1304' 7" 405 sx 8346'-9650' 7603'-8663 Perforation depth: measured 9056-9076', 9096-9106', 9126-9146', 9166-9196', 9216-9246', 9266-9296', 9324-9344', 9364-9384', 9410-9430', 9454-9474', 9474-9484', 9502-9512' true vertical 8186-8202', 8218-8226', 8242-8258', 8274-8298', 8314-8338', 8354-8378', 8400-8416' ,- 8432-8448', 8469-8485', 8505-8521', 8521-8529', 8543-8551' Tubing (size, grade and measured depth) 7", 29#, N-80, ABM 8rd to 8209 'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker sm-2 Hydroset Packer @ 8221'MD/0tis SSSV @ 2199'MD 12.Attachments Description summary of proposal ',~ Detailed operations program .~1 BOP sketch ~ 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/c~rtify that the,f,e~reg~ is tr,,~e and correct to the best of my knowledge ~_/~/~,~~~/' ! ~]// f"/ // Title Operations Engineering Manager Date Signed Commission Use Only CorYditions of approval Notify commission so representative may witness I Approval No. ~ ,~,~ [] Plug integrity :- BOP Test ~ Location clearanceI /-"d-~u.. / Approved by ~ ~,, , *,,,~, byorderof ¢' ~ %7 ~ ~¢. e,~ Commissioner the commission Date - ~ Form 10-403 Rev 12-1-85 MR0 (265-6810) Submit in triplicate WGI-2 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well WGI-2. The proposed perforation intervals are as follows: Existing Perforations 9056-9076 (20') 9096-9106 (10') 9126-9146 (20) 9166-9196 (30) 9216-9246 (30) 9266-9296 (30) 9324-9344 (20) 9364-9384 (20) 9410-9430 (20) 9454-9484 (30) 9502-9512 (10) TOTAL = 240' Proposed Perforations 9082-9092 (10') 9153-9166 (13') 9196-9216 (20) 9246-9266 (20) 9310-9316 ( 6 ) 9344-9354 (10) 9384-9410 (26) 9430-9442 (12) 9492-9497 ( 5 ) 9517-9524 ( 7 ) 9531-9539 (8') TOTAL = 137' Reference CNL of 8/31/79 A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOM HOLE LOCATION: ' ORIGINAL RKB': 49' TOP OF SADLEROCHIT: 9045' ALL DEPTHS ARE RKB MD Depths are to TOP of equipment · ~GI #2 ~-~.SPUD DATE: 8/8/79 376'S & 1184'W of NE ct. Sec. !I, TllN, R14E, UM 1463'N & 1'249'E of SW cr. Sec. 2, TllN, R14E, UM L72.5 2179 2199 RKB TO Gray HANGER 28' ' MD AVERAGE HOLE ANGLE: 33.B5° MAXIMUM ANGLE: 37o @ 9000~9300' ANGLE AT TD: 36o ANNULUS F~UID: 10.8 CaCl2 w/ 15 bbl Diesel Cap ' 20", 94#, H-40 Vetco (19.124" ID) w/ 330 sx ' Bottom of 7", 26#, L-80 Ij4S (6.276" ID) ' Otis RPB SSSV Nipple (5.963" ID} 2307' 2332' 2456' 2731' Bottom of 9-5/8", ¢7#, S00-95 BTC (8.681" ID) Howco 9-5/8" FO Howco 9-5/8" FO 13-3/8", 72#, N-80 BTC (12.347" ID) w/ 4425 sx 8209' Bottom of 7", 29#, N-80 ABM 8rd 8217' BaKer Seal Bore Extension Assembly 8221' 9-5/8" x 7" Baker SB-2 Hydroset Packer 8235' Baker Millout Extension 8236' Baker Shear Out Sub (4.843" ID} -NO TAILPIPE . 8346' Top of Liner, BOT-MC Hanger 8671' 9-5/8", 47#, N-80 BTC (8.681" ID) w/ 500 sx 9056' - 9076' g096' - 9106' 9126' - 9146' 9166' - 9196' 9216' - 9246' 9266' - 9296' 9324' - 93~4' 936~' - 9384' 9410' - 9430' 9454' - 9474' 9474' - 9484' 9502' - 9612' 9607' PBTD 9650' 7", 29#, N-80 BTC (6.18~"ID) w/ 405 sx 9655' TD 1/84 4 2 I ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF N I REL I NE BOP EQU I PMENT ,: ARCO Oil and Gas' ~pany North Slope ,.,~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 25, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil & Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 ! , 3 GEC~_ I STA'r TEC -- !.,~1 STAT TEC CONFER: FILF: Subject' Dear Si r' NGI #12 (Permit # 77-81) WGI #2 (Permit # 79-43) Enclosed please find corrected copies of the Well Completion Reports for the subject wells, as requested by your staff. The individual drilling histories and gyroscopic surveys remain unchanged as originally submitted. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' sp Enclosures RECEIVED [;i;{C -- 2 AJaska 0il & 6as 0ohs. 6ommission Anchorage ARCO Oil and Gas Company is a Division ol AllanticRichfieldCompany Form SUBMIT IN DUPL \TE* ...n~ ALASKA (see or.er ~n- STATE structions on reverse side) Gl L AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: NEW I--~ WORK DEEP- [~ PLUG DIFF. WELLI ~1 OVER E~] EN I I BACK I---] RESER. I---] Other Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 376'S & 1184'W of NE cr Sec 11, TllN, R14E, UM At top prod. interval reported below 1368'N & 1329'E of SCl cr Sec 2, TllN, R14E, UH At total depth 1463'N & 1249'E of SW cr Sec 2, T11N, R14E, UM 5. APl NUMERICAL CODE 50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #2 10. FIELD AND POOL. OR WILDCAT Prudhoe Bay Field-Prudhoe 0i' 1. SEC., T., R., M., (BOTTOM HOLE P00' OBJECTIVE) Sec 2, T11N, R14E, UM 12. PERMIT NO. · 79-43 8/8~79 I 8/27/79 I 9/3/79 49' RKB HOW~I~IANY~* 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS 9655'MD 8667'TVDI 9D~T~'MD 8628'TVDI blng, e. -?' All ~' 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BO1-FOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL I SURVEY MADE Top Sadlerochit 9045'MD 8177:'TVD Base Sadlerochit 9542'MD 8576'TVD I Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN GR/CNL/CCL, GTro/CCL 25. 26. CASING SIZE I WEIGHT, LB/FT. 20" I 94# 13-3/8" 72# 9-5/8" I 47# I SIZE CASING RECORD (Report all strings set in well) LINER RECORD TOP (MD) H-40 173'Below GLI 30" 330 sx Arcticset Cmt N-80 I 2731 I 17½" 4425 sx Arcticset Cmt ,I-RO I R671 I 12~" I BO0 .~x £1a~ G £mt I I BOTTOM (MD) 7 8346 9650 SACKS CEMENT* SCREEN (MD) 405 SIZE DEPTH SET (MD) PACKER SET (MD) 7 8236' 8221 28. PERFORATIONS OPEN TO PRODUCTION (Interval. size and number) -See Sundry Notice submitted 9/11/80 30. DATE FIRST PRODUCTION 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED N/^ PRODUCTION I WE LL STATUS (Producing o~' s,ut-ln) N/A DATE OF TEST. HOURS TESTED CHOKE SIZEI TEST PERIOD FLOWTUBING ICASINGPRESSURE ICALCULATED OIL-BBL. PRESS. I 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel, Yented, etc.) IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump} OIL--BBL. GAS--MCF. I GAS--MCF. iWATER-BBL. IGAS-OIL RATIO i ff :-ff -V E D I ,co..., TEST WITNESSED BY 32. LIST OF ATTACHMENTS ed '~or Alaska Oil & Gas Cons. C0mmissi0[i 33. ' hereby certify ~i~ t~:o:~n, a~d/ch matit is co/~plete and correct as determined from all available rec°r&l]01~0r~'~g0 /~~ /(Z,~/~,J~Z~, ~m~vl~ District Drilling Engineer O SIGNED ~ ~ ~__. ~TITLE DATE *(See instructions and Spaces for Additional Data on Reverse Side) 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' 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s). (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. ; Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above) .... 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUE) NAME , MEAS. DEPTH TRUE VER']'. DEPT , ., Top Sadlerochil 9045 8177 , Base Sadl erochii 9542 8576 .~. 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. ARCO Oil and Ga~-~.mpany North Alas ,strict Post Of,rice uox 360 Anchorage, Alaska 995'10 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 29, 1980 Reference: ARCO Cased Hole Finals D.S. /"~ West Gas Injection #2 ~'[~ CNL Run 1 D.S. 12-2 DSTNDC Run 1 D.S. 4'10 Pipe analysis Run 1 log ~PPlease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #636 DISTRIBUTION North Geology " R&D Drilling Eng. Manager D&M Geology State of Alaska ARCO Oil and Gas Company I.~ a O]¥ision of AtianhcR,chlieldCompany Sohio Marathon Chevron ARCO Oil and Gas Company North ~?-~"~ Dis!rict Posl C ~3ox 360 Anchoa, ge. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 1, 1980 Reference: ARCO Pressure SUrveys woz-z 8/zo/8o Pressure Survey Pressure Survey ~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #653 DISTRIBUTION No~th Geology R & D Drilling Eng. Manager D & M Geology State of Alaska ARCO OH and Gas Company ~. a D~wsion of Allanl~cR,chl~eldCompany Exxon Mobil Getty Phillips Sohio Marathon Chevron ARCO Oil and Gas/- pany Alaska Distr,_ _ Post Office Box 360 Anchorage, Alaska g95!0 Telephone 907 277 5637 September 9, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 [ 4 ~C~ _ I I.e. ~c~oL .1 2G~ J~l _S_~A~ T~c FILF] Subject' WGI - 1 (Permit no. 79-31) ~;~ (Permit no. 79-43) WGI - 3 (Permit no. 79-49) WGI - 4 (Permit no. 79-50) Dear Sir: Enclosed please find our SUndry Notices of Subsequent Report, for the subject wells, detailing the individual well perfor- ating procedures. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/sp Enclosures ARCO Oil and Gas Company is a Di~,ision of AtlanticRichfie!dCompany Form 10-403 REV. 1-10--73 Submit "Intentions" In Triplicate ~'. & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to ~lrill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L [--I GAs [--1 WELLI~-I WELL I.-.I OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 376" FNL, 1184' FEL, Sec.'ll, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49~ RKB 14, Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 2 10. FIELD AND POOL, OR WILDCAT Prudhoe Ba~v Field - Prudhoe 0il · 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TllN, R14E, UM 12. PERMIT NO. 79-43 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR-ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF.' WATER SHUT-OFFI I~ REPAI RING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING I I ABANDONMENT* (Dr..r) Perforate for injection (NOTE= Report results of multiple completion on Well Coml)letion or Recompletion Report and Log form.) Pool 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertinent ~letalls, and give pertinent dates, Including estimated date of starting any proposed work. set safety' ball valve. Flow well, SI well and closed safety ball and tested tree cap w/5000 psi, ok. Released well to CCP 8/14/80. valve, ok. B.egan per.f operations 8/12/80. Bleed tbg & annulus pressure. Build up tree, test manifold and extra flowline. Test tree to 5000 psi'. Install wireline BOP's and test same Perf'd following intervals w/& SP~F, per GR/CN~ log of 8/31/79' 9502 ~ 95i2, ~ . .~ - 9474 :~ ~ .-. 9474, 9410 ,.F 9430, 9364 -~o9384, 9324 -~ 9344, 9266 :'-9296, 9216 : 9246, 9166 "- 9196, 9126 '~' 9146, 9096 - 9106, 9056 'L 9076. Makeup surface readout pressure bomb and run same. Flow well. SI well. Ran and valve.~ Install *Tested safety 16. I hereby certify that the foregoing is true and correct (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE . See Instructions On Reverse Side ARCO Oil and Ga~;2~ompany Al~sk~ k~~/ Post Oil:c_ L~c..× .380 ~,n,:hora"',e. Alaska 99510 Teleohop. r: 907 277 56;37 August 22,1980 Reference' ARCO Magnetic Tapes /-COMM' :4,.' .... J 4~"G ,' ,3 GE~ .... q~'' ,., ~,qT Tr-C STAT TEC ............. FILF: D.S. 2-9 5/18/80 Tape #60521 D.S. 6-3 5/17/80 " #60504 D.S. 6-11 4/8/80 " #60510 D. ~ -4 5/21/80 " #60523 ~ 8/31/79 Tape #60646 PLEASE NOTE' Tape #60454 is labeled incorrectly as D.S. 3-7. It should be labeled as D.S. 3-17. ~"~~Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #542 DISTRIBLrFION North Geology R&D ~'illing Eng. Manager CeologM State o£Alaska E~axon Mob i 1 Getty Phzllzps Sohio ~.larathon G~e~on Oil and O~s Company ~s a O~ws,on of AllanhcR~cnlieldCompa~y ARCO Oil and Gas Company Alaska Dis." Post Offic~ _,. 360 Anchorage. Alaska ~c,, ~- Telephone 907 277 5637 August 1, 1980 Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' WGI 1 - Permit No. 79-31 iWG~/:2i~_." · ~--..._ " ~'. 79-43 WGI 3 - " " 79L49 WGI 4 -" " 79-50 Dear Sir' Enclosed please find Sundry Notices detailing work and start dates planned for the above mentioned wells. Very truly you_rs, P. A. VanDusen District Drilling Engineer PAV'ruo AUG - 4 /:.t2s:(2 -0i' & .':., , ARCO Oil and Gas Con~pa;~': is Form i~)-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OIL r=l GAS D OTHER GAS INJECTION WELLI I WELL NAME OF OPERATOI~ Atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR P. 0, Box 360, Anchorage, 4. LOCATION OF WELL At surface 376'S & 1184'W of NE cr Sec. Alaska 99510 11, T11N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. APL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 2 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 79-43 }ort, or Other Data NOTICE OF INTENTION TO; TEST WATERSHUT~)FF N PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letall~, and give pertinent dates, including estimated date of starting any proposed work. ARCo 0il and Gas Company proposes to perforate selected intervals within the Sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report. A 5000 psi. WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety vlave will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/8/80 c,~]osequent ~l~or~ t~epo~ec]" 16. I hereby certify t_hat thT~ S,GNE. _, .~~. _ _ T,TLEDistr'ict Drilling Engineer... DATE8/1/80 (This space for State office use) CONDITIONS OF APPROVAL, COMMISSIONER - , Instructions On Revere Side ," ARCO Oil and Gac'-'~-3mpany l',.l ~ ~: k ;~ Rc-~' Ai:chor;:ge. A!~ska 99510 'J'olophone 907 277 5637 OctOber 17, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas '3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 3-9, Permit No. DS 12-3, Permit No. WGI #3, Permit No. 79-22 79-41 79-49 No. 79-21 Dear Sir' Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, P. A. VanDusen District Dril ling Engineer PAV-jh Attachments ARCO Oil and Gas Company is a Division c'.l A!iar;ticR[chf;e:dCor::patly ..... -F~H~ P--7 SUBMIT IN DUP[ rE* sTATE OF ALASKA (Se~6ther In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLr-1 DRY[~ Other. Gas Injection b. TYPE OF COMPLETION: NEW~ WORKI~] DEEP-r--] PLUG I~] DIFF. WELLIAI OVER I I EN I I BACKI I RESER.I I Other 2. NAME OF OPERATOR ARCO 0il and Gas Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 376'S & 1184'W of NE cr Sec ll, TllN, R14E, UM At top prod. interval reported below l~ol~l~pt~ 1329'E of SW cr Sec 2, TllN, R14E, UM 1463'N & 1249'E of SW cr Sec 2, TllN, R14E, UM 14. DATE T.D. REACHED 8/27/79 13. DATE SPUDDED 8/8/79 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20. IF MULTIPLECOMPL., 9655!.MD 8667,TVD'I:.9~MD 8628ITVDI HOW MANY* Si ngl e 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 9045'MD 8177'TVD Base Sadlerochit 9542'MD 8576'TVD 5. APl NUMERICAL CODE 50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit ~WGI- # 2~ (23-2-11-14) 1 {~7~-&F.&,~)~ D POOL, OR WI LDCAT Prudhoe Bay Field-Prudhoe 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ;ec 2, TllN, R14E, UM 12. PERMIT NO. 79-43 0il Pool 24. TYPE ELECTRIC AND OTHER LOGS RUN ~, /ch ' r~/~-~,L/C. GR/CNL/CCL," ~- L~ ~, , , ~ ..... ~, ~, ~,, 25. ROTARY TOOLS INTERVALS ,DRILLED BY CABLE TOOLS All. 23. WAS DIRECTIONAL SURVEY MADE Yes (.'"¢ ~ ~'~"~'~ '~ I~'~' CASING RECORD (Report all strings set In well) 20" 94# Welde~l H-40 72.5' BOTTOM (MD) SACKS CEMENT* 9650' 405 sx Cla R nmt (Interval, size and number) 13-3/8"I 72# Butt l MN-8[I 2731' 9-5/8" 47# Butt180&95I 8671' 'l I I 26. LINER RECORD SIZE TOP (MD) . 7" 8346' 28. PERFORATIONS OPEN TO PRODUCTION HOLE SIZE I CEMENTING RECORD 30" 1330 sx Arcticset cmt AMOUNT PULLED N/A 30. PRODI ICTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of _,l~mp) I · ._ N/A ' DATE OF TEST. I HOURS TESTED CHOKE SIZE ITEsTPROD'NpERIoDFOR~ lOlL--BBL. FLOW TUBING ICASlNG PRESSURE CALCULATED OIL-BBb GAS--MCF. PRESS. '1 24-HOUR RATE 17-1/2'!4425 sx Arcticset II cmt 12Zl]/411500 Sx C1 ass G cmt I J 27. TUBING RECORDI SCREEN (MD) SIZE DEPTH SET (MD) _~ '7~ R236' R221 ' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED N/AI '"" -'-'-' ' - ' .., . I WE LL STATUS (Producing or shut.In) GAS--MCF. ' ";'WATER--BBL. I GAS-OIL RATIO I I I iWATER-BBL. ] OIL GRAVITY-APl (CORR.) I TEST WITNESSED BY PACKER SET (MD) 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) 32~ Ll~l; ~)F ATTACI-~ME,NTS urliIing H~s~ory & Gyroscopic Survey 33. I hereby certify that thej~regoing an~l attached_information is coFnplete and correct as determined from all available records. SIGNED - _ TITLE ' ' Dril 1 lng Engineer ! *(See instructions and Spaces for Additional Data on Reverse Side) DATE 10/15/79 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPT None Top Sadlerochit 9045' 8177' Base Sadlerochit 9542' 8576' : 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER, To be sent by our Geology Department under a separate cover letter at a later date. ! Drilling Hi story WGI #2 (23-2-11-14) API 50-029-20379, ADL 28302, Permit No. 79-43 Spudded well @ 1500 hrs 8/8/79. Drld 17-1/2" hole to 2750'. Ran & cmtd 13-3/8" 72# R-3 csg @ 2731' w/4425 sx Arcticset II cmt. Installed & tstd pkoff, did 90 sx top job. NU & tstd BOP. Drld shoe, cmt, & 10' new form. Tstd form to 12.5 ppg MW equiv. Drld 12-1/4" hole to 8691'. Ran & cmtd 9-5/8" 47# S-95 & N-80 csg w/5OO.sx Class G cmt, shoe @ 8671'. Installed & tstd pkoff. Tstd BOP. Dwnsqzd 9-5/8" x 13-3/8" ann thru lower FO w/300 sx Arcticset I cmt. Circ 285 bbls Arctic Pack followed by 75 sx Arcticset II cmt. Drld shoe, cmt, + 19' new hole. Tstd form to 12.5 ppg equiv MW. Drld to 9201' Bit torqued up. Pulled 20' off btm. Lost circ. Pumped 60 bbls LCM pill. Filled ann w/125 bbls H20. SI well. Built mud volume. Pulled 11 stds, bit @ 8131'. Regained circ, no further loss of mud. Staged 5 stds into 8600'. Lost 79 bbls mud. Built pit volume. Circ btms up. Ream & washed 8918' Stk pipe worked free. Drld to 9222'. LD 13 jts E pipe. Drld to 9358'. ~umped LCM pill. Held blowout drill. Chgd BHA. Drld to 9655'. Ran 7" l nr, top set @ 8346', shoe @ 9650'. Cmtd w/405 sx Class G cmt. Ts.td BOP. Tstd lnr lap. Displ wtr w/CaC12. Ran GR/CNL/CCL from 9569'-2700'. Ran gage ring, jnk bskt & CCL f/8345' - sur. Ran gyro from 9572'-sur. Ran 7" tbg. Tstd control lns& hgr to 5000 psi. ND BOP's & NU X- mas tree. Tstd X-mas tree to 5000 psi. Displ CaC12 w/diesel Set pkr. Ran SSSV & tstd to 5000 psi. Press up for long term tbg tst. Reieased riq @ 0830 hrs 9/3/79. ~~ i Eastman l , Whipstockl)~ A PE'I'ROLANE COMPANY REPORT of SUB-SURF.4CE DIREC TI ON~ L SURVEY ARCO 0IL & GAS COMPANY WGI 2 WELL NAME PRUDHOE BAY~ ALASKA LOCATION JOB NUMBER A879 G0440 TYPE OF SURVEY Gyroscopic DATE 9-1-79 SURVEY BY Bob Kiser OFFICE Eastman Whtpstock P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349.4617 TWX 910.881-5066/Cable: EASTCO September 4, 1979 ARCO 0il & Gas P.O. Box 360 Anchorage, Alaska 99501 '~ell Number: WGI 2 Location: Prudhoe Bay, Alaska Type of Survey: Gyroscopic Date: 9-1-79 Method of Computation: Radius of Curvature Surveyor: Bob Kiser Job Number: A879 G04~O Attn: Bob Hines Dear Mr. F_ines, I am enclos~_ug the original and one copy of the Gyroscopic Survey run on the ahove mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, · Bob Miser District Operations Surveyor cc: file eEC. 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A T t!: ~i~ i) ]i ~!.~'i',::~iH'C:l!i] i) i i:;:l:C'i" I OF~ IEUti:F(: ill TY F:' ii: IE "t" ]') H ill F' I!: IE 'i" F:' IE Iii; "1" F:' IE tiil "1" F:' lie Ii: 'i" 1::' F:' R O,..I Iii; E'.: T liil i) ri iii ~' ]. 18 , ; j~ Eastman ~ ~'~ ~ Whipstock ~ A PETROLANE CCMPANY REPORT of SUB-SURFACE DIREC TI ON~ L SURVEY ~d~C0 0IL & GAS COMPANY WGI 2' WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUM8ER A879 GO~0 DATE 9-1-79 SURVEY BY Bob Kiser OFFICE i"'i t:i; A S U R E D D I:;; I 1::' T 0 R I I::' '1" I::' li!] Iii] T 0 4'"i D 0 ~ 0 0 0 100~ 0 0 0 200 o 0 0 0 · 400~ 0 0 0 10 C' 0 ,.. 0 30 N 4 Iii] :1. 1 (').. O. ~ 0 .45 i".~ .,;.":' E 120()~ 0 15 iq I W 1300 ~ 0 0 0 1 .,<) 00 ,, 0 0 0 15() 0., 0 0 0 16 ()() o () 0 0 17 C, 0 .:. 0 0 0 1 iii 00'' () 0 0 1900 ~. 0 ]. !9... ,...c' 79' W 2000 ,, 0 0 0 2100 o 0 0 0 "':' "':' ("30 (") 0 0 230 C, + (') C, 0 "':' 0 .,:. 400, 0 0 "') 5 0 (") () (") 0 26 () (), (').. 1 .'9 M .~.;' 6' I.,). 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',::.';, 00 iH 1249, ~::J 4 W 1400° 7' S it :!., ;'..~ 8 W 0 ~, C,"" 1448, '2 ....... iii 6 !-'5,"; 0 iii: 8 N1 .~. ,, :.:., '''> o ~. 4 :.'~ W 145 S , ;.i!: 5 N 6.3; (ii W 1 ,, · .., 0 ',:;! :'.¢,..681 ;':~ 6 N 1 S 44 ,, 46 W 1 '::' "; .... 1 ":'" ~, ":' ".~ ,. ,.., ~., 7 ,, :....: 6 N 6 S7 W 0 ,, 7 1 ,.¢,.J 7,04 706, ,.., 5; N :1. S 9 '.;':'.', 93 W 15 ~'!> 1 ,, 90 N,.,..:'. ,., TM 6 W 0., 60. ....... 1 ,.515, / 9 7 S 3,,. 70 bi 1442, b: 6 W 1618,69 N ,.. ,.,"; ':~ 3. W ....."'~, ::~ .I. ~::.,., 00, 36 0 N 61 W 100, 6042° 6,,. ''~ 6 a, 00,, .7.'; 60 N 61 14 .1. 00, 612 S, 52 6700, 36 0 N 60 W .100, 6204,42 68000 S6 0 N 60 W 100, 6285,S;.'5 6900, ;.:¢6 0 iq 60 W 100, 6S66,2S :1.672 ~ 5:1. 762~20 N 1494027 W :1.677~44 N 62 58 W 0°00 · I;'" ; 1 '?. ;'.;¢ 1,.,..."' 4 790,70 N 1 ,.¢'::' 45,68 W :1. ":',- ,..,,.. TM A ~ 18 N 4: .,..'> ,.'.. 4 W 0,, C, 0 1789 .... ) 8:1.9 64 N 1596 84 W 179.4091 N d:,'.?. '::;(", W 0 59 :1.84(ii075 849,0S N 1647,74 W i (ii55,62 N 62 44 H 0° 00 71:.,,, 42 .......... :1. 907,51 8 .... ' N 1 o 9 ~:::,o" ,.,'::' W:t. 9120 S,.", N c, :-2 ;'..'~; 9 W 0,00 "1" i:i: LJ iii: i":'ili!:[:':'~i~k, fi:i:iii::[:~ ,O f;: ]: t::' "l" .EI F~: ]: I::' "I" r:OLJl:~:Eii;tli: k~ I!!: I:;: "I" ]: C: /."~ L.. k,~E:I:;.:'i']:C:F~I... I:;: I!i: C 'f ~::~ N 0 L.I 1... i:'-~ I:~: [::: 1... 0 fi~ l.J l:;.: ti!: ~3[3(:~l...tii:Ci :0 Iii: 1::' "1" I..I ;q N E.:i I... Ii!: 50:1: i:i: Iii: E:"f' ]: (3 N I... Iii: N (.:i "t' l.i :(:l Iii: t::' 'i" HE; E I::: T :t: (3 FI C O O l:;: :0:1: N i.":. 'i"Iii: E; ii) :1: [i~ "1" ~'::'~ i'..(C Iii: .0:1: F;: Iii: C "[' :l: 0 N E; Iii: L,~ I!i: 1:~: :1: 'i" Y i::' i!i: E: "i' .i') i',i :1[:~ 1::' I!!: 1!!: 'T' F:' E: E: 'i" F' E: I!i: "l' I::' I!i: I!i: "1" i::' i!i: l!i: "1" .t:l i'-'i [j (:.:i / :l. 00 1::' "1" F:' I:~: (:),J I!i: C: T Iii: .0 ~"i B 9 :t. :1. E!: Eastman September ~, 1979 P. O. Box 4-1970/Anchora~Te, Alaska 99509/(90?) 34,¢4617 TWX 910-881.5066/Cable: EASTCO ARCO Oil & Gas P.O. Box 360 Anchorage, Alaska 99501 Well Number: WGI 2 Location: Prudhoe Bay, Alaska Type of Survey: Gyroscopic Date: 9-1-79 Method o£ Computation: Radius of Curvature Surveyor: Bob Kiser Job Number: A879 GO440 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Gyroscopic Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the £uture. Sincerely, Bob Kiser District Operations Surveyor cc-. file enc, Oir~tional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/SaJes/Woddwicle I:;~ Eil (i~ E) F;~ iEI (;ii F:' !i~ LJl:;~ ~...-* lie Y I , 15110 , ALI::iSKAi i J I VFF;~-t"ICAI_ SECTION CALCULATED IN PLANE OF F'ROPOSAL '" DIRECTIONI N 58' DEG. 35 Hi'N. W , . . RECORD OF SURVEY RADIUS OF CURVATURE HETI--IOD AF(CO WoG~I,, -~.'2 B .1: R E C T .'1:0 N A I... S I N G L E S I.-I 0 T COMF'LITA T I ON l' l: ME DATF 08 .~ S5: 08 06-SEF'-79 F:'AGE NO o ~' fl 'f'RLJE ,'v; "' C:' 7* t' .... . . j,I::.A,..~Ut,.,:..Lt DRIF'"I" DR'[F'T CCil..IRSE VERTICAL VERTICAL SUBSEA R E C 'lr' A N O U I_ A R C L 0 S U R E: DOGL. E:I D IF_' F:' l' H A N G L E D I R E C T I 0 N I, E N G T i"1 l"lE F' T t-'1 S E C T I 0 N T V D C 0 O R D I N A T E S D I ,.) ][ ,.~ N Ci:i: D I I::,' E C T I 0 N S E:. Vi:: r~ I F'EET D i'j D M FEET FEET FEET FEET FEET I:;EE'F I) Pi DG/1001 O, 0 .0 0 0 O. 0.00 486, 0 45 S 2]. 0 W 486. 485.99 11.51S. 0 SO N S6 0 E 1027. 1512.92 2755. ' JO 3.5 S 86 0 E 1242. 2754.90 2816. 2 ~0 N 66 0 E 61. 2815.88 o.oo -0.57 455.99 --8.27 1482.92 -11.2.59 2724.90 -13.o8 ~ ~7b~ .88 0,O0 2.97 S , 6,65 S ~.S5 S S,lO S O, O0 0, O0 0 0 O, 00 3..14 W 3.1E.', S 21 0 W ( "~; 5,6S E 8.71 S 40 17 E 0,~ :2 12.70 E ].;.:,].4 S 75 14 E O.OS 14o13 E 14,47 S 77 S8 E: 2879. S 0 N 6 0 E 2972. 6 45 N 9 0 W 3065, 7 45 N SO 0 W S:L57. 10 0 N 45 0 W 3250, 12 1.5 N 63 0 W ,.,':~,90. 11.7 1~',-, ~"~69 '0 W ,'-5.700. 2~ SO N 65 0 W S916. S2 0 N 64 0 W 4100. SS SO N 65 0 W 4~,9,.,. SS SO N 6S O W · · 63. 2878.80 -13.91 2848.80 93. 2971.45 -9.62 2941.45 93. 306S.70 ......... -0.57 3033,70 ,?2. 3154. o 12.64 512 .6o .' 93. 3245.84 jli;;''.30,45 3215.84 240. 3477.86 91.00 3447.86 210.. 3674.63' 163.28 3644.63 216. 3865.61 184, 4020.35 492. 4430~63 .93,23 N 263,22 3835,61 -.136,48 N 362,22 3990,35 179,34 N 632.55 4400.63 298.37 N ,,. 0.76 S 15.83 E 7.11N 15.62 E 18.'11' N 11.1,73 E 29,34 N 3.11E 39°85 N., ..... 11.35 W :' 67.12 W 134.38 W 225.07 W 314.911. W 558.96 W 93.22 N 46 4 W 163.55 N 55 15 W 263.22 N 58 46 W 362.39 N 60 20 W 633.61 N 61 54 W · 490S. 3'2 SO N 63 0 W 5397. 31. 11.5 N 64 0 W 5876. ;fl 0 N 63 0 W 6357. 34 SO N 61 0 W 6560. 36 1~-~, N 6:>~. 0 W 311, 4691.45 801.42 4661.45 494. 5110,95 1061.32 5080.95 479. 5520.99' i308.02 5490.99 481. 5925.46 1~67.71 5895,46 203. 6090.98 1685.07 6060.98 · · 375.27 N 709.88 W 802.97 N 62 8 W 491.66 N 943.33 W 1063.77 N 62 28 W 602.i4 N 1164.92 W 133.1.34 N 62 40 W 724.28 N 1S94.6S W 1571,48 N 62 SS W 780.S5 N 11.497.90 W 1688,98 N 62 29 W ·, 4.42 4.23 S,02 3.49 4.42 ':2. I G :3,05 0.87 0.22 .)3:2 0.27 0,12 0,76 0.91. 6972. 35 45 N 62 0 Id .7739. 29 0 N 59 0 W 7995. 29 0 N 58 0 W 8260. 32 0 N 53 0 W 8870+ 36 O N 44 0 W 412. 6424.29 1926.81 6394.29 894.04 N ].711.7S W 193]..15 N 62 25 W 767. 7071.70 2337.00 7041.70 1096.14 N 2068.94 W 2341.37 N 62 5 W 256. 7295,60 '2461.11 7265.60 1160.99 N 2174.75 W 2465.25 N 61 54 W 265. 7523.91 2595.S5 7493.91 1237.13 N 2285.55 W 2598,89 N 61 34 W 610. 8029.52 2930.78 7999.52 1462.88 N 2540.71 W 2931.76 N 60 4 W 0,12 0.90 0,19 1,48 1.05 9029, 37 0 N 38 0 W 9152. 37 15 N 39 0 W 9399. 36 0 N 39 0 W 9585. 35 SO N 39 0 W 159. 8157.33_ 3020.89 8127.3S 1534..~3~_ N 2601).73,- W 3021.27 N ,.,':'9 ~°9 W 123. 8255.40 3090.62 8225,40 1592.32 N 2648.94 W 3090,69 N 58 59 W 247. 8453.63 ' 3229.44 8423.'63 '1706,84 N 2741+67 W 3229.56 N 58 6 W 186. 8604,58 3331.83 8574.58 1791,c'9,. N 2810,06 W 333©~,45 N 5'7.29. W 2.33 0,53 0,51 0.27 F"INAL. 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'__, ...... : _.L :._=.'_.: _ _.: ..... :....:7_.~_.: ......................... '-':'-':-;'-'--' :'-'F' '--~-'~ -~-~--~-'----~'--I-, : --'-'-i-- ---~-~--~-- '--' : I 7 ~;- ,. ~ . . . ' . , . ! : ' ' , ,-- . , ., ,. ,' / · h .......... i ......... :- ? ...... -F-'!,--t--,~ ........ I"F'~ -~ .... F':-: .................. --:-f .... :-?"--: --:--F-i-,-:-?-~--~ ; ~ J': .......... 1 ......... ~'-: ......... -~-',-'-t--~-;--:'?i-~--+-: ........ t'---~-.~ ..... :- .......... t''-~'- ;'-'~'-~--'--'~-?'-'-~-' .--~'I__~.7:--:7_.':T.:.-_.:_-_'L-.c::: .~ _:._F',.;-::F.7-?'_-:_-: , . : ; b:-~-..::: ---~-~r : t. ---b--- ..........--.--~- .-:-. :::::--'.~1--'-~ ' ¢7 7-- ....,--~-' "---"-;-'i-'-'+'," ',' :! . : :- 'r · , - ! . ..... , :--i-' .......... -*-+--~ .... , ..... ?'~-P'---- 4 . i . · . i 4 i ,, , l ,, . j __ ..... _'--:2 i~i.i ARCO Oil and G,.~?'-'mpany Alaska Re,. Post Office iBox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 4, -1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SubJect:? ~G.~I ~2.,.~JPermlt No. 79-43 ~1~-~]~0, Permit No. 79-21 DS 12-3, Permit No. 79-41 DS 14-6, Permit No. 78-65 DS 14-8, Permit No. 78-67 CPF-1-23, Permit No. 79-42 Dear Si r' Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:-jh Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form No. P-4 SUBMIT IN DUPLICATE REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · 5. APl NUMERICAL CODE 50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME O,L []] GAS [] Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME ARCO Oil and Gas Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 WGI #2 (23-2-11-14) 4. LOCATION OF WELL 376'S & l184'W of NE cr Sec ll, TllN, R14E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. 79-43 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of August, 1979 Spudded well @ 1500 hrs 8/8/79. Drld 17-1/2" hole to 2750' Ran & cmtd 13-3/8" 72# R-3 csg @ 2731' w/4425 sx Arcticset II cmt. Installed & ts~d pkoff, did 90 sx top job. NU & tstd BOP. Drld shoe, cmt, & 10' new form. Tstd form to 12.5 ppg MW equiv. Drld 12-1/4" hole to 8691'. Ran & cmtd 9-5/8" 47# S-95 & N-80 csg w/,5,00 sx Class G cmt, shoe @ 8671'. Installed & tstd pkoff. Tstd BOP. ~Dwns~]zd 9-5/8 x 13-3/8" ann thru lower FO w/300 sx Arcticset I cmt. Circ 285 bbls A~{c~'~--~61-16~ed by 75 sx Arcticset II cmt. Drld shoe, cmt, + 19' new hole. Tstd form to 12.5 ppg equiv MW. Drld to 9201' Bit torqued up. Pulled 20' off btm. Lost circ. Pumped 60 bbls LCM pill. Fille~ ann w/125 bbls H20. SI well. Built mud volume. Pulled 11 stds, bit @ 8131'. Regained circ, no further loss of mud. Staged 5 stds into 8600'. Lost 79 bbls mud. Built pit volume. Circ btms up. Ream & washed 8918'. Stk pipe worked free. Drld to 9222'. LD 13 jts E pipe. Drld to 9358'. Pumped LCM pill. Held blowout drill. Chgd BHA. Drld to 9655' Ran 7" lnr, top set @ 8346', shoe @ 9650'. Cmtd w/405 sx Class G cmt. Tstd BOP. Ts~d lnr lap. As of 8/31/79 cond & circ CaCl2. 14. Ihereby~~efoz~~SiGNED. TITLEDistrict Drilling En§ineerDATE ,_~~_a,~. /~. ,~/7~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. North American Producing Division North Post ('J~r~,..e ,.70× 3SO Anchorage, Alaska 995-10 T.e'~:~ri:-"-- ¢,. 907 277 ..... ~-.c. 3 .... ~' September 7, 1979 Reference' ~nclosed are Directional Surveys of the following ARCO wells' 10' 8/31/79 b~gnetic bbltishot Eastman ~d~ipstock 9/1/79 Gyroscopic Eastman ~ipstock /~'lease sign and return the a~tached copy as receipt of data. Very truly yours, K. J. Sahlstrom North ~ngineering TRANS,.II R~FAL # 319 DISTR'[B[~ION North Geology Drilling Eng. Manager R & D Geology State of Alaska ~xxon Mobil Getty Sohio Marathon P]~illir~$ Ct~evron lqor!h Ams.:~"~ Producing Division Norlh Alas', .,istricl Post Office £~ox 330 Anchorage, Alaska 995~0 Teteohone 907 277 5537 September 7, 1979 Reference' _ Enclosed is a Directional Survey of the following ARCO --~- wez± WGI #2 8/13/79 Single Shot ease sign and return the attached copy as receipt of data. Very truly yours, K. J. Sahlstrom North Engineering TE&NS~ETTAL # 318 DISTRIBb~I'ION North ,~,~olo~}. Exxon I)ri 11 ing Mob i 1 Eng. Manager Getty R & D Sohio Geology Marathon State of Alaska Phillips D & M Chevron Alaska Oil and Gas Conservation Ccmmissicn Hoyle II. Hamilton Lonnie C. Smith Cau~issioner Ben H. LeNonman Petroleum InspeCt August 16, 1979 B.O.P.E. test on AR00's W~I#2, Sec. 2, Ti/N, R14E, UM P~___w!hoe Bay Unit Friday, August 10 - I de~ my hc~e at 7:00 AM. for a 7:30 AM shc~up and 8:40 AM departure via the ARCO Charter for Deadhorse arriving at 10:20 Nd. An attempt to reach Deadhorse the evening before resulted in our depl~ in Fa/xbanks due to bad weather and our subsequent return to Anchorage at 11:50 PM. B.O.P.E test concluded on ARO0's DS 3-10, the subject of a separate report. Sa.turday, Aq.~.t 11 - I transferred to Parker Rig %141 ~here I m~t with ARO0 Drilling Foreman Ben Davis and Pazker Rig Pusher Tc~ Black. Nippling up was in progress and modifications to the choke manifold were underway per this agency's request. These modifications were ccmpleted at 3:00 PM and it was decided to test the manifold while the manifold house was on the ground. Nine valves and eighteen flanges successfully tested to 5000 psig. Tests began at 5:15 PM with the shoe on the 13 3/8" at 2731'. Kelly cock, upper pipe rams, wing valve in the choke line, and check valve in the kill line tested to 5000 psig. Lower Kelly valve, outside valve in the kill line, and HCR valve in the choke line tested to 5000 psig. Inside wing valve in the k~ll line then tested to 5000 psig. Lower pipe rams tested to 5000 psig and annular preventer tested to 3000 psig. Accumulator pressure was 3000 psig. With the pumps off both ram preventers and the annular preventer w~re closed and the HCR valve opened simultaneously. Accumulator pressure fell to 1350 psig and stabilized. The pumps were then turned on and a 200 psig buildup was recorded in one m/nute, fifteen seconds. Each of the four N2 ~ottles tested 2000 psig. ~ile pulling the test joint to test the blind rams I toured the location ~ahich was well organized, the reserve pit well built, the rig in good repair, and the well sign was in place. The blind rams and all flanged coD_nections to the choke manifold then tested to 5000 psig. The manual adjustable choke was free moving and the Swaco superchoke actuated. Both ball and dart type floor valves were in place. Tests w~re concluded at 6:30 PM and a field inspection report prepared with a copy given to Ben Davis, a copy mailed to Bob Hines, and the original attached to this report. .~~ ~_!~ - SSV and SSSV tests began on Drill Site #1, the subject of a separate report. ~.Mg~ ¥, Augus_t_.!3 - SSV and SSSV tests ~let~d o~ Drill Sit~ %1 and SSV and SSSV ~TS-~ on Drill Site #5, the subject of a separate report. ~' A~ugust 14 - ssv and SSSV tests on Drill Site %5 c~leted at 6:30 PM. i-'departed ~adhorse via wien Flt. #20 at 9~35 PM arriving in Anchorage via Fai~ at 11:55 PM. and at my ~ at 12~25 AM. In su~, I witnessed successful B.O.P.E. tests on ARO0' s ~1%2. ~ ,~, ~I'Oil and Gas Conservation Comm,.. Field Inspection Report Drlg. Permit No.~.._ Well/q~l. eWam~m Sec~:~ TI. iii/ R/~/Z~-,~!.-M Operator ~l,~_~,~.~ Repr~esented bY'~c--~qL~. ,i~),~/gN,~ Name & Number Satisfactory Type Inspection Satisfactory Type Inspection Yes (~() (~-)- ( ) (~' ( ) (~Y () () () () () () () () () () () () () No Item (~,~Location,General 1. Well Sign 2. General Housekeeping 2. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. Yes (~-)- ( ) (~() (~- ( ) (.~)-- ( ) (~-' ( ) (~() (~() (~ () ) No Item (1,~7' BOPE Tests 15./~Casing set 16 T;$s'c fluid-('~')%~t~ )mud ( ) oil 17. Master Hyd. Control Sys.-~sig 18. N2 19. Remote Controls 20. Drilling spool- ~ "outlets 21. Kill Line-(~Check valve 22. Choke Flowline (~-~-TqCR valve 23. Choke Manifold No. valvs~ 24 Chokes-(,;~)q~emote( )Pos.(-~j 25. Test Plue-(~l~ellhd( )csg( )none' 26. Annular Preventer~psie ( ) Final Abandonment i (~)~ ( ) 27. Blind Rams~sim ( ) ( ) 11. P&A Marker (~,~7~ ( ) 28 Pipe Rams.~'~psiq~ ( ) ( ) 12. Water well-( )capped( )plugged (~/" ( ) 29. Kelly & Kelly-cock,~i~psig ( ) ( ) 13. Clean-up (~'~() 30. Lower Kelly valve~~si~ ( ) ( ) 14. Pad leveled_~/ (~)~() 31 Safety Floor valves-(~BV /~s~t~l~rt Total inspection observation time/_/~?'hrs/~tlm9~ Total number leaks and/or equip, failures ~ Remarks ~'c~-~=~r ~ .~~..~ ...... days or when ready Inspected by ... __ ~' DateJ~-//,~ July 24, 1979 Prudhoe Bay Unit WGI #2 Atlantic Richfield Company Permit No. 79-43 Sur. Loc.: 376'S & i184'W of NE cr Sec 11, TllN, R14E, UM. Bottomhole Loc.: 1320'N & 1320'E of SW cr Sec 2, TllN, R14E, UM. Mr. P. A. VanDusen District Drilling Engineer Arco Oil and Gas Company P. O' Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the ak~ve referenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18-, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to c~,~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. P. A. vanDusen Prudhoe Bay Unit WGI #2 -2- July 24, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly · --.. ~ ~' C ~,"-. ' :/'/" C~issioner of Alaska Oil & Gas Conservation Co~ission Enclosur~ ~C: Depar~ent of Fish & G~e, Habitat Section w/o encl. X Deparment of Enviro~ental Conservation w/o/encl. ~xDepar~ent of La~r; Supervisor, Lair Law Compliance ~,...~ivtsion w/o enel. ARCO Oil and Gas' ,pany Alaska Regio¥, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July ll, 1979 Mr. Hoyle Hamilton State of Alaska A1 aska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: WGI #2 Dear Mr. Hamilton: Enclosed herewith is our Application for Permit to Drill WGI #2, the $100.00 filing fee, and the required survey plat. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401' REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [X'] DEEPEN [-'] b. TYPE OF WELL OIL GAS WELL[] WELL [-3 OTHER Gas InjectionSINGLEzoNE 2. NAME OF OPERATOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P.O. Box 360 Anchoraqe, Alaska 99510 4. LOCATION OF WELL At surface 376'S & 1184'W of NE cr Sec ll, TllN, R14E, UM At proposed prod· zone 1320'N & 1320'E of SW cr Sec 2, IllN, R14E, UM SUBMIT IN TRI. .,TE (Other instructions on reverse side) MULTIPLE API #50-029-20379 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 11. SEC.,T.,R.,M.,(BOTTOM Oil Pool HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 13.' DISTANCE IN MILES AND DI~ON FROM NEAREST TOWN OR POST OFFICE* 12. 9 miles North of Deadhorse, Alaska ~ 14. BOND INFORMATION: r~E Statewide Suretyand/orNo; Federal Insurance Co. #8011-38-40 Amount $100,OOQ 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1320-' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. · 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTH 9665 'MD, 8654'TVD -, 17. NO,ACRES ASSIGNED TO THIS WELL 80 20. ROTARY OR CABLE TOOLS Rotary . 2000' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) . 22. APPROX. DATE WORK WILL START 49' RKB August 1, 1979 23. .. . PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 H-40 80- 250 sx PF Il to _qurfaco_ 17-1/2" 13-3/8" 72 MN-80 2700 Circ to surface-approx. 5500 sx 12-1/4" 9-5/8" 47 80&95 8800 -+1000' cmt column on first stage plus 300 sx on second stage 8-1/2" 7" 29 N-80 9665 ADprox 350 sx Atlantic Richfield Company proposes .to directionally drill this well to +9665'MD (+8654'TVD) to produce the Sadlerochit zone. Logs wll be run across selected .intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 7" 29# N-80 tubing, packer & necessary pro- visions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. A 20" 2000 psi Hydril and diverter system will be used on the 20" conductor. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dkectionally, give pertinent data on subdurface locations and measured and true vertical depths. Give blowout preventer program. 24, I hereby certif~hat the Fo.r%oing is T-~4e and Correct DA= 7////7~7 roLE District Drlg. Engineer '/ ! CHris space for State office use) SAMPLES AND CORE CHIPS REQUIRED []~s _~k~_o DIRECTIONAL SURVEY REQUIRED ~ [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. ~f APPOVED BY%.. ~ ORDER OF THE APPROVAL DATE -r,~l ~r 9,1 1 o'70 TITLE Oznm~ssioner *See Instruction On Reverse Side DATE. 7/24/79 Protracted Section Line 1209 1184 - I --- AS-BUILT WELL No. I ! LAT 70 o 19'42,634" LONG. - 148°29' 58,597" ~ WELL No. Z 13°26' I LAT. 70° 19'4 1.476" LONG. 148°29'57,861'' · -o I WELL No. 3 ,, :z: ~: JLAT. 70° 19'40.3~13,, 2 I / LONG. 148o29'57. I 12 /WELL No. 4 I. LAT. 70° 19' 39.170" 0 ~ LONG. 148 29 56.;599 Y 5 972 002.90 X 684 985.72 Y 5971 885.82 X 685 OI 3.80 Y 5 971 769.08 X 685 041.62 Y 5971 652.66 Y 685 069.67 1159 1154 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN. AS-BUILT SURVEY MADE BY ME OR UNDER MY SUPER- VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE SU RVI~,¥OR I I Chanqed title No. REVISION ~:~,~.. J7/79 JGDI ARCO No. AFE HVL No. / ATLANTIC RICHFIELD CO. AS-BUILT WEST INJECTION SITE. WELLS 1,2,;5 8~4 LOCATED IN PROTRACTED SECTION I I, TII N, R 14 E, U.M., ALASKA PREPARED BY HEWITT V. LOUNSBURY 8[ASSOC. 723 W. 6TH. AVE., ANCHORAGE, ALASKA DATE JUNE 1979 SCALE I"= 300' CHKD. BY GDD FLD BOOK SURFACE DiVERTER SYSTEM 3 1. 20" Bradenhead 2. 20" 2000 psi drillin§ spool 3. 20" 2000 psi annular preventer 4. '6" butterfly valve~ e e 7'. 8. 11. 12. 13. 14 .' 15. 16. 17. 18. 19. Is a regis , ..... Is roll located proper d±stance' from property line .............. Is well located proper distance frcm other weIls ..... ... .............. ,. Is sufficient underdicated acreage available in this pool Is Well to be' deviated .... ~, .' .......... . ~., ....... Is operator the only affected party ~.. ,... :~ ..... · . Can permit .he approv~ before ten-day w~it ........ ...'. Does Operator have 'a bond'in fOrce . ~ ...... '..' ': ~ '." ..... · · · Is a conserVatiOn order needed ,.. ...................... · administrative ' ' approval needed' ' · ~ , ~ Is conductor string provided ' ' ' ~ ~.e eee e · · ee ee ee ee ee'ee ee eee ee · · · · · · · e e e e Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ..................... Will surface casing' protect fresh Water zones ........ . ............... Will all casing give adequate safety in collapse, tension and burst.. Does BOPE have sufficient pressure rating - Test to .~0o psig .. ~. Approval Rec~_nd~: · . Item' Approve (1) Fee ~ (3) A:]n~.' ./("']g.,;~ . (4) cas . (5) mP . Additional Requirements: Geology: . Engineering: Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX~ ., No 'special'effort has been made to chronologically organize this category of information. '117171'1777 77 ? 17-17777 77 '11 77 ?? 77 '17 77 77 ?? 11 6b~666 666666 6~ 66 66 6~ ~6~66~6~ 66666~66 66 66 b6666b 666666 6~ *$TA~'fT*. U6t:,I-< PCAb [1070'? ~60b46J ,]:, Jt. Jb SHIP 51~;L4. 7696 l) A'£k., 1[0-AUG-80 1.0:05:.~9 tvl U N 1 '.1" [') P 5 ~'~ ~$ F, b 10 B 37 .A P R- 8 0. ,* ;5 T A. H, * *~;rARl't.' LiS.'.L14 E~.CA,L, [[0707,bO~4b.i ,3LJ[!s 51:ilP SE,~. 7696 [')ATk, IO-AIJG-80 10:05:39 11 II, 1 I I1 I1 Ii I 1 I 1 11 ,t 1 ,[ 1 '11 t 1 PP PP PP PP Y T T '.1.~ T ':r T '~ S E; (.~. '7 e, q e, ! O-AIIG-80 DA'iE lO-AUG-80 09; b5: 08 1 0: Ob: 39 VtsNt[IRA~ (.:Ai.,i~GPt~[A 9 JO03 ~CCC ~'CCC 1 1 1 1 1 ,[ 1 1 1 11 1 I 1 J, I Iii, I1 Il I1 11 I1 I1 ,IL 1 I, l i 1, 000000 00 (,) 00 i,) 11 O000OO 000000 I 1 O0 O0 O0 O0 111 l O0 O0 0() UO I 111 O0 0000 O0 f) O00 1 1 O0 0090 0() OOOO 11 00 00 00 (') 0 00 00 i 1 00 00 0 O 00 O O 00 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 00 O 0 0 o 00 1, 1, 00 00 00 00 11 OOOO00 OOuo00 11111. 1 OOfJO00 OOOO00 11. 111. 1 *b'I'ART* L.iSkR [-.'CAb t. 10'10'1,t~06461 ,]t. JL~ SHiP ~lbL: I)S~ttlV'L~l.~.L)Ol<O57>[lO'IOT~bOfq~J CREATED: /Si-A(iI~G; I /t~lbll'l.': 110 '769b OA:'I'ts 1 (')- AU G,-, ~ 0 IO'"AUG-80 10:U4:~1 10:0b:39 i 0 ? O?, ~,0646 1-< t.i, i:. L NANt'.: P.C.. A.I.. ~ERVICB N A ~:~ t-_: E b.L'I Ri~.~,g C(iNTINUA'II. Ot',i I',,IIJNBL~: PP, EVIUU$ F:EEL i,~AI~E,: Ct)r,,'~q~N'l'S: hi8 ?t~i-qP~AT CUSTUivlER TAI::E DA'I'E: 801 8/IO TAPE 1 ,t':N (;'1 .t-~: 1 '].'APE NAN.IL: St".,R V 1C t-., t',l A 1'.,$ g: I~ D ..[ 'T TAPE C(jNIV~ENT8 TH l.,$ TAPE O1 D 1GI:I~ I zIED DA'I'g: 80/ 8110 I,~ t ) G P', U 1~,1 U i'~ .,t 1, '-.A U G - 7 9 . F I 1..: E l'q g ,i~t E: t~., O I T ,0 0 1 FiAX]tv~U/~ P,H~S1CAL I~,ECURD ,L, ENGTH: 1024 ~i',['k, 5 1. N i~ U k Iq A T .I, b i~ R E., C U t:4, D GAS CU. '0 I:':H'-I"F;.~ 1C .L'uuL f, VuR.tJ, Ui'.~.L'[',5 A~..L At-:'1' APl APl ["'[J.~b..,~. t L) ['., P 1,' 2 g l-.~ C l~ 1.., 4 l.,.~ R A I. Ci'4L [., t 0 0 0 O O ':,t 0 ~,) 1 f~t¢ O O GAPI. q2 ~1 32 O 0 4 0 O I 6.8 O 0 P U 42 68 .:~ 0 O q: 0 0 I b 8 0 0 C/C 42 ~l, 2 1 0 0 4 0 0 1 ~8 0 0 (;g GR GR Gl, GR GR GR G I-::, V A L, 0 g 5O. 188 3 ~. 313 40.9]8 21.281 42.56 3 14.055 26.90 ~ 40.969 112 , 000 1 ,?,8.125 4u .9~9 3,:. J 25 58.625 8 9.50 () ~3 54.5q4 50.594 53.40~ 56.219 5a.1~8 75.875 51 .'78i 51.781 51.3'75 53.406 41. 344 t8.9 ~8 ,35.719 V t; b U E 21,1.25 27 ,"119 18,1.56 1.1,469 1. 3,023 6.453 2,4. 859 47.563 50,438 44. 438 48.1,50 54. 909 5 ,~. 40 b 42.906 38,000 3b,t~88 3 ~. 344 ~0. .34.0 o 3 55.5q4 g2 ~5. 000 35.25O ~ _~.250 40.875 37.03.1 35. :J75 3 '~. 094 g M t] N 1 C NRA 1' l~ ,R A T r~RAT N.R A T NRA 1' i~ R A '1' NRA'I' N R A 1' NRA T NRA NRA NRA'i' ~ R A T i'~RAI' N R A T NRAI N~A'I aRA'L V AL U k 2.908 3.117 2.500 2. 002 2.102 I. 53,3 2.102 2.961 4. 210 4o430 3. 963 4..~ 13 4.~98 4.551 4,090 3.982 3.b'74 3.3o5 3.385 3. 545 3,~55 3.U54 3.0o-i 3.555 4. Ob3 3, 'i93 3.~45 3.584 3. 395 VALUE 50.594 42.9~9 41. 750 31 .313 3 '7. 750 34.531 41.. 750 27. 7('}3 2~. 90b 31.3{. 3 38.531 40.15b 29.7:19 4 q. 56.3 35.719 19.260 3t~.125 33.71 9 45.781 3,4.125 4b. 5e~ 3 ,42.156 22.484 56.625 38.5,31 35 .'719 32. 125 3,3.7 1 '9 V A b t,j E -43.000 43.1'25 ~ 1. 469 ~9.438 40. 969 45.406 42.063 '~0. 031 44.09'4 41 42.40b 4{). 469 41. ]44 ~6.1,25 /t, ~. 625 48.0,3 l 39.188 5 (). 438 41.094 58. 438 5 0..~ 1 3 50. 656 q2.9O6 q '1.0 63 60.00 0 q6.4~69 45.281 39. 531 NRA ',L N H A '1 NAA '1 N H A 1 NRA'I iv R A I' N R A '1 i'~ R A '1 NHA'I' N R A '1" NRAJ,' ~RA'I N R A 'f N R A 1' NRA T ,N R A I' ,N R A l' i~ R A T NRA'i' ~ R h T NRA T ~'~ g A T VALUE 3.914 4.05[ 3.814 3.~24 .3. U44 3.924 3.904 3.863 4.0O4 3.992 4.141 ,3.96,3 4.121 4.0 4 ,] 4.2~2 ,3.953 4.410 3.9 7 3 5.000 4.3'7.1 4.3,40 4.230 4.191 5. :195 4. 102 4. 172 .3.854 4.648 G R GR (,; .H G }< V ,A L U F,, 35. '719 52.188 42.281, 23.31 3 39.12,.5 ,4~. 625 ,~ 2. e, 88 24.500 4 ,~. 844 23.703 22. 922 -999.25(3 -999. 250 I C V A L U 57. 54. 47. 55. 52. ,47. 5"1. 1. 5 b . 52. 56. '"999. -999. 000 7 50 21.9 5 00 fl 15 688 125 188 781 625 :.1:13 250 250 V ,A L, U E: 4. 801 4.699 4.594 4. 148 5.000 4. '7 '70 0.691 ,'~. 70,3 4.336 ,'4. b 72 -999.250 '.'999.250 ?/ t,~tt¢'IB~h bk }-:ECU~r,)5: 220 I~b;NGIH I. jf Pk, CiJ~'DS: 101'4 ~ ].Lf. 'iBglLE~ 1024 T A P ~: T R A ,i ,L k, ,E 0 1 .D A T E: 8 O/ 8t 10