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Home My WebLink About220-0251 Guhl, Meredith D (OGC) From:Boyer, David L (OGC) Sent:Monday, June 27, 2022 11:49 AM To:Guhl, Meredith D (OGC) Subject:FW: [EXTERNAL]KRU 3S-625 Duplicate Well Official cancellation from CoP. Dave B. From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Monday, June 27, 2022 11:40 AM To: Boyer, David L (OGC) <david.boyer2@alaska.gov> Cc: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Re: [EXTERNAL]KRU 3S‐625 Duplicate Well Yes sir, we already have a PTD but as you mention it expires just before our planned spud date unfortunately. I had asked Victoria if we could do extension or sundry and she mentioned we needed to file an all new permit, so we did. Samantha, could we use this email as the cancellation request for the previous PTD for the well, listed below? Thank you, Matt Smith 432‐269‐6432 From: Boyer, David L (OGC) <david.boyer2@alaska.gov> Sent: Monday, June 27, 2022 11:33:18 AM To: Smith, Matt <Matt.Smith2@conocophillips.com> Cc: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]KRU 3S‐625 Duplicate Well CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Matt, After plotting the 3S‐625 well path on a Geoatlas base map, I learned that there was a duplicate well with the same name: PTD no. 220‐025 and API no. 50‐103‐20825‐00‐00. It was submitted in March 2020 and approved on 08/06/2020 by the Commissioners. Actually, the permit is still active until 08/06 but the proposed spud date is 08/15/2022. 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. 2 We need ConocoPhillips to send an e‐mail to Samantha Carlisle cancelling the original permit, since it cannot be extended by a revision, according to the regs. The new well can keep the same name but will have a new API no. and PTD. Please CC: me with the cancellation e‐mail to I can put it in the current permit digital folder for future reference. Thank you, Dave Boyer AOGCC 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 Mark Vanderhorst Kuparuk Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-625 ConocoPhillips Alaska, Inc. Permit to Drill Number: 220-025 Surface Location: 2569” FNL, 1286’ FEL, Sec. 18, T12N, R8E, UM Bottomhole Location: 914’ FNL, 4374’ FEL, Sec. 2, T12N, R7E, UM Dear Mr. Vanderhorst: Enclosed is the approved application for the permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of August, 2020. Jeremy M. Price Digitally signed by Jeremy M. Price Date: 2020.08.06 16:29:56 -08'00' 6 VTL 08/06/2020 BOP test pressure to 5000 psig(initial test); 3500 psig subsequent tests Annular preventer pressure to 2500 psig Separate fracture stimulation sundry required Cement evaluation log of INT required. Results must be submitted to AOGCC as soon as available NO Delayed to 02/2021 VTL 8/5/20 X 8/6/2020 ate fracture stimulatio 8/7/20208/6/2020 2562/5183*1/.052=9.5 ppg VTL 8/5/20 Submit LOT/FIT results to AOGCC when available.VTL 8/5/20 Results of cement job to be communicated to AOGCC as soon as available. Results of cement eval log to be communicated to AOGCC as soon as available. VTL 8/5/20 VTL 8/5/20 Refer to AOGCC Industry Guidance Bulletin 13-01:Remedial Cementing for Surface Casing. VTL 8/5/20 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3S-625Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2200250KUPARUK RIVER, TOROK OIL - 490169NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view & wellbore profile included.8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO 39 for Torok pool injection.14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For YesKUPARUK RIVER, TOROK OIL – 490169 governed by Conservation Order 72515All wells within 1/4 mile area of review identified (For service well only)YesWell will be pre-produced for about 30 days.16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor installed18Conductor string providedYesSurface casing set to 2775' MD19Surface casing protects all known USDWsYes118% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented production liner w/ frac sleeves22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesDiverter size and route meet regulation27If diverter required, does it meet regulationsYesMax formation pressure is 2562 psig(9.5 ppg EMW); will drill w/ 8.8-10.0 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2044 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableYesThere are no existing wells in the 1/4 mile AOR34Mechanical condition of wells within AOR verified (For service well only)NoH2S is present in reservoir, measures required. Well 3S-620 measured 60 ppm H2S on 12/15/17.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate3/9/2020ApprVTLDate8/6/2020ApprDLBDate3/9/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 8/6/2020Daniel T. Seamount, Jr.Digitally signed by Daniel T. Seamount, Jr. Date: 2020.08.06 12:00:03 -08'00'JMP8/7/2020