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From:AOGCC Records (CED sponsored) To:Gluyas, Gavin R (OGC) Subject:FW: OPERABLE: Injector 04-20 (PTD #1831190) Bled IAP / OAP Date:Tuesday, October 21, 2025 9:14:05 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, October 20, 2025 9:01 AM To: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: FW: OPERABLE: Injector 04-20 (PTD #1831190) Bled IAP / OAP From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, October 19, 2025 5:51 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: OPERABLE: Injector 04-20 (PTD #1831190) Bled IAP / OAP Mr. Wallace, Injector 04-20 (PTD #1831190) IA & OA pressures were bled on 10/17 from 990 to 250 psi and 340 to 20 psi respectively. We will continue to monitor casing pressure for any signs of leakage or impairment of well barriers. 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, March 14, 2024 6:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: OPERABLE: Injector 04-20 (PTD #1831190) Stable IAP throughout monitoring Mr. Wallace, Injector 04-20 (PTD #1831190) has shown stable inner annulus pressure during the recent online injection period post perforations shot on 02/09 (TIO plot attached). The well is now classified as OPERABLE. 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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, February 13, 2024 8:17 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Update Under Eval Injector 04-20 (PTD #1831190) extended monitoring Andy, Continued injection under monitoring and evaluation for additional 30 days is approved. 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.govCONFIDENTIALITY 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: Tuesday, February 13, 2024 7:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Update Under Eval Injector 04-20 (PTD #1831190) extended monitoring Mr. Wallace, Injector 04-20 (PTD #1831190) e-line shot perforations on 02/08 – 02/09. The initially approved 30 day Under Evaluation period ends on 02/17/24. With approval, we would like to continue injection for an additional 30 day Under Evaluation period and monitor for possible communication with the new perfs. Attached is a TIO plot from the beginning of the month. Please respond at your earliest convenience. 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: Tuesday, February 6, 2024 11:53 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]Re: Request to put Injector 04-20 (PTD #1831190) online Andy, Yes, under evaluation is approved. Speaking with Oliver I think the plan you have outlined is prudent. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, February 2, 2024 10:07:15 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: Request to put Injector 04-20 (PTD #1831190) online Mr. Wallace, Injector 04-20 (PTD #1831190) was placed on produced water injection on 01/18/24 and an AOGCC witnessed MIT-IA passed on 01/22/24 to 2,158 psi. The well is still Under Evaluation as we monitor per the plan below. The long-term plan for this well is to plug the existing perforations and add new perforations up hole. We would like to do this during the Under Evaluation period so we can monitor the well with the injection characteristics of the new perforations. We are requesting your approval of the plug set and add perfs while Under Evaluation. I have attached a TIO chart from when the well was placed on injection. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, January 8, 2024 7:33 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Request to put Injector 04-20 (PTD #1831190) online Andy, Plan as per below is approved. 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 privilegedinformation. 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: Friday, December 29, 2023 4:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request to put Injector 04-20 (PTD #1831190) online Mr. Wallce, Injector 04-20 (PTD #1831190) was reported on 10/07/21 as having an increasing IA pressure trend while shut-in. A TTP was set on 10/24/21 and a passing MIT-T to 2,226 psi and passing CMIT-TxIA to 2,176 psi were performed on 10/27/21 confirming competent production tubing and production casing. The well was recently classified as UNDER EVALUATION in attempt to put the well on production for a temporary flowback, but it would not flow. Hilcorp is requesting approval to put the well on injection for up to the 30-days to monitor for IA re-pressurization. If approval is granted, an AOGCC witnessed MIT-IA will be performed when the well is thermally stable. Plan Forward: 1. Operations: Put well on injection 2. Fullbore: Perform AOGCC MIT-IA 3. DHD: Monitor for IA re-pressurization 4. Well Integrity: Additional diagnostics if needed (apply for AA if re-pressurization is observed) Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 7, 2021 12:59 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Not Operable Injector 04-20 (PTD #1831190) slow IA re-pressurization Mr. Wallace, Injector 04-20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4-year AOGCC MIT-IA. The well has been shut in since 10/20/17. During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G. Plan forward: 1. Slickline: Set TTP 2. Fullbore: Perform MIT-IA 3. Well Integrity: Additional diagnostics as needed. 1-year TIO as requested: 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: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA Mr. Wallace, Injector 04-20 (PTD #1831190) is due this month for 4 year AOGCC MIT-IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE and will remain shut in. 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 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 strictly prohibited. If you have received this email in error, pleaseimmediately 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 carry out such virus and other checks as it considersappropriate. 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 strictly prohibited. If you have received this email in error, pleaseimmediately 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 carry out such virus and other checks as it considersappropriate. 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 strictly prohibited. If you have received this email in error, pleaseimmediately 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 carry out such virus and other checks as it considersappropriate. 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 strictly prohibited. If you have received this email in error, pleaseimmediately 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 carry out such virus and other checks as it considersappropriate. 1 Coldiron, Samantha J (OGC) From:Wallace, Chris D (OGC) Sent:Friday, March 15, 2024 3:42 PM To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector 04-20 (PTD #1831190) Stable IAP throughout monitoring Attachments:04-20.docx   From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Thursday, March 14, 2024 6:43 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York  <byork@hilcorp.com>  Subject: OPERABLE: Injector 04‐20 (PTD #1831190) Stable IAP throughout monitoring    Mr. Wallace,    Injector 04‐20 (PTD #1831190) has shown stable inner annulus pressure during the recent online injection period post  perforations shot on 02/09 (TIO plot attached). The well is now classified as OPERABLE.    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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Tuesday, February 13, 2024 8:17 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Update Under Eval Injector 04‐20 (PTD  #1831190) extended monitoring      Andy,  Continued injection under monitoring and evaluation for additional 30 days is approved.    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,  CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.  7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 04-20 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 183-119 50-029-20996-00-00 11890 Conductor Surface Intermediate Production Liner 8831 80 2491 11269 848 11575 20" 13-3/8" 9-5/8" 7" 8593 38 - 118 37 - 2528 37 - 11306 11040 - 11888 38 - 118 37 - 2528 37 - 8396 8210 - 8830 11885 470 2670 4760 7020 11575 1490 5380 6870 8160 11337 - 11768 5-1/2" 17# x 4-1/2" 12.6# L-80 35 - 11072 8419 - 8739 Structural 4-1/2" BAKER FHL , 10994 , 8178 No SSSV 10993 8178 Bo York Operations Manager Dave Wages David.Wages@hilcorp.com (907) 564-4545 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028322 35 - 8232 0 0 0 0 9000 22840 140 480 1344 1920 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Coldiron at 9:09 am, Mar 08, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.07 10:11:12 - 09'00' Bo York (1248) RBDMS JSB 031324 WCB 2024-06-25 DSR-3/11/24 ACTIVITYDATE SUMMARY 1/15/2024 ***WELL S/I ON ARRIVAL*** DRIFTED TO 11,700' SLM W/ 30' X 3.66" DUMMY GUNS ***WELL S/I ON DEPARTURE*** 1/22/2024 AOGCC MIT-IA (ANN-COMM) AOGCC MIT-IA to 2250 PSI ***PASS*** Target = 2044 PSI Max Applied = 2250 PSI Pumped 7 BBLS 130*F Diesel down the IA to take pressure to 2249 PSI for MIT-IA. IA lost 80 PSI in 1st 15 mins and 11 PSI in 2nd 15 mins for a total loss of 91 PSI in 30 min test. Bled IA to 171 PSI and got back 7 BBLS. Pad Op notified of well status per LRS departure. Well on injection. IA, OA=OTG ***Witnessed by WSS HOLT and State Rep BIXBY. ***Tag hung on IA*** 2/7/2024 T/I/O=0/50/0 Assist eline with tubing and flowline freeze protect.Pumped 2 BBLS 60/40 followed by 56 BBLS DSL to Freeze protect the tubing. Pumped 2 BBLS 60/40 followed by 66 BBLS DSL to Freeze Protect the Flowline. FWHP=1000/50/0 2/7/2024 *** WELL INJECTING ON ARRIVAL *** PT TO 250 LP AND 3000 HP. THUNDERBIRD FREEZE PROTECTS TUBING AND FLOW LINE. LOG CORRELATED TO SLB RESERVOIR SATURATION LOG DATED 25-SEPT 2011. RIH WITH 31' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11479-11510' CCL-TOP SHOT: 7.5' CCL STOP:11471.5' WELL SI. SWAB CLOSED. TUBING AND FLOW LINE FREEZE PROTECTED. WELL ON A VAC. *** JOB CONTINUED ON 8-FEB-24 *** 2/8/2024 *** JOB CONTINUED FROM 7-FEB-24 *** PT TO 250 LP AND 3000 HP. LOG CORRELATED TO SLB RESERVOIR SATURATION LOG DATED 25-SEPT 2011. RIH WITH GUN 2 31' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11448-11479' CCL-TOP SHOT: 7.5' CCL STOP:11410.5' RIH WITH GUN 3 31' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11417-11448' CCL-TOP SHOT: 7.5' CCL STOP:11409.5' RIH WITH GUN 4 31' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11386-11417' CCL-TOP SHOT: 7.5' CCL STOP:11378.5' WELL SI FOR NIGHT WITH NIGHT CAP. *** JOB CONTINUED ON 9-FEB-2024 *** 2/8/2024 T/I/O = VAC/50/VAC. Temp = SI. T FL (Eline). T FL @ 450' (11 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:00 Daily Report of Well Operations PBU 04-20 PERFORATE INTERVAL: 11386-11417' PERFORATE INTERVAL: 11448-11479' PERFORATE INTERVAL: 11417-11448' PERFORATE INTERVAL: 11479-11510' Daily Report of Well Operations PBU 04-20 2/9/2024 *** JOB CONTINUED FROM 8-FEB-2024 ** PT TO 250 LP AND 3000 HP. LOG CORRELATED TO SLB RESERVOIR SATURATION LOG DATED 25-SEPT 2011. RIH WITH GUN 5 31' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11355-11386' CCL-TOP SHOT: 7.5' CCL STOP:11347.5' RIH WITH GUN 6 18' 3-1/8" HSD 6 SPF, 60 DEG, 22.7 GRAM GEO CHARGES. PERFORATE INTERVAL: 11337-11355' CCL-TOP SHOT: 9.2' CCL STOP:11327.8' RIH WITH CCL AND HEX PLUG. CCL - MID ELEMENT: 15' SET DEPTH: 11575' WELL LEFT SI ON DEPARTURE. *** JOB COMPLETED *** PERFORATE INTERVAL: 11337-11355' Adperfs are correctly shown on the WBS, below. -WCB PERFORATE INTERVAL: 11355-11386' (2/09/24) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, March 5, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-20 PRUDHOE BAY UNIT 04-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/05/2024 04-20 50-029-20996-00-00 183-119-0 W SPT 8174 1831190 2044 1520 1541 1512 1487 115 310 318 322 4YRTST P Brian Bixby 1/22/2024 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 04-20 Inspection Date: Tubing OA Packer Depth 171 2249 2169 2158IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240122160936 BBL Pumped:7.4 BBL Returned:7 Tuesday, March 5, 2024 Page 1 of 1           2 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: Tuesday, February 13, 2024 7:34 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: Update Under Eval Injector 04‐20 (PTD #1831190) extended monitoring    Mr. Wallace,    Injector 04‐20 (PTD #1831190) e‐line shot perforations on 02/08 – 02/09. The initially approved 30 day Under Evaluation  period ends on 02/17/24. With approval, we would like to continue injection for an additional 30 day Under Evaluation  period and monitor for possible communication with the new perfs. Attached is a TIO plot from the beginning of the  month.    Please respond at your earliest convenience.    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: Tuesday, February 6, 2024 11:53 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]Re: Request to put Injector 04‐20 (PTD  #1831190) online      Andy,  Yes, under evaluation is approved.  Speaking with Oliver I think the plan you have outlined is prudent.    Regards,  Chris  From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Sent: Friday, February 2, 2024 10:07:15 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: RE: Request to put Injector 04‐20 (PTD #1831190) online      Mr. Wallace,     Injector 04‐20 (PTD #1831190) was placed on produced water injection on 01/18/24 and an AOGCC witnessed MIT‐IA  passed on 01/22/24 to 2,158 psi. The well is still Under Evaluation as we monitor per the plan below.       CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.  3 The long‐term plan for this well is to plug the existing perforations and add new perforations up hole. We would like to  do this during the Under Evaluation period so we can monitor the well with the injection characteristics of the new  perforations. We are requesting your approval of the plug set and add perfs while Under Evaluation. I have attached a  TIO chart from when the well was placed on injection.     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Monday, January 8, 2024 7:33 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Request to put Injector 04‐20 (PTD  #1831190) online        Andy,  Plan as per below is approved.     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: Friday, December 29, 2023 4:00 PM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity  <PBWellsIntegrity@hilcorp.com>  Subject: Request to put Injector 04‐20 (PTD #1831190) online     Mr. Wallce,     Injector 04‐20 (PTD #1831190) was reported on 10/07/21 as having an increasing IA pressure trend while shut‐in.  A TTP  was set on 10/24/21 and a passing MIT‐T to 2,226 psi and passing CMIT‐TxIA to 2,176 psi were performed on 10/27/21  confirming competent production tubing and production casing. The well was recently classified as UNDER EVALUATION   CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.   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. 4 in attempt to put the well on production for a temporary flowback, but it would not flow. Hilcorp is requesting approval  to put the well on injection for up to the 30‐days to monitor for IA re‐pressurization. If approval is granted, an AOGCC  witnessed MIT‐IA will be performed when the well is thermally stable.     Plan Forward:  1. Operations: Put well on injection  2. Fullbore: Perform AOGCC MIT‐IA  3. DHD: Monitor for IA re‐pressurization  4. Well Integrity: Additional diagnostics if needed (apply for AA if re‐pressurization is observed)     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Thursday, October 7, 2021 12:59 PM  To: chris.wallace@alaska.gov  Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York  <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Subject: Not Operable Injector 04‐20 (PTD #1831190) slow IA re‐pressurization     Mr. Wallace,     Injector 04‐20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4‐year AOGCC MIT‐IA. The well has been  shut in since 10/20/17. During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure  trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G.      Plan forward:  1. Slickline: Set TTP  2. Fullbore: Perform MIT‐IA  3. Well Integrity: Additional diagnostics as needed.     1‐year TIO as requested:     5    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: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04‐20 (PTD #1831190) Lapse 4 year AOGCC MIT‐IA     Mr. Wallace,     Injector 04‐20 (PTD #1831190) is due this month for 4 year AOGCC MIT‐IA. There are no immediate plans to resume  injection. The well is now classified as NOT OPERABLE and will remain shut in.   6    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        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 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 carry out 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 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 carry out 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 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 carry out 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 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 carry out such virus and other checks as it considers appropriate.         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: Injector 04-20 (PTD #1831190) Additional 30 days of monitoring Date:Wednesday, February 21, 2024 8:55:23 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, February 17, 2024 5:55 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: Injector 04-20 (PTD #1831190) Additional 30 days of monitoring Mr. Wallace, Injector 04-20 (PTD #1831190) additional 30 days of monitoring while on injection has been granted by AOGCC post additional perforation. The clock has been reset. 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: Friday, January 12, 2024 7:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector 04-20 (PTD #1831190) Temporary flowback complete - POI All, Injector 04-20 (PTD #1831190) temporary flowback is complete. AOGCC has approved the plan to put on injection and an AOGCC witnessed MIT-IA will be performed when thermally stable. IA pressure will be monitored for possible communication during the online period. The well remains classified as UNDER EVALUATION and the clock will be reset for 30 days once injection begins. 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 <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 15, 2023 2:42 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; PBE FS2 Field Lead Operator <PBEFS2FieldLeadOperator@hilcorp.com>; PBE FS2 Foreman <PBEFS2Foreman@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; PBE FS2 DS Operators <FS2DrillsiteOperators@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-20 (PTD #1831190) Temporary flowback All, Injector 04-20 (PTD #1831190) is a Not Operable PWI injector with no verified integrity issues. AOGCC has approved temporary flowback of up to 30 days. The well is now classified as UNDER EVALUATION for temporary flowback for up to 30 days. If the flowback period exceeds 30 days, a 10-404 will be required. Production allocation will be reported off 04-22 well slot and 04-22 will remain shut in during the duration of the temporary flowback. A miscellaneous SVS test will be required within 5 days of stabilized production. 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 Sent: Monday, August 23, 2021 2:36 PM To: Alaska JMS User <akimsuser@hilcorp.com>; Alaska NS - FS2 - Field Lead Operator <FS2FIeldLO@hilcorp.com>; Alaska NS - FS2 - Foreman <FS2Foreman@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; FS2 Drillsite Operators <FS2DrillsiteOperators@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Cc: Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA All, Injector 04-20 (PTD #1831190) is due this month for 4 year AOGCC MIT-IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE and will remain shut in. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Junke, Kayla M (OGC) From:Wallace, Chris D (OGC) Sent:Tuesday, February 13, 2024 8:19 AM To:AOGCC Records (CED sponsored) Subject:FW: Update Under Eval Injector 04-20 (PTD #1831190) extended monitoring   From: Wallace, Chris D (OGC)   Sent: Tuesday, February 13, 2024 8:17 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: RE: Update Under Eval Injector 04‐20 (PTD #1831190) extended monitoring    Andy,  Continued injection under monitoring and evaluation for additional 30 days is approved.    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: Tuesday, February 13, 2024 7:34 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: Update Under Eval Injector 04‐20 (PTD #1831190) extended monitoring    Mr. Wallace,    Injector 04‐20 (PTD #1831190) e‐line shot perforations on 02/08 – 02/09. The initially approved 30 day Under Evaluation  period ends on 02/17/24. With approval, we would like to continue injection for an additional 30 day Under Evaluation  period and monitor for possible communication with the new perfs. Attached is a TIO plot from the beginning of the  month.    Please respond at your earliest convenience.    Ryan Holt  Hilcorp Alaska LLC  Field Well Integrity / Compliance  Ryan.Holt@Hilcorp.com  P: (907) 659‐5102  M: (907) 232‐1005    2 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Tuesday, February 6, 2024 11:53 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]Re: Request to put Injector 04‐20 (PTD  #1831190) online      Andy,  Yes, under evaluation is approved.  Speaking with Oliver I think the plan you have outlined is prudent.    Regards,  Chris  From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Sent: Friday, February 2, 2024 10:07:15 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: RE: Request to put Injector 04‐20 (PTD #1831190) online      Mr. Wallace,     Injector 04‐20 (PTD #1831190) was placed on produced water injection on 01/18/24 and an AOGCC witnessed MIT‐IA  passed on 01/22/24 to 2,158 psi. The well is still Under Evaluation as we monitor per the plan below.      The long‐term plan for this well is to plug the existing perforations and add new perforations up hole. We would like to  do this during the Under Evaluation period so we can monitor the well with the injection characteristics of the new  perforations. We are requesting your approval of the plug set and add perfs while Under Evaluation. I have attached a  TIO chart from when the well was placed on injection.     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Monday, January 8, 2024 7:33 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Request to put Injector 04‐20 (PTD  #1831190) online         CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.   CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.  3 Andy,  Plan as per below is approved.     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: Friday, December 29, 2023 4:00 PM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity  <PBWellsIntegrity@hilcorp.com>  Subject: Request to put Injector 04‐20 (PTD #1831190) online     Mr. Wallce,     Injector 04‐20 (PTD #1831190) was reported on 10/07/21 as having an increasing IA pressure trend while shut‐in.  A TTP  was set on 10/24/21 and a passing MIT‐T to 2,226 psi and passing CMIT‐TxIA to 2,176 psi were performed on 10/27/21  confirming competent production tubing and production casing. The well was recently classified as UNDER EVALUATION  in attempt to put the well on production for a temporary flowback, but it would not flow. Hilcorp is requesting approval  to put the well on injection for up to the 30‐days to monitor for IA re‐pressurization. If approval is granted, an AOGCC  witnessed MIT‐IA will be performed when the well is thermally stable.     Plan Forward:  1. Operations: Put well on injection  2. Fullbore: Perform AOGCC MIT‐IA  3. DHD: Monitor for IA re‐pressurization  4. Well Integrity: Additional diagnostics if needed (apply for AA if re‐pressurization is observed)     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Thursday, October 7, 2021 12:59 PM  To: chris.wallace@alaska.gov  Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York   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. 4 <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Subject: Not Operable Injector 04‐20 (PTD #1831190) slow IA re‐pressurization     Mr. Wallace,     Injector 04‐20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4‐year AOGCC MIT‐IA. The well has been  shut in since 10/20/17. During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure  trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G.      Plan forward:  1. Slickline: Set TTP  2. Fullbore: Perform MIT‐IA  3. Well Integrity: Additional diagnostics as needed.     1‐year TIO as requested:        Please respond with any questions.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity / Compliance  5 andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: Alaska NS ‐ PB ‐ Field Well Integrity   Sent: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04‐20 (PTD #1831190) Lapse 4 year AOGCC MIT‐IA     Mr. Wallace,     Injector 04‐20 (PTD #1831190) is due this month for 4 year AOGCC MIT‐IA. There are no immediate plans to resume  injection. The well is now classified as NOT OPERABLE and will remain shut in.      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        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 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 carry out 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 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 carry out 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 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 carry out such virus and other checks as it considers appropriate.   abM 200 3� IN 306 IN 34 170 32 1w 30W 150 TIO Plot 2� 110 26'.YJ IN tTbg W On 0 Bleed 22W 110 3 ♦ Operable 2(MI IN } Not Oper 1 K 90 ♦ Bnaer Eval 1600 W t WIN IA N0\N OA 1 rlO 00 —#— WIN OOA 1 WO 50 t WIN OOOA IM tl $Temperature 6W 3 dO] A W 10 1010720 1 102120 11i0120 111= 1Jnn/m 1] VM 1]f9YN 0111321 01= 0i11621 @ Wl "1001 MU1 0WQ1 OE 101 0.5R521 MK1 Cti0 l O ld l WNT OT1Y1 0IQ&21 0 llnl 08 l O M21 OW= 1d 1 Junke, Kayla M (OGC) From:Wallace, Chris D (OGC) Sent:Tuesday, February 6, 2024 5:00 PM To:AOGCC Records (CED sponsored) Subject:FW: Request to put Injector 04-20 (PTD #1831190) online   From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Tuesday, February 6, 2024 11:53 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: Re: Request to put Injector 04‐20 (PTD #1831190) online    Andy,  Yes, under evaluation is approved.  Speaking with Oliver I think the plan you have outlined is prudent.    Regards,  Chris  From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Sent: Friday, February 2, 2024 10:07:15 AM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  Subject: RE: Request to put Injector 04‐20 (PTD #1831190) online      Mr. Wallace,     Injector 04‐20 (PTD #1831190) was placed on produced water injection on 01/18/24 and an AOGCC witnessed MIT‐IA  passed on 01/22/24 to 2,158 psi. The well is still Under Evaluation as we monitor per the plan below.      The long‐term plan for this well is to plug the existing perforations and add new perforations up hole. We would like to  do this during the Under Evaluation period so we can monitor the well with the injection characteristics of the new  perforations. We are requesting your approval of the plug set and add perfs while Under Evaluation. I have attached a  TIO chart from when the well was placed on injection.     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816         From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>   Sent: Monday, January 8, 2024 7:33 AM  To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>  2 Subject: [EXTERNAL] [WARNING: ATTACHMENT(S) MAY CONTAIN MALWARE]RE: Request to put Injector 04‐20 (PTD  #1831190) online        Andy,  Plan as per below is approved.     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: Friday, December 29, 2023 4:00 PM  To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>  Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity  <PBWellsIntegrity@hilcorp.com>  Subject: Request to put Injector 04‐20 (PTD #1831190) online     Mr. Wallce,     Injector 04‐20 (PTD #1831190) was reported on 10/07/21 as having an increasing IA pressure trend while shut‐in.  A TTP  was set on 10/24/21 and a passing MIT‐T to 2,226 psi and passing CMIT‐TxIA to 2,176 psi were performed on 10/27/21  confirming competent production tubing and production casing. The well was recently classified as UNDER EVALUATION  in attempt to put the well on production for a temporary flowback, but it would not flow. Hilcorp is requesting approval  to put the well on injection for up to the 30‐days to monitor for IA re‐pressurization. If approval is granted, an AOGCC  witnessed MIT‐IA will be performed when the well is thermally stable.     Plan Forward:  1. Operations: Put well on injection  2. Fullbore: Perform AOGCC MIT‐IA  3. DHD: Monitor for IA re‐pressurization  4. Well Integrity: Additional diagnostics if needed (apply for AA if re‐pressurization is observed)     Please respond at your earliest convenience.     Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816          CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.   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.   3 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Thursday, October 7, 2021 12:59 PM  To: chris.wallace@alaska.gov  Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York  <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Subject: Not Operable Injector 04‐20 (PTD #1831190) slow IA re‐pressurization     Mr. Wallace,     Injector 04‐20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4‐year AOGCC MIT‐IA. The well has been  shut in since 10/20/17. During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure  trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G.      Plan forward:  1. Slickline: Set TTP  2. Fullbore: Perform MIT‐IA  3. Well Integrity: Additional diagnostics as needed.     1‐year TIO as requested:        Please respond with any questions.  abM 200 3� IN 306 IN 34 170 32 1w 30W 150 TIO Plot 2� 110 26'.YJ IN tTbg W On 0 Bleed 22W 110 3 ♦ Operable 2(MI IN } Not Oper 1 K 90 ♦ Bnaer Eval 1600 W t WIN IA N0\N OA 1 rlO 00 —#— WIN OOA 1 WO 50 t WIN OOOA IM tl $Temperature 6W 3 dO] A W 10 1010720 1 102120 11i0120 111= 1Jnn/m 1] VM 1]f9YN 0111321 01= 0i11621 @ Wl "1001 MU1 0WQ1 OE 101 0.5R521 MK1 Cti0 l O ld l WNT OT1Y1 0IQ&21 0 llnl 08 l O M21 OW= 1d 4    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: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04‐20 (PTD #1831190) Lapse 4 year AOGCC MIT‐IA     Mr. Wallace,     Injector 04‐20 (PTD #1831190) is due this month for 4 year AOGCC MIT‐IA. There are no immediate plans to resume  injection. The well is now classified as NOT OPERABLE and will remain shut in.      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        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 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 carry out 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 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 carry out such virus and other checks as it considers appropriate.     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: Injector 04-20 (PTD #1831190) Temporary flowback complete - POI Date:Tuesday, January 16, 2024 9:19:40 AM Attachments:FW EXTERNAL WARNING ATTACHMENT(S) MAY CONTAIN MALWARERE Request to put Injector 04-20 (PTD #1831190) online.msg 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: Friday, January 12, 2024 7:51 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: Injector 04-20 (PTD #1831190) Temporary flowback complete - POI All, Injector 04-20 (PTD #1831190) temporary flowback is complete. AOGCC has approved the plan to put on injection and an AOGCC witnessed MIT-IA will be performed when thermally stable. IA pressure will be monitored for possible communication during the online period. The well remains classified as UNDER EVALUATION and the clock will be reset for 30 days once injection begins. 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 <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 15, 2023 2:42 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; PBE FS2 Field Lead Operator <PBEFS2FieldLeadOperator@hilcorp.com>; PBE FS2 Foreman <PBEFS2Foreman@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; PBE FS2 DS Operators <FS2DrillsiteOperators@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-20 (PTD #1831190) Temporary flowback All, Injector 04-20 (PTD #1831190) is a Not Operable PWI injector with no verified integrity issues. AOGCC has approved temporary flowback of up to 30 days. The well is now classified as UNDER EVALUATION for temporary flowback for up to 30 days. If the flowback period exceeds 30 days, a 10-404 will be required. Production allocation will be reported off 04-22 well slot and 04-22 will remain shut in during the duration of the temporary flowback. A miscellaneous SVS test will be required within 5 days of stabilized production. 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 Sent: Monday, August 23, 2021 2:36 PM To: Alaska JMS User <akimsuser@hilcorp.com>; Alaska NS - FS2 - Field Lead Operator <FS2FIeldLO@hilcorp.com>; Alaska NS - FS2 - Foreman <FS2Foreman@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; FS2 Drillsite Operators <FS2DrillsiteOperators@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Cc: Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA All, Injector 04-20 (PTD #1831190) is due this month for 4 year AOGCC MIT-IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE and will remain shut in. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Request to put Injector 04-20 (PTD #1831190) online Date:Monday, January 8, 2024 7:36:03 AM Attachments:image001.png04-20.pdf 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: Friday, December 29, 2023 4:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request to put Injector 04-20 (PTD #1831190) online Mr. Wallce, Injector 04-20 (PTD #1831190) was reported on 10/07/21 as having an increasing IA pressure trend while shut-in. A TTP was set on 10/24/21 and a passing MIT-T to 2,226 psi and passing CMIT-TxIA to 2,176 psi were performed on 10/27/21 confirming competent production tubing and production casing. The well was recently classified as UNDER EVALUATION in attempt to put the well on production for a temporary flowback, but it would not flow. Hilcorp is requesting approval to put the well on injection for up to the 30-days to monitor for IA re-pressurization. If approval is granted, an AOGCC witnessed MIT-IA will be performed when the well is thermally stable. Plan Forward: 1. Operations: Put well on injection 2. Fullbore: Perform AOGCC MIT-IA 3. DHD: Monitor for IA re-pressurization 4. Well Integrity: Additional diagnostics if needed (apply for AA if re-pressurization is observed) Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 7, 2021 12:59 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Not Operable Injector 04-20 (PTD #1831190) slow IA re-pressurization Mr. Wallace, Injector 04-20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4-year AOGCC MIT-IA. The well has been shut in since 10/20/17. During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G. Plan forward: 1. Slickline: Set TTP 2. Fullbore: Perform MIT-IA 3. Well Integrity: Additional diagnostics as needed. 1-year TIO as requested: 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: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA Mr. Wallace, Injector 04-20 (PTD #1831190) is due this month for 4 year AOGCC MIT-IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE and will remain shut in. 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 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 strictly prohibited. If you have received this email in error, pleaseimmediately 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 carry out such virus and other checks as it considersappropriate. TRIBE = FMC 120 WELLHEAD= MCEVOY ACTUATOR= BAKER KB. E_EV = 57 BF. BF/ _ KOP= ? Max Angle = 61"@ 7900 Datum MD = 11925 Datum TV D= 8800 SS 0 _2 O SAFETY NOTES. FFLfTIW PR PKRS HAVE REDUCED TEST EST PRESSURE LIMITS IN SOME CASES. CONTACT WE (x5102) PRIOR TO PRESSURE TESTING C 13-M-CSG, 72#, 7 LSO, ID=12.347 2528' BG-PC,17#,L80, 0.0232 bpf,lo-4.892 10988' TOPOF 4-12- TBGPC 10 W8 I TOP OF 7-LNR — 11040' f Minimum ID = 3.813" @ 11059' 4 1/2n CAMCO D13-6 NIPPLE 4-1/2"TBG-PC, 12.6#, L80, 0.0152 bpf, D--3.958 11072' o-8.681 1--i 113W PERFORATION SUMMARY REF LOGS BRCS 09/02/83 ANGLE AT TOP PEW: 42° @ 11600' Note: Refer to Production DB for historical pert data SIZE SIPE INTERVAL Opn/Sgz DATE 3-38' 6 11600 - 11641 O 01/05/09 3-3/8 025 11653-11673 O 0721/89 3-3/8 1 11679-11680 O 07/21/89 3-3/8 025 11686-11706 O 04/01/89 3-3/8 4 11710-11737 O 04/01/89 3-3/8 4 11740-11768 O 10/19/87 1 7-LNR 29#, L-80, 0.0371 bpf,ID=6.1841--i 11888' 1 11890, 109W —j5-12" X 4-12- XO 70993' 9-5/8' X 4-1/2' BKR FFL PKR 1) = 8.81' 110� 4-12- CAMCO DB-0 NIP, ID=3.813 110�-14-12- TUBING TAIL 11060' EMD TT-LOGG®9/10/97 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/83 ORIGINAL COMPLETION 11/0121 JKC/JMD SET PLUG & PRONG 102621 01/12/09 JKD/SV ADPERF 01/05/09 12/1423 JCM/JMD PULLED PLUG 1211323 0620/17 ZV/JMD SET DSSSV PLUG 06/09/17 0620/17 JLS/JMD TREE C/O (06116/17) 0627/17 LLG/JMD PULLED DSSSV 0625/17 PRUDHOE BAY UNIT WELL: 04-20 PERMITND: 183-1190 API ND: 50-029-20996-00 SEC 22 T71 N R75E 1858.39 FEE 3145.3 FNL Hilcorp North Slope, LLC 4M No Ato Mo to no Plot Mo I to NAo to :1 I Mo 3o , MAN IA "o No. to No No to 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:04 AM To:AOGCC Records (CED sponsored) Subject:FW: Not Operable Injector 04-20 (PTD #1831190) slow IA re-pressurization     From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Thursday, October 7, 2021 12:59 PM  To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>  Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York  <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Subject: Not Operable Injector 04‐20 (PTD #1831190) slow IA re‐pressurization    Mr. Wallace,    Injector 04‐20 (PTD # 1831190) is currently Not Operable due to lapsing on its 4‐year AOGCC MIT‐IA. The well has been  shut in since 10/20/17.  During a review of the AOGCC Quarterly Not Operable Injector report, an increasing IA pressure  trend was discovered. This notification is to satisfy the requirements outlined in Rule 7 of AIO 4G.     Plan forward:  1. Slickline: Set TTP  2. Fullbore: Perform MIT‐IA  3. Well Integrity: Additional diagnostics as needed.    1‐year TIO as requested:    2   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: Monday, August 23, 2021 2:36 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: NOT OPERABLE: Injector 04‐20 (PTD #1831190) Lapse 4 year AOGCC MIT‐IA    Mr. Wallace,    Injector 04‐20 (PTD #1831190) is due this month for 4 year AOGCC MIT‐IA. There are no immediate plans to resume  injection. The well is now classified as NOT OPERABLE and will remain shut in.   4On 2n yen + 1m 31S00 1m 3400 1m 3200 1m 3" 1m TIO Plot 2&q im 2Re 130 Tbg 2400 in On 22m 1103 Bleed! ♦ Opemble 2000 1004 } Xo[OPr &q ♦ under Er,I 1 Em m m A M IN O 14RCOm j MpXM1" — MQXOM 10n tMPXOOOII Xp $TapereWre m ao0 2m 10q]20 102120 11/0120 1111020 1=0 1 IUN 1MYA O111i 01(O21 0 1021 02 l n1021 MY l 01R121 012121 fl 6 l 041421 O l O llWl Odrml W1171 0l l O llm oo2 l �21 oaMl loex 3   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      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 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 carry out such virus and other checks as it considers appropriate.     From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA Date:Wednesday, August 25, 2021 11:22:53 AM From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, August 23, 2021 2:36 PM To: Wallace, Chris D (CED) <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: NOT OPERABLE: Injector 04-20 (PTD #1831190) Lapse 4 year AOGCC MIT-IA Mr. Wallace, Injector 04-20 (PTD #1831190) is due this month for 4 year AOGCC MIT-IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE and will remain shut in. 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 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 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 16,2017 TO: Jim Regg P.I.Supervisor Net,/ Zi(17 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC. 04-20 FROM: Bob Noble PRUDHOE BAY UNIT 04-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-20 API Well Number 50-029-20996-00-00 Inspector Name: Bob Noble Permit Number: 183-119-0 Inspection Date: 8/15/2017 - Insp Num: mitRCN170815140529 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 04-20 ' Type Inj W 'TVD 8174 ' Tubing 1194 - 1191 1202 F1206. PTD 1831190 - Type Test SPT Test psi 2044 IA 359 2495 " 2457 " 2444 ' -- -------- BBL Pumped: 5.5 7 " OA 46 I 126 p ; BBL Returned: 129 - 132 - Interval -..- -- 4YRTST JP/F P Notes: SCANNED FEB 2 a i Wednesday,August 16,2017 Page 1 of 1 Gyrodata Incorporated • "fur."S'5S 23000 Northwest Lake Dr. gyroldcltai t Houston,Texas 77095 T: (281) 213-6300 • F: (281) 213-6301 Precision Wellbore Placement = 4 7..1t15, SC041*'° SURVEY REPORT BP Exploration Drill Site: 04 #04-20 Wellhead Prudhoe Bay, North Slope Borough, AK AK0915GCM178 29 September 2015 RIGHT PLACE FIRST TIME www.gyrodata.corn Gyrodata Incorporated • • 23000 Northwest Lake Dr. gyro/data Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 October 19, 2015 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 04, Well # 04-20 Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME rS&www.gyrodata.com • S 0 0 .....Cd U 0o .1 0 ..... 71tii 0 x 0 3 I r x o z a 0 clo0 Ts to 1 s� c4 0 ° U to ay�� a' C7 -d G) ..o Z1 U c� -O 0 at lo. U U o • c) 0 a , c,„ ._, ,...4 r/) ., r., p 0 N U 5 C � a o03 N I ! I w o Ell 0 C: 1czt -4c, z as 0 y -0 b ° o w —,Q � 0. a o ( PI Ct o, U 0.0od 3 w bp b H p U > .2 a O U az oo b •h 8 .0b — O — ° —, 0 00 v - N 0 oN U "d a CI O a) O U V) U N -o oN 0 ',1t ,P z A a) z U 0 V> U v> V> O • N w e.g. 44333 33333 33333 333 O en ---, d' \O \O \O o0 0 a, a\ C` en 141 N M ,--t \O M aCl) O d• O O .--i M VD a\ M v) N 00 00 N VO d; N Oh \O WO r" O O O O O O .-" -1 .--i .-. ,4 ." .--i r" ,. O O H z4 NQS w r-, 0 0 en 0 � en en N O d- en 0 - en en -i d' �rO+ O a ---- en N en a, \0 en 00 d: 01 'Ch 0 lei 00 0 Cl en ►+t O O OO O O O .-. �-. 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ON V1 '0 N 00 01 10 d' ' 10 N M 'n 0 N 10 00 "100 ���C11 00 00 00 00 00 00 00 00 00 00 00 00 00 00 N N N N N t-: N N to 'o ,--� M M M M M M M M M M mmmmm M M M M M M M M M Mmm M M U N r-1 O �~-+ v) U a V) (---- M .:1- MO\ ' d' - X01000 ,-+ 00N10 ,--, N ,--, 10N Rj O U a 00 ,4-. ,*: d. ,,r. m00 0, 000 0101001: v1N 00 �+ I3 z to 0 00 00 00 0o 00 00 00 00 t- N 00 00 N Oo N N t-400 N N L`' .--i 4 "b v1 V7 v) V'1 h v1 h h v1 v1 V'1 V1 ,n v1 v1 V'1 to 'n v) ,n v) v7 � o clC -rd3 i W o - , (i! x 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 Q E H 0000 00000 00000 00000 000 A, O i v1Ov1O V10v1O +n OviOv16 v1O v1Ov1 6v1O 67-1Z .1 QI N N to N O N V1 N O N ' NON N N O N 41 l O N V1 • W c `4 W 000 000 000 000 000 000000000000 000 000000 000 000 000 000 000 000 000, 000 M M N O 'O Wr A aaaa1.° • .41 33 33333 33333 33333 33333 VD d' VI OT O> >n M o0 0o O\ NN 00 VD CIN d' . d' N N 00 IV)V) N00 00NVDLnTr N0 -4 � MO0 00VOet CT Wd' N 000 \O 4 N6 00 v1 M — O\ vO Ti N6 00 96 M — Ol PNM d' Tt 'n V) N 0000 O\ 0 •, — Nen Tr v1 vl VD N 0000 N N N N N Cl Cl N N N M M M M M M M M M M M M �p a) a py z �j yy y�i yy yy �iy�i y�i yy �j yy y y y r� yy y�i y�i �i rr�� w O Tr .. „) .„ ,..1 „... 0 N ---IN '0 MMO\ vl '0 en � 'd N ' M • Q 0N 4, '000 0 •-. 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W I I 1 -- I I I i 1- — 1 I I 1 I 0 I O N o 1_O^ .... •• I 1 I o_ 0 1 1 I - X ' I 1 I I I i - • V I I I , l 1 I till ; I I I Ili I I 1 1 11 I ) I I I I I I I .i J I t I I I I I COcoGO i� tip in d' M N *'1 0 (400T/60p) A.1.III A3S 93190a i S Survey QC - RGS-CT Continuous Specification Sheet • • ' • M k SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-30B CALIBRATION VERIFICATION (ROLL TEST System Parameter dGx dGy dmbo Mean Gravity Error* Stdev Gravity Error Standard Deviation 0.009 0.009 0.009 -0.00018 0.00003 Tolerance 0.033 0.033 0.087 0.00591 0.00720 GYRO VERIFICATION(ADVANCED INITIALISATION) Gyro Compass Parameter Gyro noise dGx dGy dmbo Max corr coef Standard Deviation 0.035 0.005 0.005 0.000 0.45 Tolerance 0.141 0.033 0.033 0.087 0.45 Initialisation inclination standard deviation 0.08 Initialisation azimuth standard deviation 0.36 Initialisation azimuth uncertainty in percent of error model -Tolerance < 100% 37% ACCELEROMETER VERIFICATION (G-TOTAL TEST)-not applicable for 2 accelerometer systems G-Total Test Parameter Mean Gravity Error Mean Gravity Error Standard Deviation Error -0.00011 0.00002 Tolerance 0.00590 0.02175 CALIBRATION Tool Number I F0052 I Calibration Date 117 May 2014 OPERATING TEMPERATURE _Calibration range From 50.48 To 120.02 Gyro operating range From 52.03 To 70.45 I In-Spec if+/- 2.5 °C of Calibration CONTINUOUS DRIFT CORRECTION Linear Drift Uncertainty 0.14 Random Walk Uncertainty 0.05 Tolerance 0.46 Tolerance 0.23 CONTINUOUS MISALIGNMENT CORRECTION Misalignment Parameter dMx dMy Cross corr coef Standard Deviation Tolerance DEPTH CONTROL Wireline Company Schlumberger I Line type 11/32" Encoder SF I Schlumberger Max Depth (TD) 11700 CCL Corrected NO Zero Depth(Rig up) RKB @ 57'AMSL Rezero Depth -2.16 Given pup joint depth NA Measured PJ NA Strech cor.At TD divided by TD/1000 .8547 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .2222 Spec'-2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'-2.0/1000 INDIVIDUAL STATION REPORT 0/0 of Total stations accepted Tolerance > 80% 100% Consecutive Interval out of Specification Tolerance < 100 m(300 ft) 0 feet SURVEY RUNNING TIME Rig up Rig down Start Inrun Field Survey Presented End outrun Lost Time Comments SURV-Q163 December 2011 Page 1 of 2 Created:13-Oct-15 17:17 AK0915GCM178 • Survey QC - RGS-CT Continuous Specification Sheet gy I • f . ACCEPTANCE SUMMARY Accept NAME AND DATE Yes/ No Pre-job calibration verification (roll test) YES Click here to enter text. Gyro Verification(Advanced Initialisation) YES Accelerometer verification(G-Total Test) YES Operating temperature within calibration range(+/- 2.5°) YES SIGNATURE Continuous Drift Correction YES Click here to enter text. Continuous Misalignment Correction N/A Depth Control YES Individual Station Report YES Note : Any modifications or amendments to this sheet must be reported to the client representative and the Gyrodata survey focal point. SURV-Q163 December 2011 Page 2 of 2 Created:13-Oct-15 17:17 AK0915GCM178 • • Survey QC - RGS-CT Analysis Sheet 0g • • SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I 1 Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 I ND 10.00 Northings 0.00 Eastings 0.00 Latitude 70.2748 Az. Ref: Grid/True True Grid Corrected Y/N? N Description I CALIBRATION Tool Number I F0052 I Calibration Date 117 May 2014 1 OPERATING TEMPERATURE Calibration range From 50.48 To 120.02 Gyro operating range From 57.61 To 70.45 I Spec'-Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not ossible input roll test data performed after return to base) Cal value Pre job offset Post job offset Abs dif.cal.post Abs dif.pre.post Spec' Accel Scale 0.000056 0.000045 0.000054 0.000054 0.000010 Cal/Post-0.00015 Mass Unbalance 0.45 -0.08 0.21 0.21 0.28 Pre/Post-0.4°/hr INITIALISATION Depth(Approx) 2839.86 No of stns 7 Spec'- Min No. -6 Azimuth Mean 343.23 Std deviation 0.08 Spec'-Azi SD 0.2° Inclination Mean 10.47 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean(Abs(meas-theor)) 10.02 Std deviation 0.01 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean 0.000 Std dev' 0.002 Spec's -Mean and SD-0.333°/hr Residual y gyro bias Mean 0.000 Std dev' 0.001 Spec's-Mean and SD -0.333°/hr TOOLFACE RATE I Maximum toolface rate 1 0.07 I Spec'-400°/sec IN/OUT COMPARISON AZI'N/A IF INC' <15°1 Inclination Difference Mean -0.08 Std dev' 0.08 Spec's-Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean -0.11 Std dev' 0.15 Spec's- Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 1.28 Spec- 5.0/1000 Vertical Divergence/1000 1.09 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company Sclumberger I Line type 11/32" Encoder SF I Schlumberger Max Depth (TD) 11700 CCL Corrected NO Zero Depth (Rig up) RKB @ 57'AMSL Rezero Depth -2.16 Given pup joint depth NA Measured PJ NA Strech cor.At TD divided by TD/1000 .8547 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .2222 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 SURV-Q165(OPS SUR-MA-010)22"Jan 2004/Revision 20 Page 1 of 1 AK0915GCM178 • • Survey QC - RGS-CT Specification Sheet + * • SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 268.58 213.79 0.00005296 -5.04 63 268.58 219.91 0.00005448 -6.00 62 224.18 384.83 0.00009623 -7.00 61 224.18 392.26 0.00009809 -8.74 60 44.23 388.40 0.00009712 -2.56 59 44.23 396.54 0.00009915 -1.37 58 357.99 50.39 0.00001272 -4.83 57 357.99 64.58 0.00001630 -5.44 56 329.42 -175.16 -0.00004400 -6.44 55 329.42 -167.07 -0.00004197 -6.74 54 299.35 -114.32 -0.00002845 -5.61 53 299.35 -110.03 -0.00002738 -6.01 52 269.47 208.34 0.00005161 -8.18 51 269.47 218.98 0.00005425 -7.61 50 240.79 400.77 0.00009970 -3.34 49 240.79 403.89 0.00010048 -7.78 48 209.70 343.14 0.00008620 -4.22 47 209.70 341.87 0.00008588 -4.11 46 179.08 92.84 0.00002344 -0.27 45 179.08 100.30 0.00002532 0.74 44 149.74 -123.40 -0.00003100 8.25 43 149.74 -117.70 -0.00002957 7.86 42 119.82 -63.31 -0.00001576 9.22 41 119.82 -62.39 -0.00001553 8.36 40 90.52 246.00 0.00006094 5.40 39 90.52 249.30 0.00006176 4.83 38 58.56 432.04 0.00010755 2.24 37 58.56 431.99 0.00010754 2.39 36 28.71 340.19 0.00008548 -0.10 35 28.71 344.09 0.00008647 -2.17 34 0.30 77.17 0.00001948 -4.29 33 0.30 80.88 0.00002042 -3.94 32 269.60 198.31 0.00004912 -3.49 31 269.60 196.55 0.00004869 -3.89 30 225.53 377.39 0.00009432 -6.93 29 225.53 393.15 0.00009826 -8.75 28 45.28 407.29 0.00010181 3.00 27 45.28 412.93 0.00010322 3.92 26 1.10 73.76 0.00001862 -1.71 25 1.10 75.27 0.00001900 -0.92 24 331.14 -173.91 -0.00004371 2.76 23 331.14 -167.97 -0.00004222 3.35 22 300.77 -114.78 -0.00002857 6.79 21 300.77 -104.80 -0.00002609 6.80 20 270.26 223.04 0.00005525 1.08 19 270.26 228.78 0.00005667 1.09 18 241.16 432.00 0.00010747 -2.66 17 241.16 435.69 0.00010839 -2.56 16 209.66 356.91 0.00008966 1.28 15 209.66 356.10 0.00008946 1.73 14 179.77 104.22 0.00002631 5.51 13 179.77 108.43 0.00002737 3.48 12 148.97 -116.21 -0.00002919 10.39 11 148.97 -109.24 -0.00002744 10.71 10 119.49 -17.96 -0.00000447 15.17 9 119.49 -20.57 -0.00000512 16.17 8 89.12 316.56 0.00007843 10.14 7 89.12 323.66 0.00008019 10.66 6 59.43 493.03 0.00012272 4.66 5 59.43 497.15 0.00012375 5.47 SURV-Q167(OPS SUR-MA-003) 19'"Nov 03/Rev 15 Page 1 of 7 AK0915GCM178 • • Survey QC - RGS-CT Specification Sheetgir + • - 4 29.32 363.41 0.00009131 -1.92 3 29.32 368.55 0.00009260 -1.77 2 0.07 60.15 0.00001518 -1.39 1 0.07 60.85 0.00001536 -0.47 MBO = -0.08 Gravity Error= 180.11 Scale Factor Uncertainty= 0.00004494 Rate Error= 0.39 POST-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 23582 269.17 224.49 0.00005561 -0.88 23581 269.17 221.88 0.00005496 -0.47 23580 224.14 411.33 0.00010286 -2.00 23579 224.14 411.05 0.00010279 -3.00 23578 44.92 422.84 0.00010571 2.24 23577 44.92 426.02 0.00010651 1.20 23576 0.33 95.02 0.00002399 1.46 23575 0.33 97.07 0.00002450 0.92 23574 329.85 -161.68 -0.00004062 1.71 23573 329.85 -152.50 -0.00003832 0.98 23572 299.93 -100.74 -0.00002507 0.94 23571 299.93 -98.46 -0.00002451 -0.02 23570 269.85 221.74 0.00005493 -2.03 23569 269.85 230.54 0.00005711 -2.73 23568 239.53 436.44 0.00010862 -3.59 23567 239.53 440.32 0.00010959 -3.59 23566 209.15 368.43 0.00009257 -1.65 23565 209.15 369.40 0.00009282 -1.79 23564 179.58 124.44 0.00003142 0.64 23563 179.58 128.34 0.00003240 0.04 23562 148.60 -102.30 -0.00002570 1.78 23561 148.60 -103.67 -0.00002604 1.04 23560 120.20 -29.64 -0.00000738 5.05 23559 120.20 -20.10 -0.00000500 3.70 23558 90.26 285.62 0.00007076 4.46 23557 90.26 289.96 0.00007184 3.80 23556 59.97 473.28 0.00011778 1.37 23555 59.97 480.25 0.00011952 0.78 23554 30.33 382.03 0.00009596 -0.07 23553 30.33 390.56 0.00009810 0.58 23552 359.39 83.54 0.00002109 0.37 23551 359.38 80.98 0.00002044 0.09 23550 269.85 247.31 0.00006127 -0.26 23549 269.85 256.20 0.00006347 -0.08 23548 225.08 428.87 0.00010722 -4.26 23547 225.08 430.40 0.00010760 -6.23 23546 44.79 442.33 0.00011059 -0.65 23545 44.79 445.72 0.00011144 -0.74 23544 358.80 90.38 0.00002282 0.28 23543 358.80 90.91 0.00002295 0.10 23542 328.98 -143.63 -0.00003608 1.90 23541 328.98 -142.13 -0.00003570 1.28 23540 299.29 -54.14 -0.00001347 3.72 23539 299.29 -51.09 -0.00001272 5.37 23538 270.40 275.00 0.00006813 0.23 23537 270.40 283.84 0.00007032 0.53 23536 239.94 485.59 0.00012085 -2.70 23535 239.94 491.49 0.00012232 -3.36 23534 209.58 395.83 0.00009945 -2.19 23533 209.58 398.08 0.00010001 -1.21 23532 179.92 135.42 0.00003419 1.74 23531 179.92 140.41 0.00003545 2.24 23530 149.86 -75.94 -0.00001908 6.22 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 7 AK0915GCM178 • • Survey QC - RGS-CT Specification Sheet. gy f 23529 149.86 -74.81 -0.00001880 5.79 23528 119.49 53.94 0.00001343 8.79 23527 119.49 57.53 0.00001432 9.16 23526 89.74 404.79 0.00010031 5.46 23525 89.74 410.80 0.00010180 5.73 23524 59.16 585.13 0.00014568 1.27 23523 59.16 598.60 0.00014904 0.14 23522 28.92 416.86 0.00010476 -0.94 23521 28.92 421.33 0.00010588 -0.48 23520 358.48 94.64 0.00002389 0.85 23519 358.48 94.38 0.00002383 0.12 MBO = 0.21 Gravity Error= 218.13 Scale Factor Uncertainty=0.00005444 Rate Error= 0.77 INITIALISATION Gyro Compass Reading/Station Raw Inclination Raw Azimuth Abs(ERMeas-ERrhee) 2845 10.46 343.33 0.0257 2846 10.46 343.21 0.0311 2847 10.47 343.13 0.0214 2848 10.46 343.26 0.0077 2849 10.47 343.32 0.0203 2850 10.47 343.19 0.0123 2851 10.47 343.15 0.0021 Average 10.47 343.23 0.0172 Tolerance on Average* 0.0833 Standard Deviation 0.00 0.08 0.0103 Tolerance on St. Dev.** 0.10 0.20 0.0405 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance=TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cost)*.[(CosA*SInI*Q.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cos1)*J[(CosA*SinI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 0.00 1300.16 0.00 0.00 0.000 0.000 0.000 0.000 2 0.00 2200.53 0.00 0.00 0.000 0.000 0.000 0.000 3 0.00 2700.16 0.00 0.00 0.000 0.000 0.000 0.000 4 0.00 2839.86 0.00 0.00 0.000 0.000 0.000 0.000 5 993.24 3649.98 25.06 352.65 -0.000 0.000 -0.000 0.001 6 1049.65 4400.02 39.86 344.24 0.001 0.000 -0.001 -0.000 7 1456.64 5749.98 48.52 345.22 0.001 -0.000 -0.001 0.000 8 1431.26 7099.98 56.51 338.96 -0.000 0.001 -0.002 0.001 9 1407.04 8400.11 59.82 338.23 -0.000 0.001 -0.003 0.002 10 1481.88 9800.04 50.68 337.19 0.000 0.000 -0.001 -0.000 11 1412.83 11099.92 46.66 342.76 -0.006 0.004 -0.002 0.002 12 821.27 11700.00 40.90 344.19 0.001 -0.001 -0.002 0.003 13 886.70 11000.13 46.85 341.39 0.001 -0.001 0.001 -0.000 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 7 AK0915GCM178 • • Survey QC - RGS-CT Specification Sheet • a a . • , 14 1332.86 9800.00 50.66 337.17 0.001 -0.000 0.002 -0.001 15 1469.30 8399.92 59.87 338.34 0.002 -0.002 0.002 -0.002 16 1400.05 7100.08 56.65 339.04 -0.004 0.004 0.000 0.000 17 1471.35 5749.91 48.70 345.31 0.004 -0.004 0.001 0.000 18 1463.90 4400.00 40.05 344.37 0.000 -0.001 0.003 -0.001 19 966.34 3649.65 25.16 353.06 0.000 -0.001 0.001 -0.001 20 951.61 2850.03 10.92 343.27 -0.001 0.001 0.000 -0.000 21 0.00 2699.48 0.00 0.00 0.000 0.000 0.000 0.000 22 0.00 2200.03 0.00 0.00 0.000 0.000 0.000 0.000 23 0.00 1300.00 0.00 0.00 0.000 0.000 0.000 0.000 24 0.00 99.72 0.00 0.00 0.000 0.000 0.000 0.000 Average 0.000 0.000 -0.000 0.000 Standard Deviation 0.002 0.002 0.001 0.001 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON I Depth I Corrected Inclination I Corrected Azimuth Inrun * I Outrun* I Difference I{ Inrun * I Outrun * I Difference 100.00 0.17 0.07 0.10 169.33 152.21 17.13 200.00 0.19 0.21 -0.02 205.75 198.32 7.44 300.00 0.26 0.29 -0.04 199.03 181.31 17.72 400.00 0.43 0.45 -0.02 206.91 202.62 4.30 500.00 0.37 0.40 -0.04 207.67 200.95 6.72 600.00 0.46 0.47 -0.02 201.31 204.98 -3.67 700.00 0.38 0.41 -0.02 203.58 213.83 -10.25 800.00 0.37 0.30 0.07 209.37 207.88 1.49 900.00 0.37 0.29 0.09 192.38 189.48 2.90 1000.00 0.28 0.24 0.04 180.67 182.55 -1.88 1100.00 0.33 0.28 0.05 169.07 169.11 -0.04 1200.00 0.32 0.35 -0.04 170.77 174.28 -3.50 1300.00 0.30 0.30 0.00 165.71 150.96 14.75 1400.00 0.15 0.11 0.03 137.34 124.85 12.49 1500.00 0.21 0.20 0.01 133.76 126.49 7.28 1600.00 0.16 0.15 0.01 124.61 122.18 2.43 1700.00 0.24 0.28 -0.05 112.82 109.17 3.65 1800.00 0.31 0.36 -0.06 102.39 110.34 -7.94 1900.00 0.28 0.28 -0.00 79.33 93.87 -14.54 2000.00 0.54 0.57 -0.04 359.72 9.55 -9.82 2100.00 0.58 0.59 -0.01 357.00 356.62 0.38 2200.00 1.08 1.12 -0.04 24.71 22.35 2.36 2300.00 0.65 0.60 0.05 41.07 44.12 -3.05 2400.00 1.11 1.05 0.06 62.36 60.70 1.66 2500.00 0.75 0.79 -0.03 68.19 65.88 2.31 2600.00 1.91 1.83 0.07 357.60 357.35 0.24 2700.00 4.82 4.82 -0.00 344.20 342.94 1.26 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 7 AK0915GCM178 S • Survey QC - RGS-CT Specification Sheet g •- • - - A 2800.00 7.54 7.40 0.14 344.03 344.29 -0.26 2900.00 13.23 13.16 0.07 349.07 348.94 0.13 3000.00 19.23 19.33 -0.10 353.27 353.90 -0.63 3100.00 19.37 19.55 -0.18 352.62 353.00 -0.37 3200.00 17.56 17.55 0.01 349.01 348.51 0.50 3300.00 17.29 17.27 0.01 351.63 351.79 -0.16 3400.00 19.54 19.56 -0.03 356.12 356.31 -0.18 3500.00 23.19 23.18 0.00 1.71 2.23 -0.51 3600.00 25.05 24.97 0.07 358.30 359.06 -0.76 3700.00 25.10 25.24 -0.13 346.94 347.58 -0.65 3800.00 26.71 26.85 -0.14 341.40 341.55 -0.16 3900.00 29.46 29.62 -0.16 341.57 341.74 -0.17 4000.00 31.42 31.58 -0.16 342.17 342.32 -0.15 4100.00 32.77 32.89 -0.13 342.45 342.54 -0.10 4200.00 35.18 35.30 -0.12 343.12 343.19 -0.08 4300.00 37.53 37.64 -0.11 343.49 343.59 -0.10 4400.00 39.86 39.97 -0.11 344.24 344.36 -0.12 4500.00 42.58 42.67 -0.09 345.08 345.15 -0.07 4600.00 44.36 44.47 -0.11 345.69 345.79 -0.11 4700.00 45.36 45.51 -0.15 345.79 345.90 -0.11 4800.00 44.82 44.94 -0.12 345.84 345.98 -0.14 4900.00 44.58 44.68 -0.10 345.64 345.79 -0.15 5000.00 45.21 45.35 -0.13 345.39 345.53 -0.14 5100.00 44.90 45.02 -0.12 344.95 345.10 -0.14 5200.00 44.80 44.95 -0.14 344.46 344.61 -0.15 5300.00 44.70 44.81 -0.11 344.39 344.51 -0.11 5400.00 44.52 44.64 -0.12 344.27 344.38 -0.11 5500.00 44.56 44.70 -0.14 344.03 344.15 -0.12 5600.00 44.49 44.63 -0.14 344.59 344.66 -0.07 5700.00 46.37 46.45 -0.08 345.32 345.40 -0.08 5800.00 50.38 50.46 -0.08 345.23 345.31 -0.08 5900.00 53.50 53.55 -0.05 345.27 345.37 -0.10 6000.00 54.09 54.22 -0.14 345.51 345.61 -0.10 6100.00 54.48 54.60 -0.12 345.78 345.86 -0.07 6200.00 54.94 55.07 -0.13 347.04 347.09 -0.05 6300.00 55.87 56.00 -0.13 348.78 348.86 -0.08 6400.00 56.88 56.99 -0.11 349.22 349.31 -0.09 6500.00 57.04 57.19 -0.15 349.26 349.31 -0.04 6600.00 56.77 56.92 -0.15 349.37 349.46 -0.08 6700.00 57.04 57.16 -0.12 349.70 349.77 -0.07 6800.00 57.73 57.82 -0.10 350.29 350.35 -0.05 6900.00 58.30 58.46 -0.16 349.71 349.90 -0.20 7000.00 55.93 56.04 -0.11 342.71 342.99 -0.28 7100.00 56.43 56.56 -0.13 338.96 339.10 -0.14 SURV-Q167(OPS SUR-MA-003) 19'"Nov 03/Rev 15 Page 5 of 7 AK0915GCM178 4 • • Survey QC - RGS-CT Specification Sheet • f 0 . it . 7200.00 56.89 57.06 -0.18 338.75 338.84 -0.09 7300.00 57.31 57.46 -0.15 339.11 339.18 -0.08 7400.00 58.04 58.19 -0.15 339.37 339.45 -0.08 7500.00 58.68 58.83 -0.15 339.45 339.55 -0.10 7600.00 59.02 59.17 -0.14 339.30 339.41 -0.11 7700.00 59.77 59.91 -0.14 339.29 339.41 -0.11 7800.00 59.96 60.11 -0.14 339.10 339.21 -0.11 7900.00 60.28 60.43 -0.15 338.91 339.00 -0.09 8000.00 60.98 61.13 -0.15 338.86 338.96 -0.10 8100.00 61.38 61.52 -0.14 338.63 338.74 -0.11 8200.00 61.61 61.76 -0.15 338.32 338.46 -0.14 8300.00 60.52 60.67 -0.14 338.20 338.31 -0.11 8400.00 59.77 59.91 -0.14 338.22 338.30 -0.08 8500.00 58.90 59.03 -0.13 338.31 338.40 -0.09 8600.00 58.36 58.51 -0.15 338.06 338.15 -0.10 8700.00 58.28 58.41 -0.13 338.11 338.22 -0.11 8800.00 57.94 58.06 -0.12 337.80 337.93 -0.12 8900.00 57.61 57.73 -0.12 337.42 337.52 -0.10 9000.00 57.44 57.57 -0.13 337.17 337.27 -0.10 9100.00 56.25 56.37 -0.12 336.90 337.02 -0.12 9200.00 55.85 56.00 -0.15 337.35 337.46 -0.11 9300.00 55.32 55.45 -0.13 337.34 337.44 -0.11 9400.00 54.26 54.41 -0.15 337.00 337.10 -0.10 9500.00 53.86 53.99 -0.13 337.15 337.28 -0.13 9600.00 52.99 53.13 -0.14 337.40 337.50 -0.10 9700.00 51.48 51.58 -0.10 337.59 337.70 -0.11 9800.00 50.64 50.76 -0.12 337.20 337.31 -0.11 9900.00 49.83 49.96 -0.13 337.39 337.46 -0.07 10000.00 50.38 50.51 -0.13 337.31 337.45 -0.14 10100.00 50.75 50.89 -0.14 337.09 337.13 -0.04 10200.00 50.38 50.54 -0.16 337.07 337.08 -0.01 10300.00 50.25 50.35 -0.10 337.44 337.44 -0.00 10400.00 49.39 49.48 -0.09 338.17 338.21 -0.05 10500.00 48.69 48.83 -0.14 339.11 339.11 -0.01 10600.00 48.31 48.44 -0.13 339.57 339.54 0.03 10700.00 47.86 48.01 -0.15 339.44 339.42 0.01 10800.00 47.80 47.96 -0.16 340.22 340.13 0.10 10900.00 47.35 47.49 -0.14 340.75 340.72 0.03 11000.00 47.10 47.12 -0.03 341.43 341.33 0.09 11100.00 46.51 46.51 -0.01 342.75 342.79 -0.04 11200.00 45.07 45.05 0.02 343.71 343.73 -0.01 11300.00 43.79 43.79 -0.00 344.66 344.65 0.01 11400.00 43.24 43.23 0.01 344.71 344.70 0.01 11500.00 42.31 42.29 0.02 344.66 344.67 -0.01 SURV-Q167(OPS SUR-MA-003) 19"'Nov 03/Rev 15 Page 6 of 7 AK0915GCM178 b • • Survey QC - RGS-CT Specification Sheet 1 r ' 0 11600.00 41.64 41.63 0.01 344.45 344.45 0.00 11700.00 40.82 40.82 -0.00 344.18 344.18 -0.00 Average -0.0798 -0.1078 Standard Deviation 0.0754 0.1489 Tolerance for both the Average and the Standard Casing 0.3° Casing 0.50 Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 7 of 7 AK0915GCM178 t • • gy i • . Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BP Exploration(Alaska)Inc. Field/Platform Wellhead Well Number Drill Site:04 04-20 Survey section From 0.00 ft. to 11700.00 ft. Date 29 Sep 2015 Gyrodata Job No AK0915GCM178 Gyrodata Surveyors Joshua Camacho,Adam O'Connor Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 Page 1 of 1 AK0915GCM178 STATE OF ALASKA RECEIVED • AL ...,KA OIL AND GAS CONSERVATION COMM._ _,SON DEC 0 6 2013 REPORT OF SUNDRY WELL OPERATIONS /ry C 1.Operations Abandon ❑ Repair Well❑ Plug Perforations ❑ Perforate ❑ Other U 'B�ICjtat @f Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development❑ Exploratory ❑ 183-119-0 . 3.Address: P.O.Box 196612 Stratigraphic❑ Service ell 6.API Number: Anchorage,AK 99519-6612 50-029-20996-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028322 . PBU 04-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL . 11.Present Well Condition Summary: Total Depth measured 11890 feet Plugs measured None feet true vertical 8834.25 feet Junk measured 11885 feet Effective Depth measured 11843 feet Packer measured 10994 feet true vertical 8798.51 feet true vertical 8174.91 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 38-118 38-118 1490 470 Surface 2491 13-3/8"72#L-80 37-2528 37-2527.95 4930 2670 Intermediate None None None None None None Production 11269 9-5/8"47#L-80 37-11306 37-8396.6 6870 4760 Liner 848 7"29#L-80 11040-11888 8206.82-8832.73 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 true vertical depth) 4-1/2"BAKER FHL PACKER 10994 8174.91 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): ,, 11,600'-11,641', 11,652 -11,707', 11,710'-11,737', 11,740'-11,768' ittp iE% J2 r' q ; Treatment descriptions including volumes used and final pressure: 5,671 Gallons EC9360A Surfactent,27,877 Gallons EC9398A Polymer, 1580 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 11608 0 1405 Subsequent to operation: 0 0 18664 - 0 1740 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service IN • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ El. WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 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 Garry Catron Email Garry.Catron(cilBP.Com Printed Name Garry Catron Title PDC PE Signature /'" C Phone 564-4424 Date 12/6/2013 V1--F--: Ak RBDMS DEC 13 20 I/` % 7 Form 10-404 Revised 10/2012 de. /iy/i Submit Original Only 0 m M M M O O LO �MOONMO o•0o M r- vt• 0 aN , v- NOOo0v- 0CflCoM o CO O to to (o CO co Co - N co O O O O OoOO (o (oCO0C0 (oCOCOCOCOCO (DN- N- O 0 00 00 00 co co cO c0 ) o0 c0 00 00 00 a 0 oo W z 1 w w 0 W 0 g g Y 0 - N- MtoN- O W o 0 2 N -M M c0 O NtoN- O) toOO 0 J O O W w L P 000 cY I- Lo 00 O M c- _1 _1 _1 Q Q U) W = ti460i � OiC\i660iCOtrir� cNcv) N- o < « W o a z 0 CO O LO M tL) (o (o COO 0 c0 0) 0) 0) N _U 0 _0 J J J 0 J 0 00 130 "3000OO (OCOOCOO CO N- z z z O 0 0 J 0 J 0 co c0 c c0 00 co OD c0 c0 c0 00 00 < < < M000„ 0- W r 0 0 0 w W W Z 0 Z W WW a 1- 1- Q J Q 2220 U) ( cn (n co co H N m Lo to to to to LC) tO to Lo to to to w N MIS toO) MO) COtoaD (oMo 0. 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CI CL E . z µ Cr) iD cD iD D 0 0 rn is 4 (D @ 0 O U 2 0) 0 0) 0 L C 0) 0 rn a)) L 0 o N o m cn a) N - -0 -t ,— t 0) . .0 d- -c d .0 0 L L0 t co t 0)D f C C Ln -0 'co co co C o 'L Lf) (D N Cn C •0)co CD co o (D -0 c O_ Lo .Q N CO U u) _0 N U) = C �L CO U) v- U) 0_ C '4' w OU L[) -0 0)-0 U Ts U Y) 0 0)P a) p p)_ 0 0)'0 U -0 U -p 0 Q a) .0 a) C a) C � -3 C a) C a) as C a) C a) C .0 a) N o Q Q n'� i1'� N * C- Q'U) Q� o o_ C1.6 Q.6 Q Q C2 U) Q E E E _ E _ w E E _ E ,- w - E E _ E _ E E W * — z z D Z c D * n cts D c o * * :3 :3 ('3 :3 :3 :3 , * * � aaa co CL m* an 0)� � * * CI CL co d 0)a Q co Co co O O o N N N N CO r r r TREE= ? SAFETY NOTES:FHL/TNV HBBP PKRS WELLHEAD= MCEVOY 04-2 0 HAVE REDUCED TEST PRESSURE LIMITS IN ACTUATOR= AXELSON SOME CASES.CONTACT WIE(x5102) KB.ELEV= 57 PRIOR TO PRESSURE TESTING BF.ELEV= KOP= ? Max Angle= 61°@ 7900 Datum MD= 11925 I 2208' J15-1/2"CAMBAL-OSSSVNIP,ID=4.562 I Datum TV D= 8800 SS 13-3/8"CSG,72#,7 L-80, I0=12.347 -I 2528' I I f 10974' I-15-1/2"BAKERPBRASSY I 5-1/2"TBG-PC,17#,L80,0.0232 bpf,ID=4.892 -I 10988' I , TOP OF 4-1/2" TBG-PC -I 10988' I . 10988' H 5-112"X 4-1/2"XO I 10993' —f9-5/8X4-1/2"BKR FHL PKR, ID=8.81" I TOP OF 7"LNR 11040' I 11059' 1-14-1/2"CAMCO DB-6 NIP,I0=3.813 I Minimum ID = 3.813" @ 11059' 4 1/2" CAMCO DB-6 NIPPLE 11070' I-14-1/2"BAKER SHEAROUT SUB I 4-1/2"TBG-PC, 12.6#,L80,0.0152 bpf, I0=3.958 --I 11072' I 1 NI 11072' H4-1/2"TUBING TAIL I 11060' -I ELMD TT-LOGGED 9/10/97 I 9-5/8"CSG,47#, L-80,ID=8.681 -{ 11306' I-4 PERFORATION SUMMARY I REF LOG: BHCS 09/02/83 ANGLE AT TOP PERF: 42°@ 11600' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11600-11641 0 01/05/09 F3-3/8 0.25 11653-11673 0 07/21/89 F3-3/8 1 11679-11680 0 07/21/89 r3-3/8 0.25 11686-11706 0 04/01/89 1'3-3/8 4 11710-11737 0 04/01/89 '3-3/8 4 11740-11768 0 10/19/87 7"LNR,29#,L-80,0.0371 bpf,ID=6.184-I 11888' I 4,,,,�,,, **f1••*1 •j•f!...AA 11885' H BAKER IBP I TD -I 11890' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/04/83 ORIGINAL COMPLETION 05/30/06 DTM WELLHEAD CORRECTION WELL: 04-20 01/02/01 SIS-MWH CONVERTED TO CANVAS 01/12/09 JKD/SV ADPERF(01/05/09) PERMIT No: 183-1190 01/16/01 SIS-MD INITIAL REDRAW API No: 50-029-20996-00 01/17/01 SIS-CL FINAL SEC 22 T11 N R15E 1858.39 FEL 3145.3 FNL 02/15/01 TP CORRECTIONS BP Exploration(Alaska) . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 29,2013 TO: Jim Regg --� / P.I.Supervisor eye( 11 4 I13 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC 04-20 FROM: Bob Noble PRUDHOE BAY UNIT 04-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv[J/ -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-20 API Well Number 50-029-20996-00-00 Inspector Name: Bob Noble Permit Number: 183-119-0 Inspection Date: 8/26/2013 Insp Num: mitRCN130826131243 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ■ Well 04 20 - T e 1n r W TVD 8174 IA � 1054 2500 2454 I, 2438 1_YP J -' 710 , 844 + Type P 852 • 'WRIST 2044 OA 710 813 1002 -r __ Interval 11 P/F Tubing 1005 1002 993 e es ; � i Notes: SCANNED li to 1 0 2013 Thursday,August 29,2013 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellIntegrityCoordinator @bp.com] Sent: Monday, August 19, 2013 11:43 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 DS Operators;AK, OPS PCC EOC TL;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D(DOA); Igbokwe, Chidiebere; G GPB FS2 Drillsites; G GPB FS2 DS; Regg, James B(DOA) Cc: Parks, Kevin D;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; Climer, Laurie A Subject: Under Evaluation: Injector 04-20(PTD#1831190) Due for 4 Year AOGCC Compliance MITIA All Injector 04-20 (PTD#1831190)can now be brought online post planned facility maintenance for AOGCC testing.The well has been reclassified as Under Evaluation,and has passed a pre AOGCC test to 2500 psi. Thank you, Laurie Climer (;Wei nate:Jack Div/,,ou BP Alaska Well Integrity Coordinator seat HEM aye'` ;`1"'t7495e WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent:Thursday, August 01, 2013 9:13 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OR; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace @alaska.gov'; Igbokwe, Chidiebere Cc: Parks, Kevin D; Clingingsmith, Mike 3; AK, D&C Projects Well Integrity Engineer; 'jim.regg @alaska.gov'; AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Injector 04-20(PTD #1831190) Due for 4 Year AOGCC Compliance MITIA All, Injector 04-20(PTD#1831190)is due for is due for its 4 year AOGCC compliance MITIA on 08/15/2013. The well is currently shut in for planned facility maintenance,and will not be placed on injection prior to the AOGCC MITIA anniversary date. The well is reclassified as Not Operable and will be added to the quarterly AOGCC not operable injector report. Plan forward: 1. Fullbore: Pre AOGCC MITIA to 2000 psi 2. Fullbore:AOGCC MITIA to 2000 psi when well is injecting and thermally stable 1. P P7'6 163 ccf , Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Tuesday, June 04, 2013 12:01 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: FW: PBU/East Area/FS2/04 defeated pilots Mr. Regg, Here is the info you requested on the DS-4 water injectors that were temporarily SI yesterday for pigging operations. Well PTD 04-06 1760830 04-08 1760100 04-10 1760420 04-13 1780310 04-15 1780370 04-19 201218 sata4EU • - - �(04-20 1831190 04-25 1860490 04-27 1852950 04-45 1940340 I apologize for the time delay since the initial email was sent. I will have this data available for future notification emails since I now know it is required. Thank you, Lee Hulme From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, June 04, 2013 8:35 AM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM Subject: RE: PBU/East Area/FS2/04 defeated pilots Lee, All of the PWI wells are$agged during pigging operations in order to prevent inadvertent blocked flow and a stuck pig.— This is how we always pig and how we will always pig every week in the future. It is a manned operation. The wells gagged yesterday were DS4-6,8,10,13,15,20,25,27,19,45. Wsnt 'White Ak, Ops FS2 DS Lead 907-659-5493 Alt: James Barndt From: AK, OPS FF Well Ops Comp Rep Sent: Tuesday, June 04, 2013 7:43 AM To: AK, OPS FS2 DS Ops Lead Cc: Regg, James B (DOA); Redmond, Randy; AK, OPS FF Well Ops Comp Rep 1 • Subject: FW: PBU/East Area/FS2/04 defeated pilots Importance: High Ron, Please supply me with a list of the water injectors on DS-04 that were defeated during the pigging operations yesterday so I can look up the PTD numbers and pass on to Mr. Regg. Thanks, Lee From: Regg, James B (DOA) [mailto:jim.reggPalaska.gov] Sent: Monday, June 03, 2013 9:08 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Our approvsl only covers injectors. And yes, I want a record of the injectors involved. Particularly since it is DS 4. Sent from Samsung Mobile Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep @bp.com> Date: 06/03/2013 6:32 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg @alaska.gov> Subject: RE: PBU/East Area/FS2/04 defeated pilots Mr. Regg, I just called the FS2 Field Lead Tech and he told me the pigging operation is completed and the temporary defeat for PWI wells has been lifted. It will take some research to determine which wells were involved since the DSD log blanketed the whole pad. I can get this data tomorrow if you still want it. Please advise. Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony-7187 (Alternate: Ryan J Hayes) From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Monday, June 03, 2013 5:01 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Please identify wells and PTD for each. Jim Regg AOGCC 2 333'W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@bp.com] Sent: Monday, June 03, 2013 4:25 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, D&C Well Integrity Coordinator; Bill, Michael L (ASRC); Starck, Jennifer L; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, RES GPB East Wells Opt Engr Subject: PBU/East Area/FS2/04 defeated pilots Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that wells on DS-04 are now operating with its SVS defeated as of 6/3/13 for pigging operations. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) 3 o7r27n o • ~cht~nnherger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth Well Job # N0.5567 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 Wes! 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD P2-16 F-03A B86M-00027. AVKP LDL - ! - 07/20/10 1 1 V-225 -00096 SCMT 1r^~ ( 07/22/10 1 1 5-100 2 5tUS 09 BBKA-00039 BCZ2-00014 USIT _ USIT ... ,~ ~ 07/01/10 07/14/10 1 1 1 1 - - 1.15/P-25 W-19A 01-228 8-20 04-20 B-18 OS-32A H-25 P2-34 BC22-00016 AVKP-00094 BCRD-00036 AZ2F-00042 AY1M-00042 BCRJ-00020 AVKP-00082 89K5-00040 BCRD-00017 AVVO.00063 LDL LDL _ USIT ~ MCNL RST - RST RST RST _ RST RST - 07/17/10 07/11/10 07/25/10 05/19/10 05/07/10 05/30/10 06/02/10 05/19/10 05/10/10 04/17/10 i 1 1 1 1 1 1 1 1 1 1 i 1 y 1 1 1 1 1 1 PLEASE ACKN~WLFnGF NFC PtUr av crr_uiu r_ Bran oerno.,,ur .,.,~ ........ ~..... ~.._ BP Exploration (Alaska) Inc. Petrotechnicai Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 at.f 5 ..... . ,y ~ I (a ~ ~ STATEOFALASKA ~l', ~~~~-~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanicat Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~Q'„ ~ jG(~~~~, Prudhoe Bay / PBU / DS 04 ~~ `1`1 08/15/09 Torin Roschinger Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-20 ' Type Inj. W ND ~8,174' Tubing 1,250 1,250 1,250 1,250 Interval 4 P.T.D. 1831190 Type test P Test psi ~'2043.5 Casing 530 ~2,500 2,430 2,430 P/F P Notes: AOGCC MITIA to 2500 psi, witness declined OA 50 70 70 70 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D= Drilling Waste M= Annulus Monitoring G= Gas P= Standard Pressure Test I= Industrial Wastewater f2 = Internal Radioactive Tracer Survey N= Not Injecting A= Temperature Anomaly Survey W= Water D= Differential Temperature Test . , ...,~;~ „ ~l i{; INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27I07 MIT PBU 04-20 08-15-09.x1s l ~ STATE OF ALASKA ' G{ ~ ~ ALA OIL AND GAS CONSERVATION COM~ION ~ REPORT OF SUNDRY WELL OPERATIONS ~C1VE~ JAN 0 ~ 2009 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated AIaSk~E~7flr ` SSI Perforrned: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well ncnorage 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 183-1190 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ~ ~' 6. API Number: Anchorage, AK 99519-6612 50-029-20996-00-00' 7. KB Elevation (ft): 9. Well Name and Number: 57 KB PBU 04-20 8. Property Designation: 10. Field/Pool(s): ADLO-028322 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11890 ~ feet Plugs (measured) None true vertical 8834.25 ~ feet Junk (measured) 11885' IBP ~~aa Effective Depth measured 11843 feet ~~,':4 3.1~t~~~'' Fj-\~ ~. '~U~b true vertical 8798.51 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" Surface - 80' Surface - 80' Surface 2528 13-3/8" 72# L-80 Surface - 2528' Surface - 2528' 5380 2670 Production 11306 9-5/8" 47# L-80 Surface - 11306' Surface - 8696' 6870 4760 Liner 11888 7" 29# L-80 Surface - 11888' Surface - 8833' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 35 - 10974 4-1/2" 12.6# L-80 10988 -11072 Packers and SSSV (type and measured depth) 4-1 /2" Baker FHL Packer 10993 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 12862 1518 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: _ Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL 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 Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 1/7/2009 m Form 10-404 Revised 04/2006 ~ ~~'~, ,~~~ ~ ~ %00~ ~-~~~ Submit Original Only 04-20 183-119 PERF ~TT~[:HMFNT • • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-20 10/19/87 PER 11,740. 11,768. 8,720.19 8,741.48 04-20 4/1/89 APF 11,685.5 11,686.5 8,678.76 8,679.52 04-20 4/1/89 APF 11,694.5 11,695.5 8,685.59 8,686.35 04-20 4/1/89 APF 11,697.5 11,698.5 8,687.87 8,688.63 04-20 4/1/89 APF 11,703.5 11,704.5 8,692.43 8,693.19 04-20 4/1/89 APF 11,705.5 11,706.5 8,693.95 8,694.71 04-20 4/1/89 APF 11,710. 11,737. 8,697.37 8,717.91 04-20 7/21/89 APF 11,678.5 11,679.5 8,673.45 8,674.21 04-20 7/21/89 APF 11,672.5 11,673.5 8,668.9 8,669.66 04-20 7/21/89 APF 11,668.5 11,669.5 8,665.87 8,666.63 04-20 7/21/89 APF 11,652.5 11,653.5 8,653.78 8,654.53 04-20 7/21/89 APF 11,660.5 11,661.5 8,659.82 8,660.58 04-20 7/21/89 APF 11,656.5 11,657.5 8,656.8 8,657.56 04-20 7/21/89 APF 11,664.5 11,665.5 8,662.85 8,663.6 04-20 1/4/09 APF 11,620. 11,641. 8,629.3 8,645.1 04-20 1/5/09 APF 11,600. 11,620. 8,614.3 8,629.3 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 04-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***WELL INJECTING ON ARRIVAL*** INITIAL T/I/0=300/80/0. LRS PERFORMED FREEZE PROTECT ON TUBING AND FLOW LINE PRIOR TO RIG UP. SHUT WELL IN AT WING, RU AND PERFORATE INTERVAL FROM 11620'-11641' WITH 3 3/8" PJ 3406, 6 SPF, 60 DEG. REFERENCE LOG =SLB BHCS DATED 02 SEP 1983, PERFORATIONS TIED INTO SLB CNL DATED 02 SEP 1987. THERE IS NO DEPTH OFFSET BETWEEN THE REFERENCE LOG AND TIE IN LOG. *** JOB CONTINUED 05 JAN 2009 *** ***JOB CONTINUED FROM 4 JAN 2009*** PERFORATE INTERVAL FROM 11600'-11620' WITH 3 3/8" PJ 3406, 6 SPF, 60 DEG. REFERENCE LOG =SLB BHCS DATED 02 SEP 1983, PERFORATIONS TIED INTO SLB CNL DATED 02 SEP 1987. THERE IS NO DEPTH OFFSET BETWEEN THE REFERENCE LOG AND TIE IN LOG. CONFIRM VALVE POSITIONS W/ DSO UPON DEPARTURE, WING OPEN, FINAL T/I/O = 0/100/0 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 4 meth 5 Total ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 1?~q 'll ~ih DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-20 PRUDHOE BAY UNIT 04-20 /\\G \q,"b FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv $,4- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-20 Insp Num: mitCS0508l6132424 Rei Insp Num: API Well Number: 50-029-20996-00-00 Permit Number: 183-119-0 Inspector Name: Chuck Scheve Inspection Date: 8/16/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __h___.____._._-,--_.........__._.......,--._ r---------·-·--· I ' -----¡------ ... ..--·T-·---·..---·..-....--..·-r··----..- Well I 04-20 iType Inj. I W . TVD I 8174 ,IA I 1600 ' 2500 ! 2460 2440 I I -·P'-T. I I83I-·ï90~ypei~~tTSPT-1 Test ps¡-·-¡W43.s+ÜÄ-r--" -~20' :-·9Õ-----i9ö-----t----90..-¡--·----¡·-·----··- ____L. -..--- ---- ___L=-.J_______:........L_.._.____L.._+ ---.----¡-. ---+- --.--1-----. -!--'---T'--'- 2!!terval 4'0TST..__rLL ___~_____ _.____ Tu_~~_~g..L__=~_~.J.__. 2IOO__L_~~~___~_21~_L_____I__.._____ Notes: The pretest pressures were observed for 30+ minutes and found stable '(".".",', (',.....¡',' {J..'_n.. r.I..'¡..::,·..·.I· I;;"~(( -'l¡¡" \~W¡,~tJ::::\; i (~, f~ 10, {... ~ \,5' ",,o.j i'.~ ,I'.. "iJ [;... ..- ~. L I Wednesday, August 17,2005 Page I of 1 . . State of Alaska Alaska 011 and Gas Conservation Commission TO: Cammy 0 Taylor rJj{ DATE: September 16, 2001 Chairman )....... SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder . .Q?'fl(~ f BPX P.I. Supervisorj<fJ-- -;¡:Y \ DS 4 Qc...~ \ \ 4-20 & 4-49 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL MEMORANDUM Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Tesfs Details I traveled to BPXs Drill Site 4 and witnessed the 4 year MIT on well 4-20 and the initial MIT on converted well 4-49. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 2 hour ~ M IT report form 5/12/00 L.G. MIT PBU 4-20 & 4-49 9-16-01 CS.xls 10/1/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operal~on Shutdown _ SUrnulate__ Plugging _ Per/orate 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 57' RKB 3. Address: Exp~orato[y_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1206' FSL, 1753' FWL, Sec 26, T11N, R15E, UM. 4-20i At top of productive interval: 9. Permit number/approval number: 1783' FSL, 1753' FEL, Sec 22, T11 N, R15E, UM. 83-119 / 397-094 At effective depth: 10. APl number: 2104' FSL, 1858' FEL, Sec 22, T11N, R15E, UM. 50-029-20996 At total depth: 11. Field/Pool: 2134' FSL, 1869' FEL, Sec 22, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11890 feet Plugs (measured) Tagged Fill @ 11678' U D (11/12/97). true vertical 8834 feet Effective Depth: measured 11678 feet Junk (measured) true vertical 8673 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 385 Sx Arclicset 80' 80' Surface 2528' 13-3/8" 1935 Sx Fondu & 2528' 2528' 400 Sx PFC Production 11306' 9-5/8" 500 Sx Class G & 11306' 8396' 300 Sx PFC Liner 848' 7" 358 Sx Class G 11888' 8833' Perforation Depth measured 11653 - 11673'; 11679'; 11686'; 11695'; 11698'; 11704'; 11706'; 11710- 11737'; 11740 - 11768' true vertical 8654 - 8669'; 8674'; 8679'; 8686'; 8688'; 8693'; 8694'; 8697 - 8718'; 8720 - 8741' RECEIVE Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, POT @ 11988' MD; 4-1/2", 12.6#, L-80, POT @ 11072' MD. -'0 I% Packers and SSS¥ (type and measured depth) Baker FHL Packer @ 10993' MD; Camco BaI-O SSSV @ 2208' MD. 13. Stimulation er cement squeeze summary .... /'A['IC, II'J~ ~'d~ Intervals treated (measured} see attachedO IGINAL Intervals treated (measured) 14. Representitive Daily Average Production or Iniection Data OiI-Bbl Gas-Mol Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - Shut In Subsequent to operation - 7635 1926 15. Atlachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~,~,~ '~1., ~ Title: En~lineerin9 Supervisor Date //-"~ ~- ~' 7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 4-20i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE OF LEAKY PACKER 4/7/97: Performed a leak detection log that indicated a packer leak existed at 10993' MD. 6/18/97: RIH & set an inflatable Bridge Plug at 11160' MD. PU & pumped gelled sand slurry down CT containing 20/40 mesh sand on top of IBP, to isolate all the open perf intervals located between 11653 - 11768' MD. POOH leaving estimated TOS at 11065' MD. RD. 6/21/97: Performed an injectivity leak rate test on well & took returns up IA. 6/29/97 - 7/8/97: Performed sand FCO & tried to fish fallen IBP. IBP had dropped to PBTD at 11789' MD during FCO. 7/13/97: RIH w/CT & adjusted sand plug height to isolate the open perforation intervals located between 11653 - 11768' MD. POOH w/CT leaving final TOS at 11062' MD. RD. 7/14/97: RIH & tagged TOS at 11055' MD. 7/20/97: Performed a Cement Squeeze of the leaking Packer as follows: MIRU &PT equipment. RIH &tagged TOS at 11059' MD. Reversed excess sand from WBto 11067' MD, then pumped 1 bbl of Neat Latex Acid Resistive Cement, followed by 4.5 bbls of LARC w/fibers, to squeeze the leaking packer. Circulated 3 bbls of cement past packer into IA & left 2.5 bbls of cement plug in tubing across the packer. POOH w/CT & left 150 whp on well. RD. 7/23/97: RIH & tagged TOC at 10885' MD. 7/29/97: RIH w/CT milling BHA. Milled cement from 10881' through the sand cement interface at 11062' MD, then cleaned out sand plug to 11075' MD. Noted IA pressure rise on break through the sand/cement interface. Attempted MITIA to 3000 psi. MIT failed; lost 500 psi in 30 minutes. PU tubing to 3000 psi & IA pressure slowly climbed to 700 psi. POOH. RD. 8/6/97: RIH w/CT & jetted sand from WB to obstruction encountered at 11035' MD. POOH w/CT. RD. 8/29/97: RIH w/CT milling BHA. Milled cement & performed fill cleanout from 10881' to 11075' MD. POOH. RD. 9/4/97: MITT failed; leaked at 4.6 gpm at 3000 psi. MITIA to 3000 psi passed. 9/25/97 - 11/12/97: Performed CT FCO's (9/25, 10/3, & 10/23), bailed fill w/bailer (10/17, 10/27 - 10/29), & attempted to fish IBP rubber element (10/29 & 11/11); no recovery. RIH w/CT milling BHA (11/12) & milled through junk in tubing. RI H & tagged bottom fill at 11678' MD. POOH. RD. 11/17/97: Performed MITIA to 2300psi; passed. Placed the well on produced water injection & obtained a valid injection rate. FLHNNIN5 FNUUH~ ID'6S9-5917 - ~ ., ARCO Alaska: Inc. ~g' RUG 02'97 15'08 No.O05 P.O1 X~.R0X FAX COVSa SI~ $$~-t~ ~l Send Verify Dat, ~;~- 'rime Sent Send To: ii - -- iii III II ' -- Checl( Locati6'r~-'Below: Name 8la;y- Od~,~ e~_[l Bldg/Rm /~0~("_.. _C.- ......... Phone No. ,,.0 ~ ~'- -~ 5'/--/~ PLEASE XEROX COPIES FOR: REMARKS: -- ' .......... ilii i One Touq_h.:Olal Number~ #~ ( ) #2 ( ) #3 ( ) #~ ( ) #$ ( ) #6 ( ) #? ( ) #~ ( ) #~ ( ) #~o( #~( ) #~2( ) ( ) OTHER' SEND ( ) ( ) V;-Rl.V #, From Company Sent By [ Verified By No, of pages following cover ~ IOperator I_ P~flNNIN6 PRUDHBE to:tu i~u.uuo r.uq .,. DATE: 8/1/97 ID'559-591F HUb U2'~F ~.NNULAR COMMUNICATION TESTII,~ MECHANICAL INTEGRITY TEST ... WELL: 4-2O TYPE'. TBG & IA Well Status: SHUT IN TBG: o CONTROL: NA INITIAL PRESSURE DATA TYPE: IA: ~eo OA: BALANCE: N^ MIT: PASS BLED IA OA FROM TYPE OF FLUID AND VOLUME BLED: .'~. 'r, ' ' ii ii · PRE-TEST PREPARATIONS PSI TO PSI HRS TBG & IA MIN FL @ SURF~ TEST PRESSURES TIME TBG IA OA COMMENTS 7:55 0 180 0 START PUMPING TIME 10: 31 3000 50 0 ST/~:IT TEST 10:46 2930 70 0 10:49 3000 70 0 START TEST 11:04 2970 1 O0 0 11 '19 29.65 . 1 ,!,5 0 PASS ........... ........ START:I'EST .. , il ,,, TOTAL VOLUME PUMPED: 1 BBLS OF DIESEL FINAL PRESSURES TBG: 29o IA: 1 20 OA: o OBSERVATIONS / COMMENTS RNAL STEPS MUST BE COMPLETED AND CHECKED OFF;ll ~ -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION I X 'i- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TE~TING. ncnaraga L~-- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL Witness:RJ ~ i ,~ ...... " PLANNING PRUDHOE 15'11No.UUb K.U~ DATE: 8/1/97' TYPE: TBG & IA Well Status: SHUT IN TBG: 0 CONTROL: NA BLED IA CA FROM TYPE OF FLUID AND VOLUME BLED: ,, -- . ID'659-5917 RUG 02'97 _ NNULAR COMMUNICATION TESTh~,~ MECHANICAL INTEGRITY TEST ,, INITIAL PRESSURE DATA TYPE: WELL: 4-2o MIT: PASS · IA: 180 CA: o BALANCE: NA .. PRE-TEST PREPARATIONS PSI TO PSI ..- .. TBG & IA TEST PRESSURES MIN FL @ SURFAC~ TIME TBG IA CA COMM~ 7:$5 .... 0 ..... 180 0 START PUMPING TIME 8:56 3020 .,.2525 0 START TEST 9:11 3000 2680 0 ,,, . ...... 9:26 2990 2580 0 , ,,,, ,,, ..... 9:4,3 300q, 3000 0 STARTTEST 9:58. 2970 2890 0 ........ 10:13 2960 ,. 2850 0 .. PASS ....... (~ START TEST ,, , ,, ,,, ... ,,, TOTAL VOLUME PUMPED: 1 1 BBLS OF DIESEL -- '~ . =m FINAL PRESSURES TBG: 290 IA: 1 20 . OBSERVATIONS / COMMENTS FINAL STEPS MUST BE COMPLETED AND CHECKED OFFll, X I- ^.o .-- OA: - FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. - NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUME8 PUMPED AND STATUS OF WELL. Wltness:FU ,, :$~'S ~ 1997 · Alaska Oil & Gas (;otis, Ooi-np~s:: Ancharage P~flNNING PRUDHOE HU~ uz'~r to-zu no.uuo r.uo DATE: TYPE: 7131/97 ID' 659-$917 jINULAR COMMUNICATION TEST~...~ MECHANICAL INTEGRITY TEST Well Status: SHUT IN TBG: VAC CONTROL: NA IA WELL: 4-20 INITIAL PRESSURE DATA IA: 150 OA: 0 BALANCE: NA ,,, MIT: FAIL PRE-TEST PREPARATIONS BLED IA OA FROM PSI TO PS1 HRS MIN TYPE OF FLUID AND VOLUME BLED: IA FL @ SURF~ TEST PRESSURES TIME TBG IA OA COMMENT~ ...!. 0:3 0 VAC 150 0 START PUMPING TIME 11 ;08 0 3000 0 START TEST " ..... i_ ,, , ,, , , ......... 11:23 0 2850 ..... 0 FAIL ,, .~. ~~, ,,,, ......... 11:27 0 3000 0 START TEST 11:42 0 2850 0 FAIL --,, 11: 45 0 3000 0 START TEST 12:00 0 2860 0 FAIL _.. ,,, .... _ · 1"1'1' ~_- _ TOTAL VOLUME PUMPED: 1 0 BBLS OF DIESEL FINAL PRESSURES TBG: o IA: 1 5 0 OA: o OBSERVATIONS / COMMENTS FINAL STEPS MUST BE COMPLETED AND CHECKED OFFII! --CASING VALVE WITH LOAD AND TEST INFORMATION FLAG THE ~- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING, - NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL, Wltness:PJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission David Johnston, Chairman DATE: May 16, 1997 TI~U: Blair Wondzeli-~ FILE NO: P. I. Supervisor gf9hepee.doc Confidential: Yes _, NoX, Attachment Only . FEOM: Doug Amos, c-~ ~3~-- SUBJECT: Petroleum Inspector Well Head Prudhoe Oil Pool DS4-20 Frid .ay, May 16, 1997: I traveled to Arco's DS4-20 well to inspect the conditiono~Tf the well head..~-~ c,,~ ~.~=-~ p o-~ ~ ~ ~ ~ ~ ] ~ ~ ~ ~"~- The ~!1 ~s shut-in ~th the SSV and master valves closed, the cellar was full of water and the well head ~s leaning approximately 3© off vedi~l. I was unable to detect any motion of the well head, fudher investigation should be made after ~_/~~,~~ break-up. ~.~c ~v,~ - i contacted Ar~ EOA, Annular Communi~tions Engin~r, Ri~ard O~iz and ask ~ if his database showed any ~11 head problems with this well. The only information his database showed, regarding problems ~th the well, was a failed MIT in March of this year. Tests indicted that the packer had failed and the well was shut-in. SUMMARY: I inspected the condition of the well head at Arco's PBU DS4-20 well. Attachment: NONE : 1 I~L; 'rKl:~ KIZ~UKU~ UCYF_J_.U~~ ~.~-,~. . ?F't? 85-lt9 PoSl-it* Fax Note 7671 Phone Fax # 4 -2o RECEIVED kd/kY 9 !997 · .as~ .Oit & Gas (;ohs. SENT BY:ARCO ALASKA INC ; 5- 9-97 ; l:31P~ ;PRB RESOURCE DEVELOP-~ I~07 27t~ 7~a~Z;g z/ z , 2~ ende~ 4-20i Packer Squeeze [revised 5/9/97) i I RU slietdtne and tag fill. I RU CT t.o RIH & set a 3-3/8" IBP at - 11,160' 2,100 R)s of 20/40 ;lver sand to bring sand top (window - 11,065' - 11,070' ELM), : ?rocedure Rill & circulate irt 5 - 10' of tubing taft 3. Perform injectivity test w/crude to confirm circulation arm]nd the packer, 4. RU CTU. RU 'to circulate down CTU w/heated seawater w/scale inhibitor or 1% KC1 water, 5. Batch mix & pump 5.0 bbls LARC cement w/1% fibers bwoc. 6. Open IA to rctm-ns to Lank. Circulate around tubh~g tail & up past packer. 7, Open choke on backside & pinup biozm~ down CFI' for clean-ou.t, der w/blozan to packer at 10,993' MD, 8. Afl. er 2 days WOC, RU $11cldinc unit. Tag cement top. Perform MIT to 3000 psi. 9. RU CTU & RIH w/3.8" mill to mill through cement do'wn to sand top. POOH w/IBP, 10. RU slickline and tag ~l, 11, Bring well on injecUon. RE E VED t~,y 9 1997' & Gas Cons. C;ommiss~u~ Anchorage May 9, 1997 .'"'-"' STATE OF ALASKA , ..,KA OIL AND GAS CONSERVATION COMMISS,.. APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operation Shutdown _ Reenter suspended well _ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate __ Change approved program Pull tubing Variance Pedo rate _ Other_X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 57' RKB 3. Address: Exploratory_ 7. Unit or Properly: P.O. Box 100360 Stratagrapic _ Anchorage, AK 99510-0360 Service x Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1206' FSL, 1753' FWL, Sec 26, T11N, R15E, UM 4-20i At top of productive interval: 9. Permit number: 1783' FSL, 1753' FEL, Sec 22, T11 N, R1 hE, UM 83-119 At effective depth: 10. APl number: 2104' FSL, 1858' FEL, Sec 22, T11N, R15E, UM 50-029-20996 At total depth: 11. Field/Pool: 2134' FSL, 1869' FEL, Sec 22, T11N, R15E, UM Prudhoe Bay' Oil Pool 12. Present well condition summary Total Depth: measured 11890 feet Plugs (measured) true vertical 8834 feet MAY 81997 Effective Depth: measured 11843 feet Junk (measured) true vedical 8798 feet ~ ~j~ ~ Casing Length Size Cemented Measured depth --~'"J~'~rilCal depth Conductor 80' 20" 385 Sx Arctic Set 80' 80' Surface 2528' 13-3/8" 1935 Sx Fondu, 2528' 2528' & 400 Sx PFC Production 11306' 9-5/8" 500 Sx G & 300 PFC 11306' 8396' Liner 848' 7" 358 Sx Class G 11888' 8833' Perforation Depth measured 11653 - 11673'; 11679'; 11686'; 11695'; 11698'; 11704'; 11706'; 11710- 11737'; 11740- 11768' true vertical 8654 - 8669'; 8674'; 8679'; 8686'; 8688'; 8693'; 8694'; 8697 - 8718'; 8720 - 8741' Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993' MD; Camco BaI-O SSSV @ 2208' MD. 13. Attachments Description summary of proposal_ X Detailed operations program _ BOP sketch _ X 14. Estimated date for commencing operation 15. Status of well classification as: May, 1997 Oil _ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service Injector 17. I hereby cedify that the forgoing is true and correct tothe best of my knowledge. -- ~ ¢---/. Signe~'"'"'-~~' ,,Z~"~" ~".~'~'d'.¢':"~% Title: Engineering Supervisor Date w ;3 FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness - .,,.,d I Approval No. ~'~ ~,,,/ ,~ ~/~, _ _ ~OOV, I -'"//" Plug integrety _ BOP test Location clearance Mechanical integrety t st _ Subsequent form required 10- /'~ o ~ ~ ¥~c,;.,;/I j ~/'...J'""'"' - Original Signed By ~,~"-¢'~ _ Approved byorder of the Commissioner David W. Johnston her Date ' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 4-20 Intended Packer Squeeze Procedure lO. 11. 1. RU slickline and tag fill. 2. RU CT to RIH & set a 3-3/8" IBP at ~ 11,160' ELM. RIH & circulate in 2, 100 lbs of 20/40 river sand to bring sand top within 5 - 10' of tubing tail (window - 11,065' - 11,070' ELM). 3. Perform injectivity test w/crude to confirm circulation around the packer. 4. RU CTU. RU to circulate down CTU w/heated seawater w/scale inhibitor or 1% KC1 water. 5. Batch mix & pump 5.0 bbls LARC cement w/1% fibers bwoc. 6. Open IA to returns to tank. Circulate around tubing tail & up past packer. 7. Open choke on backside & pump biozan down CT for clean-out. Jet w/biozan to packer at 10,993' MD. 8. After 2 days WOC, RU slickline unit. Tag cement top. 9. RU CTU & RIH w/3.8" mill to mill through cement down to sand top. POOH w/IBP. RU slickline and tag fill. MIT the IA to 3,000 psi. Bring well on injection. May 6, 1997 6 4 3 2 COILED TUBIN~ UNIT BOP EOU ! PMENT 1. 5000 PSI ?" WELLHEAD OONNECTOR FLAhGE 2. 5000 PSI 4 1/16" PIPE RAIDS ,3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PS! 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSI 4 1/16" STUFFING BOX 5 H]REL]NE BOP EOUIPMENT · 1. 5000 PSI 7" WELLHEAD C',ONNECIOR FLANGE 2. 5000 PSI WIRELINE RAUS (VARIABLE SIZE) , ,1. ~0O0 PSI 4 1/6" LUBRICATOR ; 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF GeoQuest 500 W. International Airport Road Ar~chorage, AK 99518-1199 ATTN: Sherrie NO. 9183 Company: 1/10/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 3-7 "7 ~.~, -- ~ _~'~ STATIC BH PRESS SURVEY (12-11-94) I 1 D.S. 3-14~"'~ ('~ ~"'"c7.-,.-, TUBG CU'i-rER RECORD (12-11-94) I 1 D.S. 3-14 l I -'(.~ ~) '~--' STATIC BE PRESS SURVEY (12-11-94) I 1 D.S. 4-27 ~{~ ~'~-'~--~ ~'~ STATIC BH PRESS SURVEY (12-14-94) 1 1 D.S. 4-28 ~'~ ~',." ~-~'~ STATIC BH PRESS SURVEY (12-14-94) I 1 D.S. 4-44 _ ~ I~ ..-(3"J',~ DUAL BURST TDT-P (12-13-94) I 1 D.S. 4-45 ~/.~-~ ~.~L~ DUAL BURST TDT-P (12-12-94) I 1 D.S. 5-16A C~ ~ ~-{ ?.;.~ TUBG PUNCHER & POGLM SE'I-rING RECORD (12-13-94) I 1 D.S. 9-32 _~."3-~-",J J~" INJEC PROFILE (12-12-94) / I 1 D.S. 11-32 c/- c./,_../~,~1 'STATIC BE PRESS SURVEY (12-12-94) ~ I 1 D.S. 15-40 ~ ~--- \.'~ PDC (12-11-94) I 1 ,. ss su,v D.S. 4-20 ~c ~ _ t~ STATIC PRESS SURVEY (12-14-94) I 1 D.S. 4-20 [,) ,,) I I [ INJEC PROFILE (12-14-94) I 1 D.S. 5-33 ~, 1';' (.,3 (0q2 PERF RECORD (12-19-94) I 1 D.S. 11-30 ~~~7 STATIC PRESS SURVEY (12-16-94) I 1 D.S. 12-27 INJEC PROFILE (12-21-94) 1 1 D.S. 15-23 -' I PROD LOG (CT E-LINE) (12-19-94) I 1 D.S. 16-21 (~ ~)~ I ~ INFLATABLE BRIDGE PLUG SET RECORD (12-20-94) I .~ I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ANCH:]RAG~- AI A:'7 K A DATE' i (')-i 7-90 i -25 9-:.:-i~- 90 4- ! 9- i 4 .... 1.---',::7 4-.- :,'.: 9- '; 4- 9'.:D 4-2. 9-i 6-90 -'" .... '" 9-:,2 'i --9,'--" 4-i i.-3 ".-.'-"-::2 '..; -9,::.:, 4'-- i .7; ? '- 2 i .... 7' ;'-..::, 4--"2 (') 9--:.'5- 9 ,.':'_.-' 9--4 i 9- '2.7,,- 9 '::':' i :5- 'i 9-'i ':..-:'-9"5 ! 8 -" i 4 9 -' '-2:7 - 5;' (') F'WDWi '-2A 9-2"5-'7'¢ F'WDWi -2A 9-22-9¢ R E CiE i V E D B"," _~ ~ HAVE A N'rCE DAY! 'D HOLE FZNAL. S T H I':, i:;.', i.J i:-i 4 ~,5" PPf"~DliF:'i'lOi'4 F'i;.".Oi-'r' ~- iN:lIN i, 2",'S~" , .... ., ,. -- , ~- b 12. G F;-'. S U R V E[ Y i:;.: U N 'i , 5:" ,",:-,,'~r-,~,'--",-'rON F:F.:FiFZI ¢: F'L! , ,.,.. .... ,.. .............. ., f.,..I i., _..." F' E R F R E C 0 R D i:;.: t..li"...! i , !5" F:i:;.:C)DUCT!i/.)N F'ROFiLE RUN i , 5:" '", :"" -"'", ~;;' ,", r" ."'. :": E', i" ~:. i".., ~-: .:" ~ . ~ ,,'-. I.~ Ri i h'J"i ti.';" ............... ~..~ · · ..t,:.,- ..... v i4.'.I1.¢4 i , ':'"" TEHF .............. TEi'"iF' SURVEY i:;:Ui'-4 '~ 5:" PF,:ODUCi-i-"",®~,, i:":;'or:zLE,, , RUN 1 , '3" T'RE- ...... F;'UNCHER F,'Er.,"iR'P,.. ...... , I:::UN i, ..,";" ;-i;,....~, ......-'r'-,"~._.:.,~.. i-;:LJN i , 2.'.':" PERF ""~. "" ,,.,_,...U,,......, I:,..'UNi , 5" N "..',"HE A f"f'ACHED CUPY A,? I:;:!ECii-"iF"i-JJi-: DA'f'A.. THE D 15'TR I BUT I ON ,,~ rE~"aa'RAL,_. ,., F Ii_!E~ :~: CI-iEVRON D & M · ,- ,'-. XTEbiS T ON EXPLORATION "" E'x'XON MARATHON ~ MOBIL "1~- COF..'Rr-:CTED Af:'I.$ FOR F'WDWi-2A P H :,r. i_ L_ ! F' $ F'B Wr-:'L.L. FI:LES R & D ,BPX '"'- STATE F'~F AL. ASI<A · ir ~ T E X A rS 0 ]:S 5¢-029-22024-'-0 t RECEIVED OCT 1 9 lggO Oil & ~s Con~. Commission Anchorage .,'-~!-..CO AI_A:~:KA, 'r~'JC P., 0 ~ B 0 X 'i 0 ('::: ?.'-- 6 (') ANCHORAGE, ALA£KA 995 i (-} DATE' ;'- --- .-... 2n 90 REFERENC:E' ARC'.]] iSASED HOLE i:iNAi_""'-: 2- i i 8 "" :.:3 i '-- 90 S '- 2 8 -'7 A - o ;.-; 3 '"' >"., o .._ ? -? -- ,.--:, A ..S-~ 3 8-22---9':~:' ..-3 .- 2 '-:'!:, 8 - 22 - 9 ;:._:, · :~- 2,:'-) 9-3--90 6- ~ 'i :.:::- 3 i --':..-:"':'"_.'~ .4-;.2 ,': 9- ~ .... 0 -- }--'~ -- ':.' A ,.- --¥~: ....... 9 -4 i 9'- i ':'-:'- 9':'-:' 9-'43 ':,.:'- ~ !5-9'?;' ~ i-7 ~'-]-27-9;.::' i 'i ~ ',iii: o_ 27 - 9 :'-; ~ 3-26 8-5i -90 'i 4-54 8-27-9(') F'!_IEASE ':SIGN AND RETURN THE AT'¥ACHED F:OPY AZ; RECEIVED · S EP 2 6 19 0 Alaska Oil & Gas Cons. Commission Anchorage RF'CEiF'T Of: RECEIVED BY .~- -~- HAVE A NICF_ DA"','! D i 3.'TR ]: BLJT 3: ON -.- r r-- ;,..1 T I;. A / F'r LES ~ F'H :[LL'[P.~ · f~ :_.l..-I: I I-.~ ~ ..~ " CHEVRON 'PB WEI_L F]:LE3' .I. D ,~ M n, D ~ EXTENSION EXPLORATION :~,: BF'X ~ EXXON ~ STATE OF ALA3.'KA MARATHON TEXACO ~ MOBIL -I ·-..-._~. ...... I; l~- FOR 4-20 T5 _, ,. ..:.0°° · .',+ 'I-FIE C:OR-or---'-rr:' AF' =-','-",-02°-''~ , 6 :.,.'--:~ 'THE COF:I-?ECTED A!:'!~- FOR '7-,5:3 :[/~ 50--,'.-':,29-2i8'09, ARCO ALASKA, INC. F'.O. BOX i~OS60 ANCHORAGE, ALASKA 995 t (~ DATE' 9-29-89 REFERENCE' ARCO CASED HOLE FINALS ~-t8 9-5;-89 INJECTION PROFI[.E RUN 4-S 9-t ~-_ 9 CET RUN 4-20 9-~-89 INJECTION PROFILE RUN i, 5-t 9 9-1 S-89 CET RUN 6-5 9-i~-89 LEAK DETECTION RUN i, 6-9 9-9-89 PRODUCTION PF:OFII_E RUN t, 7-28 9-7-89 PRODUCTION F'ROFILE RUN i, ~ ~-2S 9-24-89 COLLAR/PERF RUN t~-24 9-6-89 PRODUCTION PROFILE RUN ~, t t-26 9-2~-89 COLLAR/F'ERF RUN ~ , t4-72 9-i,¢)-89 LEAK DETECTION RUN t , ~4-72 9-22-89 PERF RECORD '~ RUN t, t6-4 9-t-89 LEAl( DETECTION RUN i , ~7-t 9-4-89 PRODUCTION PROFILE RUN l, t?-t 9-8-89 PITS RUN t , PLEASE SIGN AND RETURN THE ATTACHED COPY A~ RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY~ SALLY HOFFECKER ATO-i~ CT -9' & Cons. TRANS~ 89~4 DISTRIBUTION CENTRAL FILES ~ F'HILLIF'S CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL 5' 5' 5" _, 5" 5' 5" 5' i 5' 5" 5' (;ANCO $CH CAMCO ~'CH CAMCO CAMCO C A M C 0 C(4MCO A'[LAS CAMCO ~'CH CAHCO CAMCO CAMCO ARCO Alaska, In Prudhoe B,.., Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 1, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-20 Permit No. 83-119 Dear Mr. Chatterton' Enclosed, in duplicate, are the Report of Sundry Well Operations and Daily Report of Well Operations detailing the work completed on the above- mentioned wells. truly yours, D. F. Scheve DFS/WDM/ljm Attachment cc' J.S. Dietz, BP Exploration J. Gruber- ATO 1478 PI(DS4-20)W1-3 ~daska 0ii & Gas ConS. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASI' ";)ILAND GAS CONSERVATION ( vlMISSION REPOR'/ OF SUNDRY WELL OPE. RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing ~ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1206' FSL, 1753' FWL, Sec. 26, T11 N, R15E, UM At top of productive interval 1783' FSL, 1753' FEL, Sec. 22, T11 N, R15E, UM At effective depth 2104' FSL, 1858' FEL, Sec. 22, T11N, R15E, UM At total depth 2134' FSL, 1869' FEL, Sec. 22, T11 N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 57' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number DS4-20 9. Permit number/approval number 83-119 / 9-611 10. APl number 50 - 029-20996 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11890 feet Plugs(measured) 8834 feet Effective depth: measured 11843 feet true vertical 8798 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 385 sx 80' 80' Su dace 2528' 13-3/8" 2335 sx 2528' 2528' Production 11306' 9-5/8" 800 sx 11306' 8396' Liner 848' 7" 358 sx 11040-11888' 8207-8833' Perforation depth: measured 11740-11768', 11704-11737', 11686-11698', 11679'-11679', 11653-11673' true vertical 8720-8741', 8693-8718', 8679-8688', 8673-8673', 8654-8669' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 & 4-1/2", 12.6#, L-80, 11306' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993' MD, Camco BAL-O SSSV @ 2208'MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. ..... ..-. Alaska 0il & Gas Cons. C°mmJss~0n Representative Daily Averaqe Produ~ion or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Md W~er-Bbl Casing Pressure Tubing Pressure 6000 280 1186 800O 500 1340 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2~'j~~~~f'~~- Title Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Summary of Perforating Operations DS 4-20 Began perforating operations on 21 July 1989. Backflowed well with artificial lift gas to achieve drawdown. Rig up perforating unit, pressure test BOP's and lubricator to 3500 psi, okay. Shut-in well. RIH with gun 4/1, tied-in, opened well for drawdown, shot 11679' with 1 shot and 11653'-11673' with 6 shots (1/4 SPF). Shut-in well, POOH, all shots fired. Rig down and secure well. Ref. BHCS 9/2/83 ARCO Ai_ASKA.. INC~ P, O, BOX i ANCHORAGE, ALASKA 995i0 DATE · 7-.-°6-89 REFERENCE' ARCO CASED HOLE FINAL!: t-2.5 7-2(D-89 ACBL/VDL-GAidMA RUN ~, ¢-i~-u9 GR ~F'EC. TOOL RUN ~.~, 4-2~ .... ~ 89 "F ~-~.i- CJLL~R/F'ERF RUf~ i , 4' -~'~'~ ~, -~ '~ i -89 COLLAR/F'ERF RUi'4 i , 9-4 7-t 9-89 COLLAR/PERF R. UN i , i i-5 7-22-89 COLLAR/F'ERF RUN i , i 6-4 7-22-89 COLLAR/PERF RUN i 8-24 7-2¢-89 CBT RUN i 8-24 7-2¢-89 CET RUN i PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT- OF DATA. RECEIVED BY SALLY HOFFECKER ATO- t 529 CENTRAL FILE~ ~ PHILLIPS CHEVRON PB WELL FILES' D & M EXTENSION EXPLORATION $ BPX EXXON ~ ;¢ fA'I"E OF RLA3'KA MARATHON .~' I'EXAL;O MOBIL A'FL A;-:,' ~,'CH A i LA.':{ A i LA21' A'i"LA;~' A'Y'I_A,? A 'i" L A,~' '""CH ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 5, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re- DS 4-20 Permit No. 83-119 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SRB :nmh Attachment cc: T.B. Gray, BP Exploration J. Gruber- ATO 1478 W. D. Mosteller, ATO 1507 PI(DS4-20)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA .L AND GAS CONSERVATION C("---'AISSION APPLICATION FOR SUNDRY AP,-,ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-en~er suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Vadance Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 57' RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 1206' FSL, 195' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1783' FSL, 1753' FEL, Sec. 22, T11N, R15E, UM At effective depth 2104' FSL, 1858' FEL, Sec. 22, T11 N, R15E, UM At total depth 2134' FSL, 1869' FEL, Sec. 22, T11N, R15E, UM 8. Well number DS 4-20 9. Permit number 83-119 10. APl number 50 - 029-20996 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11890 feet Plugs(measured) 8834 feet Effective depth: measured 11843 feet true vertical 8798 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 385 sx 80' 80' Surface 2528' 13-3/8" 2335 sx 2528' 2528' Production 11306' 9-5/8" 800 sx 11306' 8396' Liner 848' 7" 358 sx 11040-11888' 8207-8833' . , , Perforation depth: measured 11704-11737' MD, 11704-11737' MD, 11686-11698' MD 3~L ~' ~'' 'i'~'~'''~' true vertical 8720-8741' TVD, 8693-8718', 8679-8688' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, 10988' MD, 4-1/2", 12.6#, L-80, 10988-11306' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993' MD, Camco BaI-O SSSV @ 2208' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation July 20, 1989 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereb~ certify that the foregoing is true and correct to the best of my knowledge. S i g n e d 2,~'Y/~ ,~~Z~-~'~'~~ Title 15. Status of well classification as: Gas Suspended Water Injector Operations Engineering Manager Date FOR COMMISSION H~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~-'"'~/ ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Commissioner IAppr°valN°' /~_ ~//// Approved Copy Returned Date '--/ ' /'7-~'~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 4-20i Description Summary of Proposal Current status: Proposed program: BOP equipment: Bottom-hole pressure: Fluid in hole: Injecting. Add perforations to the Sadlerochit as follows: Add Add 11653'-11673' MD (20') 11676'-11681' MD (5') Ref: BHCS 9/2/83 See attached sketch. All work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected working pressure. 3765 psi @ 8800' TVDss (estimated). Water. SRB 1. $000 PS1 ?" W[:LLH[.AZ) CONN[CTOR I~LANG[ 2. 5000 PS1 WIR[:LIN[ RAMS (VARIABL[ 3. 5000 PS1 4 1/6" LUBRICATOR 4. 50OO P$~ 4 ~/S" fLOw TuB[ PACK-orr 2 A I:;: C 0 A I... A,S' i< A, .[ N C., I::'., O, BOX ~ ~D (.) '5 6. (:,~ ANCHOI:;~AGE, A I.. A.".~,' K A / .3 F(lii:F'ERIFNC'.E' ARCO CASED HOLE F:INAL,.$' i-J9 :3-7 4-3' 4-t 5: 4'-2~ 5'-t 2 i 2-5 t t6-'? t8-25 4- t 4-89 6-. t t -.89 6-2-89 6-..S'-.89 4 '- 2 ':3 - 89 6-4-89 6-t4--89 6-S-89 6-S-89 6-4-89 6- t ?--89 4-28-89 5-Si -89 C [J L I... A R / I::' IE R F' I:< U N 1 , '.5" INJEC'f'ION PROFILE RUN i , 5" PER F R E C O R D R I.J N I , 5" COI..I..fiR/PI~RF RUN;~ t -3, COI...L. AI:(/F'ERF RUN t , '5" ZNJECTION PROFZLE RU~ t, '.5" PITS RUN i, 5" COLL. AR/PERF RUN t , :~" GAS I..IFT SURVEY RLJN t , 5" COI_I_AR/PERF F:UN t, 5" INJECTION PROFILE RUN t, '5" INJECi"ION PROFILE RUN t, 5" LEAK DETECTION RUN i, t" . . COLI..~R/F'ERF RUN ~, 5" COL. LAF~/F'EF~F RUN t, 5" F'Z'['S RUN ~ , 5" F'I_E:ASE SIGN AND REI'URN THE AI'TACFIED COPY AS RECEIF'T (iF DA'rA, '5" I.tL.$ CA~.ICO $[)1'-I HI...$ A 'r I.. A .'.'; U: A M C 0 C A t'i C 0 I"1L. S A/i_AS C A i"i C 0 CAMCO A ILAS' I.-IL.,~' CAI,iCO I:;:EL;E.[ ¥1LD BY HAVE A NICE DAY'! S AI...LY I"IC]F:FECKER A'rO-t 529 UN 2 8 ]989 "f'RANS ~- 8726S Alaska 0il & Gas Cons. CommissM1 Anchorage DISI'RIBUI'ION CENTRAL FILES ¢ F:'HILL:[F'S - CHEVRON F'B WELL F'II..E,S' DAM R A'D EXTENSION EXF'LORATION ~ BPX EXXON '~ STAI'E OF ALASKA MARATHON - ..-'"' TEXACO MOBIL [.~1:,, C u AI...A~K A, I::' .. O, B (']).: i (}') (-)'.36 (.', ANCI-.tOI:~,'AC~F2, AI...A.~'KA D A 'l' E · 5 -. 26 - 89 I:;,' Iii: I::' E R Ii': N C Ii:': A R C 0 C A,~ E D H 0 I.. E I-- I N A I... 5' t -.2~i 5:-6-89 F'I::.'.OD, PI:;,'OF. IL. lii:/I. EAK DETEC1 ].ON I:;,'UN i , 2-t I 5-4-89 1FI.:-."MF'/I.-"'I..UIi) DEN,~ITY I'.,'UN t , '2-'2'~ 5-"2()-89 COI...LAF;~/F:'E:I:;~I:: I:,,'UN t , :3'"'9 5-t 8'-89 CNL-GAMHA RUN t , "~-9 5 .... i8-89 DIFF I'EHF' RUN i, :3--tG 5-:~....82 INJECTION F'RUFILE RUN i, S .... i''~ 5-3-89 INJE.,I'ION I'-"ROF'II..E/TE. HP RUN i 4-2 5-2~-89 CNI...-C,~HIt~ RUN t, 4-"5' S .... i ?-'-87 CNL.--GAHHA IkUN t, 4- ? 5-t 9-89 CNL--bAMHA IN,'(JN t., 4- t 5: .5- S -89 I N J E C l' I 0 N P R 0 F' ]: L F F,--: L,I N i , ,1 2~ 4--i-89 I .... '/"' .... '" , - ~OI..LAR, I-ERF RUN t 4--26 5;--t 8-.89 CNL-GANHA R. UN t , 5--'3 S"-'29--89 COI_LAR/F'ERI:-" RUN I , ~-'t ? 3-29-89 COL. i_AR/PERF RUN t , '?-~(-.) 5-t '7--89 DUAL BUR3"F T'D'F-P R~JN ~ , 7-::$(') .5-i '?-89 CNL RUN t , 9-'-28 :3-3~-89 COLI_AR TO SET PATCH RUN t, t i "-t ('-) 5--i ,?)-8':? i_EAK DEI'ECI"ION RL.IN i, ~t-26 5-5-89 INJECTION I:'ROFILE/'I'EilF' RUN t, t8-~ 5-8-89 FLUID DEN,S'ITY/I'EMF' RUN i, ....... t8-'9 '-- F..- , .~..-.~ 89 FLUID DENSiTY/TEHP RUN t t !.3..-2:$ S-26-.89 COI. LAR/F'ERF RUN i, PLEASE 3'II:;,N AND RETUF;:N THE ATTACHED COFIy AS RECEIF:"F OF:' DATA, I!>" 5:" 5" [.>. 5" .5" .".'7" 5" .5 ' 5" 5 · .5" 5" 5 · ,,,, 5" 2" 5" ."7" 5" C A bi C 0 C A i'i C 0 A TI...A:;' AI'I...AS' · A'IF L A 5' C A ~'l C 0 A FLA;g' A i" I... A :';' [:l~ ij I.. A ;~' C A M L; 0 HL.S A 'I'L.~,S' HL.&' fiLS $'CI.t SCH HL2 CAMCO CAMCO C A H C 0 C A H C 0 I-I L. ~2 RECE]:VED BY .... HAVE A NICE DAY! ,S'ALI... Y I-lC}F: F'I:-~ C K EI:~: ATO-i 529 Anchorage DISTRIBUTION · ,-'" CENTRAL FILES ¢ F'HILI...I:F'S ~ CI"IEVI~ON ' F:'B WEL. I_ F']:L..E.,S' D & M R & D · ,."" EXI'EN,.?iON EXF:'LORAT'ION .,.""BF'X · "' I.:-XXON '"' · ,- .,- ,.?I'A"I'F. OF AL_AS'I<A HARAI'ftON ~ l EXACO ~' MOBIl_ ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager APril 21, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-20 DS 4-20 Dear Mr. Chatterton: Approval No: 9-223 Permit No: 83-119 Enclosed is the Report of Sundry Well Operations detailing work completed on the above- mentioned well. Very truly yours, D. F. Scheve DFS/WDM:sd Enclosures cc: BP Exploration J. Gruber - ATO 1478 PI(DS 4-20)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate __ Pull tubing __ Alter Casing Plugging __ Repair well ~ Perforate Other x 2. Name of Operator ARCO Alaska, INC. 3. Address P.O. Box 100360, Anchorage, AK . 99510 Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 1206'FSL, 1753'FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1783'FSL, 1753'FEL, Sec. 22, T11N, R15E, UM At effective depth 2104'FSL, 1858'FEL, Sec. 22, T11N, R15E, UM At total depth 2134'FSL, 1869'FEL, Sec. 22, T11N, R15E, UM 6. Datum elevation (DF or KB) 57' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well n~,ml~-,r DS 4-20 9. Aporoval Numbers 9-223 10. APl number 50-029-20996 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary: Total depth: measured 11890 feet Plugs (measured) true vertical 8834 feet Effective depth: measured 1 1843 feet Junk (measured) true vertical ~698 feet Casing Length Size Cemented Conductor 80' 2 0' 385 sx Surface 2528' 1 3-3/8" 2335 sx Production 1 1 306' 9-5/8" 800 sx Measured depth 80' 2528' 1 1 3O6' True vertical depth 80' 2528' 8396' Liner 848' 7" 358 sx 1 1040-1 1888' 8207-8833' Perforation depth: measured 11740-11768', 11704-11737', 11686-11698' true vertical 8720-8741', 8693-8718', 8679-8688' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 & 4-1/2", 12.6#, L-80, 11306'MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993'MD, Camco BAL-O SSSV @ 2208'MD REE'EiVED 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure APR aska 0il .& Gas Cons. Cc, mrnissJ0n ' , ch0rage 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 17. I hereb~/,~ertify that the foregoing is true and correct to the best of my knowledge. Signed '¢:~d~~ Title Oper. Engr. Manager Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Summary of .P. erforat, ing Operations DS 4-20 Began perforating operations on 1 April 1989. Backflowed well with artificial lift gas to achieve drawdown. Rig up perforating unit, pressure test BOP's and lubricator to 3500 psi, okay. Shut-in well. RIH with gun gl, tied-in, opened well for drawdown, shot 11717'-11737' with 80 shots (4 SPF). Shut-in well, POOH, all shots fired. RIH with gun #2, tied-in, opened well for drawdown, shot 11710'-11717' with 28 shots (4 SPF) and also shot at 11704' and 11706' with 1 shot each. Shut-in well, POOH, all shots fired. RIH with gun #3, tied-in, opened well for drawdown, shot 11686'-11698' with 1 shot at 11686', 11695' and 11698'. Shut-in well, POOH, all shots fired. Rig down and secure well. Ref. BHCS 9/2/83 APR 2 ~'.' l ~lasha .0il b Gas Cons. cc~mi~i0r~ ,, ~chorage ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 22 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-20 Permit No.: 83-119 Dear Mr. Chatterton: Attached is the Application for Sundry Approvals detailing work to be performed on the above-reference well. Very n'uly yours, D. F. Scheve DFSI/WDM:sd Attachment BP Exploration J. Gruber- ATO 1478 P 1 (DS 4-20)W 13 RECEIVED MAR 2 7' ~9~© Alaska .Oil & Gas Cons. C0mmissia'~ ' "" ;Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompanY AR3B--6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program __Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate x Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. BOX 100360 Anch, AK 99510 . Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1206'FSL, 195'FWL, Sec. 26, T11N, R15E, UM At top ct proc~uctwe ~nterval 1783'FSL, 1753'FEL, Sec. 22, T11 N, R15E, UM Az enec[Ive aep[n 2104'FSL, 1858'FEL, Sec. 22, T11 N, R15E, UM A[ zo[a~ oepzn 2134'FSL, 1869'FEL, Sec. 22, T11N, R15E, UM 12. Present well condition summary: 6. Datum elevation (DF or KB) [;7' RKB Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-2O 9. Permit number 83-119 10. APl number 50-029-20996 11. Field/Pool Prudhoe Bay Oil Pool. Total depth: measured 1 1890 feet Plugs (meaf ~red) true vertical 8834 feet Effective depth: measured 1 1843 feet Junk (measured) true vertical 8798 feet Casing Length Size Cemented Measured depth Conductor 80' 20" 385 sx 80' S u rface 2528' 13-3/8" 2335 sx 2528' P rod uctio n 11306' 9-5/8" 800 sx 11306' Liner 848' 7" 358sx R E C'~VSL~) feet True vertical depth 80' 2528' 8396' 8207-8833' Perforation depth: measured 11740-11768'MD ,~,;..', ... true vertical 8720-8741q-VD .~laSJ~3,_0jJ.& Gas Cons, C0mmissio~[ Tubing (size, grade, and measured depth) 5-1~", 17~, L-80 & 4-1/2", 1~~ 11306'MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993'MD, Camco Bal-0 SSSV @ 2208'MD 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation March 24. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as' Oil '_._~' Gas__ Suspended__ Service _Water Injector 17. I hereby certify t.b,at the foregoing is true and correct to the best of my knowledge. Signed-m. ----~- -,,~--~ '~''-'~'~'~//~'~ Title Operations Engr. Manager Date ~/~ ~/~:~' ~' FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commissioner Form 10-403 Rev 06/15/88 IApproval ~.,N o. Location clearance . o, jec~ Subsequent form required 10- ~-~' ORIGINAL SIGNED B~ [0NNIE C. SMITH Commissione~ Date SUBMIT IN TRIPLICATE ARCO Alaska, Inc. proposes to perforate DS 4-20 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. The well is currently shut-in. Diesel and 9.8#/gal NaC1 will be in the well during perforating operations. These perforations are in the Lower Romeo. The expected reservoir pressure is approximately 3600 psi. Ref: BHCS 9/2/83 Proposed Perforation Intervals: 11684'- 11699'MD 11704'-11737'MD RECEIVED 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 WIR£LIN[ RAMS (VARIABL£ SIZE) 3. 5000 PSI 4 1/6" L UBR~CA'[OR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H]REL INE BOP EOU ! PME NT ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 9, 1989 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-20 Permit Number: 83-119 Enclosed is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/BLS:sd Enclosures cc: Standard Alaska Production Company JoAnn Graber, ATO 1478 File PI(DS4-20)W1-3 ~1-1, i'-... ], .t ~-~J' Aiaaka 0il .& 6as Cons. C0mmi~i0~'~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Operation shutdown Alter casing Repair well Plugging Change approved program __Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. BOX 100360 Anch, AK 99510 . 12. . Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 1206'FSL, 195'FWL, Sec. 26, T11N, R15E, UM At top ot productive ~nterval 1783'FSL, 1753'FEL, Sec. 22, T11 N, R15E, UM A[ enecuve oepm 2104'FSL, 1858'FEL, Sec. 22, T11N, R15E, UM Au ~om~ aep~n ~2134'FSL, 1869'FEL, Sec. 22, T11N, R15E, UM Present well condition summary: Total depth: measured 1 1 890 feet Plugs (meaf ~red) true vertical 8834 feet Effective depth: measured 1 1843 feet Junk (measured) true vertical 8798 feet Casing Length Size Cemented Conductor 80' 20" 385 sx S u rface 2528' 13-3/8" 2335 sx Production 11306' 9-5/8" 800 sx Liner 848' 7" 358 sx 6. Datum elevation (DF or KB) 57' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-20 9. Permit number 83-119 10. APl number 50-029-20996 11. Field/Pool Prudhoe Bay Oil Pool. feet Measured depth True vertical depth 80' 8O' 2528' 2528' 113O6' 8396' 11040-11888' 8207-8833' ' Perforation depth' measured 11740-11768'MD true vertical 8720-8741'TVD Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 & 4-1/2", 12.6~, L-80, 1 l~i~)O Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993'MD, Camco Bal-0 SSSV 13. Attachments' Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation January 12.,1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,~..~//.o,/~2X~_~,Cf~'~- Title Operations Engr. Manager Date FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness IApproval No. Plug integrity BOP ,Test Location clearance Mechanical Integrity Test ..,~' Subsequent form required 10- ORIGINAl. SIGNED BY Approved by order of the Commissioner LO.~.~JIF. C ,SMITH Form 10-403 Rev 06/15/88 Commissioner Date I--//- Approved Copy Returned £-i SUBMIT IN TRIPLICATE ARCO Alaska, Inc. proposes to convert DS 4-20 from production to injection as part of the Flow Station 2 Waterflood Project of the Prudhoe Bay Unit. Water injection for secondary recovery and pressure maintenance purposes will be via existing perforations within the Sadlerochit Sand. '~laska_Oii & Gas Cons, ARCO AI...A~KA, !N£, F'.,O, RO'X t~S6G ANCHORAGE, AI_ASKA DATE' ~-~-~ REFERENCE' ARCO CASED HOLE FINAl.., 3--5 9-27-RR 3-8 tt-?-87 S-iS tt-2-g7 ~ ~ O-~ 9-R7 6-S 9-?8-87 6-8 !0-4-87 6-t7 9-~-87 6-22 40-1-87 9-5 9-34 - COI..[..AR/F'ERFORATTON ' CRLI..AR/PERFORATTON COI..I...AR/F'ERFORATION COI_.I...A~/P~RFORATION COI..I..AR/F'ERFORATION COI._L. AR/PERFORATION COl..[..AR/PErFORATION COI_LAR/F'ERFORAT~ON COL..I...AR/PERFOR~TIOW CO[.[..~R./PERFRR&TION -t0-8-87 COl.. L._AE~ / F'EF,'.FO ~'AT I ON RUN 'i 0-24-87 ~J].P.I.'.~./PEF.'FOR'?,~T,,.TI]N ~ R'I.IN ~, 5" F'I_F.:ASE SIGN AND R't T~~~Iq.~I~'TA~~A,.~"~~F"r OF DATA,. HAV..E A N IC~ D~,Y' F'E Gl.'.., Y BENNETT ~ T 0 :- t .... ._ 9 ,::.-:- TRAN,~ SR,O.,i AR /~ APPFe. OVED ~) .... --= D !,.~TR.T. BI. IT T RN ATI ATI... A.q ATI .A?, ATI. ATI.. AS ATI.. AS: A'TI A?, ATI... A.~' ATI A'¥1_.A.? A TI...A..e· ATI_.A.t A'TI..A.~ ATI. A.~' CENTRAL.. FII...ES CHEVRON D&M EXTEN,.~I ON EXF'L.ORATION EXXON MARATHON MOBIl_ F'H I I...t... I F',.~ PR WELl... FT.I. K' & .O · ,,.""' ' STATE OF AI...A,.gKA ~'~ TEXACO STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM,,~SION 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,j~ Perforate ~ Other 2. N~) of. ~Perator AlasKa, Inc. 3. Address P. 0. Box 100360, Anchoracje, AK 99510 4. Location of well at surface 1206'FSL, 195'FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1783'FSL, 1753'FEL, Sec. 22, T!IN, R15E, UH At effective depth 2104'FSL, 1858'FEL, Sec. 22, T11N, RI_5E, UM At total depth 2134'FSL, 1869'FEL, Sec. 22, T11N, R15E~ UM 11. Present well condition summary Total depth: measured 11890 feet true vertical 8834 feet Plugs (measured) 5. Datum elevation (DF or KB) 57' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-20 8. Permit number 83-119 9. APl number 5o-- 029-20996 feet 10. Pool Prudhoe Bay 0il P0ol True Vertical depth 80' 2528' Effective depth: measured 11843 feet Junk (measured) true vertical 8798 feet Casing Length Size Cemented Measured depth Conductor 80' 20" 385 sx 80' Surface 2528' 13-3/8" 2335 sx 2528' Production 11306' 9-5/8" 800 sx 11306' 8396' Liner 848' 7" 358 sx 11040-11888' 8207-8833' 11740'-11768'MD Perforation depth: measured 8720'-8741'TVD true vertical Tubing fsize, grade and measured depth) ~ , 17#, L-80 & 4½", 12.6#, L-80, 11306'MD '"~""; ~ ]' .'..:lo:., Packers and SSSV (type and measured depth) '..~.~,,~,.-~ .. ..... I .... (iii & ~i:;as Cons. Co~iid~SSi0~ Baker FHL Packer @ 10993'MD~ CAMCO Bal-O SSSV @ 2208'MD Anchorage 12.Attachments Description summary of proposal ~' Detailed operations program [] BOP sketch E3 13. Estimated date for commencing operation N/A Date approved 14. If proposal was verbally approved Name of approver 15. I hereby,~ertify that the_foregoing is true and correct to the best of my knowledge Signed ~//~~,~~__,~~ ' Title 0per at ions En g ineerincj Manager Date /~¢/~'~' Commission Use Only Conditions of approval Notify commission so representative may witness [ Approval No. [] Plug integrity [] BOA~pTr~)~ed[~C~3~fation clearanceI Returned ORIGINAL SIGNED BY .. _/-'~ ~, ..'-~ Approved by LONNIE C. SMITH Commissioner by order of ~)~~ the commission Date / ~_x~_,. -' ~ Form 10-403 Rev 12-1-85 Submit in triplicate ALASKA OIL AND GAS CONSERVATION COMMISSION Telecopy No. (907) .276-7542 January 25, 1988 ADMINISTRATIVE APPROVAL NO. 213.12 Re: Waiver to Rule 11 of Conservation Order No. 165 D F S cheve Operations Engineering Manager ARCO Alaska, Inc P 0 Box 100360 Anchorage, AK 99510-0360 Dear Mr Scheve.. By correspondence dated January 1, 1988, productivity profile requirements on Prudhoe Bay Unit wells DS'4-20, DS 4-23, and DS 4-29 were requested to be waived. The profile survey is required by Rule lla of Conservation Order No. 165. Ail of the wells are single zone completions which precludes/the need for a productivity profile. Therefore, the Commission hereby approves your request to waive the production profile required by Rule lla of Conservation Order No. 165 in Prudhoe Bay Unit wells DS 4-20, DS 4-23, and DS 4-29. Should additional zones be brought on production in conjunction with the original interval, a subsequent profile survey will be required. Sincerely, ,. Commissioner BY ORDER OF THE COMMISSION jo/3.AA213 In accordance with Conservation Order No. 213, ARCO Alaska, Inc. requests the fol 1 owing' Permission to waive the production profile prescribed in Conservation Order 165, Rule 11a. Only 28' of perforations were shot in 4-20. All of the perforations were shot in Zone lA thereby eliminating the need for a spinner survey. Addi- tional perforations in Zone I are planned. However, the timing of the perfor- ations is after the initial six month time period has passed. A production profile will be run subsequent to the additional Zone I perforations. ..... ...,. ~:'ifi 7, [i:~.s ..Sons. 'J ..... STAT17'SN 4-20 DATE- t 2_?_8]/ REFERENCE]' ARCO PRE,?.-:SIJRE DATA 4-'2~) t t -"t 6-'87 BHP REPOF;:.T PLEA,?E ,~'I~N A.Ni) R['?.TI.!RN THE ATTACHEI) COPY AZ: RECEIPT OF DATA.. RECE I Vi":]I) BY HAVI.:." A NICi5' D~ ' DIYTR!BUT!ON CEN TRA1... 1::' .t; I_E..? CF1EVR[iN T.', ~ H E X T F: i"-,~,? _T. 0 N E X F'I... 01:;: A T t l.-.l N '"- FXWON M A F: A T H !'] i'--...~ '"' ~'-,- F'F! T I...1_ I F',S' ... F'._T-: WEI.. !.. FII. I!.'.,".-:' '"' R & ¥:, · '~ ,S' A F' n .,.' STATE nF' .... AI...A.?I(A '"' TE-XAF:FI ~e.s~ 0ti & Gas Cons. Anchorage · ---?. ' STATE OF ALASKA ALASKA-.,~-IL AND GAS CONSERVATION L,,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL J~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-119 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20996 4. Location of well at surface 9. Unit or Lease Name 1206'FSL, 195'FWL, Sec. 26, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1783'FSL, 1753'FEL, Sec. 22, TllN, R15E, UM 4-20 At Total Depth 11. Field and Pool 2134'FSL, 1869'FEL, Sec. 22, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 57' RKB 17' GLI ADL 28322 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/13/83 09/01/83 10/04/83J N/A feet MSL 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD} 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost l1890'MD, 8834'TVD 11843'MD~ 8798'TVD YES~ NO []I Nipple @ 220~eetMD 1850' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf. 80' 30" 3R5 .~×.~ Arnold' 13-3/8" 72.0# L-80 Surf. 2528' 17~" 1935 sxs Fondu + Z~O0 .~ .q PV "C" 9-5/8" 47.0~ L-80 Surf. 11306' 12~" 500 .~×.~ Cl~.~g ('. + 3clo .,~.q PF "C" 7" ..... 29~0¥A L-80 ' 11040' 11888' 8~." 358 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPIH SE/ (MD) PACKER SET (MD) 5k 11¢)77' ln993' - 11740'-11768'MI) @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8720'-8741'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. (Well shut-in and freeze protected) PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR Gl L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ __ __ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. -- 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R CEI tD ~ nr'hOfD, q(~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~' GEOLOGI~ MARKERS' "* ..'', ..... MATION TESTS ... ' ~ ' ,~' : : :~:' ' · ' '.': ' - . .. -.-'. ' .'~ ?5 :'- ,. ~ . : -; ·: - ~.,.~: . - ~-'1:. -, - i . . - , . : ': . ¢.. '~ '" : ' "NAME 'Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 11332' 8425 ' O/W Contact Not Reached None Base Sadlerochit 11769' 8742 ' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my k~owledge. : Signed -~ . __ Title Opr. Engr. Mgr. ~Date ~'_____ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, In/~'' Prudhoe Box Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 18, 1 987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-20 Approval Number: 89 DS 4-20 Permit No. 83-119 Previously classified "Suspended" well DS 4-20 has been perforated. Enclosed are the Well Completion Report and Report of Sundry Well Operations detailing the work. The well has been temporarily shut-in and freeze protected pending Facility tie-in work. Facility tie-in is expected in January 1988. Very truly yours, D. F. Scheve DFS/MJK/sd Enclosures cc: Standard Alaska Production Company J. Gruber, ATO 1478 File: P1(DS4-20)W1-3 RECEIVED Oil .~,_.. ~as C..ns. Co,~:,r,~s~' ..... ., ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~----. STATE OF ALASKA ~-- ALA~_ A OIL AND GAS CONSERVATION COk. ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Na~(~f ~.per[ttor AlasKa, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1206'FSL, 1753'FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1783'FSL, 1753'FEL, Sec. 22, TllN, R15E, UM At effective depth 2104'FSL, 1858'FEL, Sec. 22, T11N, R15E, UN At total depth 2134'FSL, 1869'FEL, Sec. 22, TllN~ R15E, UN 11. Present well condition summary Total depth: measured true vertical 11890 feet 8834 feet Plugs (measured) 5. Datum elevation (DF or KB) 57' RKB Feet 6. Unit or Property name Prudhoe Bay Unit, 7. Well number 4-20 8. Approval number 89 9. APl number 50-- 029-20996 10. Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical Casing 11843 8798 Length Size 80' 20" 2528' 13-3/8" feet feet Junk (measured) Cemented Measured depth ~ue Vertical depth 385 SX 80' 80' 2335 SX 2528' 2528' 11306' 9-5/8" 848' 7" 800 sx 358 sx Perforation depth: measured 11740'-11768' true vertical 8720'-8741' T.~.bi. og (size, grade and measured depth) ~", 17#, L-80 & 4½", 12.6#, L-80, 11306'MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 10993'MD, CAHC0 Bal-0 SSSV @ 2208'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 11306' 8396' 11040-11888' 8207-8833' 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] l§. l hereby certify that the foregoing is true and correct to the best of my knowledge ~. ,_~-, Signed Form 10-404 Rev. 12-1-85 Title Operations Engineering Manager Date /~ Vc~,2 Submit in Duplicate ~ Summary of Operations - DS 4-20 Began perforating operations on 19 October 1987. RU perforating unit, pressure tested equipment. RIH w/gun #1, shot interval 11748'-11768'MD (4 SPF), attempted to flow well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #2 shot interval 11740'-11758'MD (4 SPF), attempted to flow well to clean-up. Shut-in well, POOH, all shots fired. Secured well, RD. Obtained SBHPS 24+ hours later, freezed protected well, and SI. ' P., o ,/:.bo x .;i.t o~o' - · · . Anchor~a~J~-. ~lask* '99.~t0 ' . DATE- September ti~ t987 REFERENCE' ARCO Magnetic 'F~pe~: w/! ~si-in9 =-~ ~e::- o-~--°T Mag+ape ~T24:38 CH CNL =~-~:~_... , : ._,, ,, . _ PLease sig~ and re~, ~ e co, y as' ~- ~ . HAVE A NICE DA_ TRAN~ ~87464 Approved P ! .S T'RI BUT[ ON Run t 'rec:eip~ of da+.a, .~ch Ceni:raL l::i Chevron D &fi F'~ M,'= Ph ee'l: er ?.--. Fx xon M a r a '1- h o n Piobi L '"' .F:' hi t L io .-.'-i.- F'B Wel. I. ~::'i !.e_~: i:;: &- D '"' S AF'f.".: 'It' · ~.:~ - ,...-.~ .. .~.:': .-. ;'_-, +_.a.:~::e~ o ~ A...t_ a s' !,..'. ,=~ .... I f.:, '::' ..::) C 0 ARCO;-~A [a-~ka/~:: Inc ~ P.O~:'i Box - t OGS6G AnChOrage, A[a.ska DATE' Yeptembel" ti, t'987 'REFERENCE' : ARCO Ca~ed HoLe F'i'r.,al. '~'?~ 9-P-P, 7 : ",' -- CF! CNL PWDW 2--~ o_, ..~.,~._.o-,,c., Wa-i-e~- '[njec'l'io?., Pro'?i ~e F' Re,."_' e i v-.ed By_~~__~ ...................... commission G~ ..... ~chomge o f T R A N ;,_7 ~i~74d~6 A~ p 'r ovecl ............... r; 'r '-."'¥' :.-., 'r B--".J T I i"iN %; .t. ,..:'- .: I '-..~ .-. ; d a t: a ~ STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMM,,.,.,ION 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 Lq 2. Name of Operator 5. Datum elevation (DF or KB) 3. Address Post Office Box 100360, Anchorage~ AK 99510 4. Location of well at surface 1206' FSL, 195' FWL, Sec. 26, TllN, R15E, UM At top of productive interval 1783' FSL, 1753' FEL, Sec. 22, TllN, R15E, UM At effective depth 2104' FSL, 1858' FEL, Sec. 22, TllN, R15E, UM At total depth 2134' FSL~ 1869' FEL~ Sec. 22~ TllN~ R15E, IM 11. Present well condition summary Total depth: measured 11890 true vertical 8834 Effective depth: measured 11843 true vertical 8798 feet feet feet feet Plugs (measured) 57' RKB feet Junk (measured) Casing Length Size Cemented Structural Conductor 80' 20" 385 SX Surface 2528' 13-3/8" 2335 SX Intermediate Production 11306' 9-5/8" 800 SX Liner 848' 7" 358 SX Perforation depth: measured NONE 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-2O 8. Permit number 8~-119 9. APl number 50-- O29-2flqq~ 10. Pool Prudhoe Bay Oil Pool true vertical Tubing (size, grade and measured depth) 5~' 17# L-80 & 4~' 12.6# L-80, l1306'MD Packers and SSSV (type and measured depth) Measured depth True Vertical depth 80' 80' 2528' 2528' 11306' 8396' 11040'-11888' 8207'-8833' Baker FHL Packer fa 10993'MD: ~f) Ba]-O gg,qV fa ~?O8'ND 12.Attachments Description summary of proposa'l Jgl Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify th/~ t?~ foregoing is true and correct to the best of my knowledge Signed ~~¢~//Z~_~.~~ Title Operations Engineering Manager Commission Use Only Conditions of approval Approved by Date ~_//Z./~"~ Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance by order of .............................. O6~missioner the commission Dat~ ¢/~ "-~?~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 4-20 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref: BHCS 9/2/83 Proposed Perforation Intervals: 11684'-11699'MD 11704'-11737'MD 11740'-11768'MD ARCO ALas'km, loc F'.O. Box Anchorage, ALaska DATE: £eptember t2, t984 REFERENCE[: ARCO Cas'ed HoLe Fina 4-7~'~/'""?-26-84 4-'2":' -- -:, 6-6 f 8'-4-84 9-~0~''~ .-S--26--84 t 4-t 0 '/ 8-,'3-84 t4 t6 ~ 0--84 t4 24 5-~7-84 i 6-~" ~ 7.-~. ?/S0-84 Temperature Log Tempera t ure Log CH CML Temperature L. og FLuid Den.s'i'iy I)DT/NLL/GR Spinner Log Injection Profi Le Log Run t Run 1 Run t Run 7 Run t Run 2 Run t Fi:un I n 5" 5" 5" 15 ' 5" 5" 5" C a rfl c: o C', a m c: o I.;.O C a m c: o DA DA C a fll C. 0 C a m c o and return the attached copy a~'~ receip'~ TRAN$~ ~S22 o f d a i' a. I)ISTRIBUTION Ch err on ExpLoration' Service~ Extension ExpLoration Ex xon Getty Marati'lon Mob i L Mot) iL E & F:' Phi tLips F'rudhoe Bay WeLL Sohio State of Alas'ka Fri Les; ~ ARCO ALASKA, INC. Extension Exploration TRANSMITTAL )- C. V. Chatterton - AOGC From- Lucille Johnston - Ext. Ex.ploratio: ~te- May 14~ 1984 Transmitted herewith are the following' One Copy Each ARCO' W.S. Pilot #13::J 6-17-83 Registered Survey Plat ~/W. Sak #24 ~ W. Sak #24 S~. Bay St#1 Lis Tape #65031. 4-12-82 Run 1,2 Open Hole " " #4230 4-5-82 Run 2 HDT. \ ~'-. ~ ~ ,~ ~ / ~, ~-:~ ~.~'-i'~.. , ~_..~ ~~_: z~W ~ -. _, , ~PT ~ ~,~ ~s ?~e ~69~2~ ~2-~8-83 Run D.S, 4-20 Lis Tape #68524 9-2-83 Runs 1,2 Open Hole Listing Registered Survey Plat 5-9-82 MUDLOG 6-8,23-82 Note'/ On this well, please contact Teresa Gorup ~__of Paleo Lab, Bayview regarding well Sample~ :¢knowledgment: Date: . ,,-__ /.~ ~ ~_.,,_-~ :4 v',A'~ .L i.u~.',i. ',eturn Receipt t RCO Alaska, Ina. ~/ Extension Exploration Aia's~a 0il a', r2.~:; Cc:~s. Ccmmissi0n P.O. Box 100360 Processed By'-. Lucille'?Johnston .. Anchorage, Ak. 99510 ATO-1015 x4599 A T"T'N - Bill Sheffield Governor ALASKA DATE: TO: RE: OIL AND GAS CO#SENVATIOH CO,~fAflSSlON Lo'c. Permit No. 3001 PORCUPINE DRIVE ANCHORAG E, ALASI<,A 99501';-3192 TEL EPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on_the subject well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please 'submit the above missing material. Sincerely, C, V. Chatterton Chairman RECEIVED MAY 1 419 4 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office ~:~", 360 .::;choraoe. , _ska 9¢510 To,et. none 907 2-77 5~37 December 19, 1983 Reference' Arco Directional Data D.S. 3-25'~; 12-6-83 D.S. 4-20" 8-17-83 D.S. 14-27 '~/ 12-12-83 D.S. 14-34~"' 10-26-83 D.S. 14-35*'~ 11-2-83 Single Shot Magnetic Survey Single Shot/GO MWD Single Shot Single Shot/GO MWD EW Teleco EW EW EW sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. # 674 Chevron D &M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North C~olo97 Carc//ne £x,/-_'.!" ';~ .-., ' ' ': "'" ''':'''~: ; {.'~ : - , Sohio ~ -,-,, -'"~'~" State of Alaska Post Office B~360 . Telephor~e 90'~"'~77 5637 - November 30, 1983 Reference: Arco Open Hole Finals 9-4-83 CPL/Cyberlook 9-2-83 BHCS 8-28/9-2-83. DIL/SFL 9-4-83 LDT / CNL/GR (Raw) 9.-4-83 LDT/CNL/GR (Poro) 9-2-83 Intermediate CH GR Run 2 5" Sch Run 2 2" & 5" Run 1/2. 2" & 5" Run 2 5" R-un 2 5" Run 2 5" Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 633 ~.Chevron f iD;; & M f'.Dallas Drilling Get=y 'Marathon Mobil' DISTRIBUTION fphillips Prudhoe Bay Sohio ~,~S~ate~:.qf_.:.:~Ala..s.ka Alaska 0i~ & Gas Cor~s. Commission Anchorage ---- STATE OF ALASKA ~-- % ALASK/; .-IL AND GAS CONSERVATION (: ¢IMISSION ~: WELL COMPL_ETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~I GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-119 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20996 4. Location of well at surface 9. Unit or Lease Name 1206' FSL, 195' FWL, Sec.26, TllN, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1783' FSL, 1753' FEL, Sec.22, TllN, R15E, UM 4-20 At Total Depth 11. Field and Pool 2134' FSL, 1869' FEL, Sec.22, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 57' RKB, 17' GLI 28322 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. N°.°fC°mplet[°ns 08/13/83 09/01/83 10/04/83I IN/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TYD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11,890'MD, 8834'TVD 11,843'MD,8798'TVD YES iX] NO [] INipple @ 2208 feetMD[ 1850' (APPROX) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED --2'0~--~ 91.5# H-40 Surf 80' 30" Cmtd w/385 sxs Arctic Set 13-3/8" 72.0# L-80 Surf 2528' 17-1/2" Cmtd w/1935 sxs Fondu + ~00 sxs PF "C" 9-5/8" 47.0# L-80 Surf 11306' 12-1/4" Cmtd w/500 sxs Class "G" + 300 sxs PF "C" 7" 29°0# L-80 11040' 11888' 8-1/2" Cmtd w/358 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 11072 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I . · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASoMCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~' Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE · ~ . · , Submit in duplicate Form 10-407 Rev. 7-1-80 I~I~N/Wf'?q CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit O/W Contact Base Sadlerochi t GEOLOGIC MARKERS MEAS. DEPTH 11332' NOT REACI 11769' TRUE VERT. DEPTH 8415' --D 8742' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attaChments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from groUnd level'(GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". DS 4-20 Drilling History NU 20" hydril and diverter system. Spudded well @ 0500 hrs, 08/13/83. Drlg 17-1/2" hole to 2535' Ran 62 jts 13-3/8" 72#/ft, w/FS @ 2528'. Cmtd 13-3/8" csg w/2335 sxs ~otal - 1935 Fondu + 400 sxs PF "C". ND 20" hydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 11,333'. Ran 248 jts 9-5/8" 47#, w/FS @ 11, 306'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld .8-1/2" hole to 11,890' (09/01/83). Ran DIL/BHCS/GR/SP f/11,871' - 11,298'. Ran LDT/CNL/GR/CALIP f/11,830' - 11,298'. Stuck logging tool. Recovered on 09/03/83. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs PF "C" + 125 bbl AP. Ran 21 jts 7" 29#/ft, f/11,888' - 11,040' Cmtd 7" lnr w/358 sxs "G" cmt. Drld cmt to 11,843'. PBTD. Tstd lnr l'ap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/11,820' - 10,900' Ran 5-1/2" completion assy w/tail @ 11,072' & pkr @ 10,993' + SSSV @ 2208". Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs, 09/08/83. DRN/DH31 09/27/83 ,l I:.i..'~.:'~!' I1_l::2; OF: C:IJF;~VATI_IRE P'IE]'HCIEI M E A'?: I.. R E !'il D F'< I I'::' T D Ii:_: F::' T I'"1 A r,,I G !_ E I:::' E I::ii"F I] Pl 'l' F."(U E] !}R I I:::.'T C("~I_II::;,'SI::.i VE::RT I r'i:AL. VEI::;:T I (":AL. D I I:? E:' C: ]* I 0 N I._ Ii:"' lxl G'I" H D F P'T H :::: E: C"F I 0 Iq 13 Pl F' E"'E ]" F E E ]" I:::' E.". 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'.:)0 W .... ll'.[i~.!{ FIO: ~ :L I:::' [:;: 0 ,...I Ii:i: C:'I" liii: D "1" i.'-I "1" I:l R E -: 01:< D 0 F' .1'_ N T E F:~ F'O L ~ T EI-~ ::i;IJ R'v'l:~ Y '1"0 F::' Z (::l hll!i!: 3 ( 'T'l::t: ) I!-i~,.'../'.iii: lii:i '.S F.l I)I.... E R 0 C H I 'l" O~ 2000' :m., im :.~...6DO0... ...... ~ 8000 i ARCO i ALASKA, I~NC, Ds 4.! .WELL NO,! 20 PRUD~OE B...~Y. N, ORTH ._.ASTM~N i , W, IeSrOCK:. INC "'i " ......... .t 1 .....! ...... Q, ........ } , 500:, .i i.~50~ , lOOOO i i ¢ .6500[ , , ,- GMS '~ SLOPE, ; :, 2000 VERTICAL tCLI3SURE '65.4 li, 60 4000 SEOTION I ; N ! I VERT'[CAL. PROJEC~I'O'N' - so~,~.~ , ~,. -i~ooo ~,~i i, ......... ':" Hq'R'~"~ONT'ALL "PiROJF-:CT'[ [ ' , , ...... {" ": +' T ...... , i " . !~RUDHOE BAY',. NO~TH PE.,.. A~A~K_A ........... .. ~ DIE, TH INDICATOR.,...TVD ] ' - ' : ':': i : ; :' -"' T L £O TELECO OILFIELD SERVICES INC. 6116 NIELSON WAY, ANCHORAGE, ALASKA 9~02 TEl--(~07) ,~ Movember 17, 198Z ARCO ALASKA PRUDHOE__BAY, ROWAN NO. ~1 DS-L, NOr 20 JOB NO. 312-AK Attached please find a copy of the computer calculated survey for the above-mentioned well ............... - On behalf of TELECO, I would like to. thank you. for the opportunity to serve ARCO Alaska.. We. at TELECO understand the importance-of good service and are-always, striving to supply only the highest quality service to ARCO Alaska. Please feel free to contact me if you have any questions. · Sincerely, Steve Billea~d, Field Service Supervisor S~B;jb Enclosures t) i ~b-~ i clNi~L CUSTOME. I WELL bAD t bRILLtN8 Co. , ROWAN ~t~ Nd. ! 4l CUSTOMER JOB NO. i hn~N~tIc QEcLiN~TioN t 30~30 I~LEc§.OILNtELb sEhvtu~u u~ DEPTH ANGLE VE~T~O~L ~EOtlOW Di~Ct~OW btBT~NO~ ~L~ BEVE.~TY DE8 MtN B£PTH D~ HIN bb NH gB DE8/100 FT. 3528 83.00 3490.68 2t?;00 3588 83,00 3498.68 8i?~00 3687 aS. Z4 3586.39 858;74 ZTaa as. mo. 3678~3~ 3837 87.18 377S.~ 349~6~ 3932 89.54 385~.99 4056 3t.54 3965.39 45~45 4180 34.30 4069.15 4308 37.84 4t67,9i 597~7t 4426 40.1~ 4864.48 67~.4~ 4547 43.30 4354.54 4609 44.48 4399.0? 799.34 4943 44.36 4636.68 ~034~06 5036 44.42 4708.84 t099~41 5220 44.36 4833.74 ta~8.70 5407 44.30 4967.00 i359,83 5748 48.06 5ama. 5~ i6m6;a~ 5809 sm. e4 5248.4t 1652.4~ 587i 52.36 588t.01 i70i,0i 5968 54. mm 5335.3~ t773.9~ 6085 54.06 5407.6~ i873.54 6456 56.36 56t8.54 2178.66 6519 56.30 5653.26 a23t.15 6672 57. m0 5737.15 2358.95 68;74 58.00 5818.82 2486.90 9.00 W 858.9~ M ~1.77 W 860.90 N k ~9 35 W 4.186 i~.36 W e9~.69 N ~9.34 ~ 3mt.~7 N ? 3e i4 W s. ao~ 18.48 W 44g,?B N ~i.4§ W 458.99 N ii 29 ~9 W i.665 1~.36 U ~56,65 N i5~.00 W 675.39 g J3 31 42 W a. 429 is. Sm W 734, aa N te~.6i W 756. ii N i~ 19 ii W a. 673 19. t8 W ?~S;79 N i98,18 U 799.~4 N i3 54 4? W 2.089 i4.54 ~ i0~a. 47 N aS~.iZ W im33.93 N i~ t0 i6 W m. m70 iS. ia W io6~.58 N eTm. im W ims~.a8 N ia 13 a~ W 0.25i t6.24 W i3i9;92 N 348. i3 W i359.67 N il 31 a~ W 0.065 i5.36 W issa. 9~ N 410.08 ~ i6m6.14 N ii 4~ 33 ~ 1.069 iS. ia W 1~44.12 N 435.63 ~ i70m. 86 N t4 5m 24 W 3.657 12.54 W i7i4.58 N 454;58 W i773. ea N 14 50 56 W i.s6! t5.08 W ibim. ze N 480.87 W i873.39 N t4 si is W m. ios 1t.48 W 81~?.74 N 550.74 W 8t78.5o N I4 38 36 W 0.995 ii.36 W aiss. aa N 56i.35 W a23i.mo N i4 34 83 W 0.807 ie. o0 W aa24.47 N 587.5a W a352. ei N t4 a5 at W m. 393 to.]e u a:41o, a~, N 61e.~t W a4e~.eo N t4 t5 14 W 1.150 t~ i ~t~:C+ i ~Wr~L blt t LL ~r Wl~t mUrlVl=Y fil=l~Ol~+ ~OB NUMBER CUSTOMER , ~CO ~nD ~ D84 W~LL No. ~ ~0 bEG MiN DEPTH DE~ MIN D~ MM ~fl DE~/ioe FT. , 7468 ~G. 30' ~te~.3e 3088,80 ~ ~e. e6 7579 ~e.~4 6~3.03 31~a,~6 N 80.48 7746 ~9.54 6308,04 3~6~3~ N ~i.5~ 8243 ~1.~0 ~55i~97 3695~ i4 N et.a4 g 861 i US. ~4 673~. 8i 400~. 7~ ~ ~ ~4 ~ 3i76 ~6.00 704i.45 148i.91 H e3, t~ Q 9393 54. ia 7165. k0 4657.35 N 8a. Si'N 97G~ 5i.06 7400.?t 4364.76 N a~.i~ 1~033 50.~4 7559.9~ 9i57.89 N 88.54 107~0 47.30 80~i.53 6681.70 N ~0.~8 11845 44. ia 8373.89 6049.14 N 16.36 BOTTOM HOLE PRINTED ~ 16 NoV, J983 8,38=3i ~M ~85,6~ N 7§i.~0 U 3088.08 N J4 ~6 ~7 ~ ~.760 30i~,49 N 814. t4 ~ 3l~a. sm N t5 ~6 48 ~ 0.648 3i~8.37 N U66.47 U 3~65.43 N i5 ~3 i5 W 0.8a5 ~311~13 N 995.~§ U 3503.87 H t~ 4~ i§ ~ o. 48a 35~o. 9s N i0~5, g3 ~ 3696. i~ N i~ ~& ~3 U 0.060 367~,~t N i07~64 g 3889.3~ N i~ i8 4b U 0.957 3§44,7t H 1146.08 W 40ii.88 N i& 35 B3 U 0.669 ~§S.~ N lt~&,ia U 4i4~.~i ~ J~ 47 0~ U 0. U04 4iai~38 N i8~9.94 ~ 4309,66 N i& b9 ~6 ~ 0.109 4885~00 fl i388.73 ~ 448&.a9 N i~ t3 60 U 0.894 ~448.7i N i398.~s U 4663.36 N i? 87 ~6 U 0.843 4608,7i N t46~.98 W 4836.~5 H t~ 3§ 4~ U 0.649 4734,5§ N {5i8. ii U 497a. ei N i? 46 ii ~ i.080 4914.0~ N i~9~.6S W 5165.73 fl i7 ~7 a{ W 0.353 5409~4& N i7~4.§? W 5639.~6 N t~ ~i 8i ~ o. 658 975~6§ N' J9i1.05 U ~061.B0 ~ i§ ~8 39 W 0.685 nencUs CGMPUTER SERVICE 3tt N. 7is{ RVENUE ANCHORAGEi R~. ~950~ ( 907 ) 344-076t Suggested ~-orm to be inserted in each "Active" well folder to d~eck for timely c~liance w-i_~h our' rcgulations. 'Operator, Well Nam~ and Number Reports and Materials to be received by: / / -- ~-- Date Required Date Received Remarks ~ , , _ Completion Ret2ort Yes Well History Yes -.. _Samples ., Core Chips " ./~f~ ,./~__~ (~. !,~.'~ Core Description z/x .~..?~ ~e~s~er,~ Su~ve~ ~at ~d~V ~- / D~e~ional ~ey Drill St~ Test Re~s , .~_ ~s ~=. ~es ~. ~. . , , Digitiz~ ~ta ~~ y~ ARCO Alaska, Inc. POSt Office .~o.x 360 A~choraoe '~ska 99510 - 'r eiepnone, 9u/ ,.'~T7 v'~637 November 7, 1983 Re ference ' Arco Cased Hole Finals D.S 1-18 D. S 3-23 D. S 4-20 D.S 5-1 ~ D.S 5-14-'- D.S 5-15-~- D.S 13-3 D.S 13-6 D.S. 13-98 .... D. S. 14-7 ~ D. S. 14-31 ..... D-',S. 14-33/. D.S. 18--7~'' 8-10-83~ 9-30-83 8-10-83 7-7-83 8-7-83 9-29-83 8-4-83,~ 10-1-83 Epilog 9-19-83 ACBL/VDL/Sig/GR 9-7-83 ACBL/VDL/Sig/GR 9-22/24-83 Diff Temp 9-10-83 Collar Log 9-10-83 Collar Log 10-5-83 Epilog 10-21-83 Spinner 10-21-83 Temperature 9-30-831~-'-$W-Overlay 8-10-83 c SW-Overlay 9-30-83 GST Inelastic & Stations 9-29-83 ~-' CH DIL 7-7-83~ CH CNL 10-1-83~ EPL 8-10-83--~ Thermal CH CNL Epithermal CH CNL GST Capture & Activation CH DIL CH CNL Epithermal DIL Epilog CBL/VD 8-4-83 ~- .... CET 9-21-83 ACBI~/VDL/Sig/GR 5-18/20-83 PLS/PBU-Spinner-Flolog 5" DA Run 1 5" DA' · . Run 1 5" DA Run 1 & repeat/i-6 5" GO Run 1 5" GO Run 1 5" GO 5" DA Run 1 5" Otis Run 1 5" Otis Run 7 5" Sch Run 5 5" Sch -Run 2 5" Sch Run 7 5" Sch Run 4 5" Sch Run 1 5" Sch 5" Sch Run 5 5" Sch Run 2 5" Sch Run 6 5" Sch Run 4 5" Sch Run 5 5" Sch 5"' DA Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" DA Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 604 D &M Drillin? DISTRIBUTION .! North Phillips £a: ; L2::~ Marathon Sch!c S%ate cf Alaska ARCO Alaska, Inc;'--" Post Office ,...,x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 October 17, 1983 Reference: Arco Magnetic Tapes P5 ~D.S. 4-20 9-2-83 OH tape w/listing # 68524 Run 1/2 Sch .~ D.S. 14-33 9-18-83 OH tape w/listing # 68580 Run 1/2 Sch D.S. 14-7 9-29-83 CN/MSN # 1828 DA X/~ D.S. 4-16 9-27-83 OH tape w/listing # 68609 Ru,n 1/2 Sch e sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 545 Chevron D & M Dallas Drilling Getty Marathon Mobil DISTRIBUTION (mcho[age North Geology Prudhoe Bay R & D ,.~ ...... ~ STATE OF ALASKA ALASKA. -AND GAS CONSERVATION CC ,VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS-/ Drilling well ~1~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 1206' FSL, 195' FWL, Sec. 26, T11N, R15E, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 57' RKB 17' GL I ADL 28322 UM 7. Permit No. 83-119 8. APl Number 029-20996 50- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 4-20 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of September ,19 83 12.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~naldri~lingpr~b~ems~spuddate~remarks Spudded well @ 0500 hfs, 08/13/83. Drlg 17-1/2" hole to 2535'. Ran, cmted & tested 13-3/8" csg w/shoe @ 2528'. Drld 12-1/4" hole to 11,333'. Ran, cmted & tested 9-5/8" csg w/FS @ 11,306'. Drld 8-1/2" hole to 11,890'. Ran OH logs. Ran, cmted & tested 7" lnr. Arctic Packed 9-5/8" x 13-3/8" annulus. Ran CBL. Ran 5-1/2" compl assy w/tail ~ 11,072' + pkr ~ 10,993'. Secured well & RR ~ 2400 hfs, 09/08/83. See Drilling History. 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, U-40, weld conductor set ~ 80'. Cmted w/385 sxs Arctic Set. 13-3/8" 72#/ft L-80 BTC csg w/FS ~ '2528'. Crated w/1935 sxs Fondu + 400 sxs PF "C". 9-5/8" 47#/ft L'80 BTC csg w/FS 8 11,306'. Crated w/500 sxs "G" amt. 7", 29 #/ft, L-80 BTC csg f/11,888' - 11,040'. Cmtd w/358 sxs "G" cmt. See Drilling History. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/GR/SP f/11,871' LDT/CNL/CR/CAL f/11,830' CBL f/11,820' - 10,900' - 11,298' - 11,298' 6. DST data, perforating data, shows of H25, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~j' // ~-~-~/ Area Dril ling Engineer .... SIGNED ;./_~,~;~¢,--¢..~. ~//~.,~.- ._/...~...-2--_->/.~,./~-,~ TITLE U/A/t:.,/'¢4//~/~/~/ '¢* NOTE/.--"F~IJ~rt on this form/' is required for each ~alendar month, regardless of the status of operations, and must be file/d in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR3 6 Submit in duplicate DS 4-20 Drilling Hi story NU 20" hydril and diverter system. Spudded well @ 0500 hrs, 08/13/83. Drlg 17-1/2" hole to 2535'. Ran 62 jts 13-3/8" 72s~x/sftP w/FS @ 252,,8'. Cmtd 13-3/8" csg w/2335 sxs total 1935 Fondu + 400 ~ "C" diverter system. Instld 13-3}8 . ND 20 hydril & "packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 11,333'. Ran 248 jts 9-5/8" 47#, w/FS @ 11, 306' Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC &'cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11,890' (09/01/83). Ran DIL/BHCS/GR/SP f/11,871' - 11,298'. Ran LDT/CNL/GR/CALIP f/11,830' - 11,298' Stuck logging tool. Recovered on 09/03/83. Arctic packed 9-5/8" x 13-~/8" annulus 300 sxs PF "C" + 125 bbl AP. Ran 21 jts 7" 29#/ft, f/11,888' - 11,040' Cmtd 7" lnr w/358 sxs "G" cmt. Drld cmt to 11,843'. PBTD. Tstd lnr l'ap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/11,820' - 10,900' Ran 5-1/2" completion assy w/tail @ 11,072' & pkr @ 10,993' + SSSV @ 2208". Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs, 09/08/83. DRN/DH31 09/27/83 ARCO Alaska, In : Post office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton- Enclosed are Monthly Reports of Drilling and Workover Operations for the following' DS 4-20 DS 14-32 DS 14-31 DS 3-23 DS 3-22 DS 3-21 Pingut State #1 South Point State #1 Sincerely, ~-M:~X~A. Major ~ Area Drilling Engineer MAM/DRN: tw NORTON/45 Encl osures ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany - ?,, ~ " ~- STATE Or: ALASKA ~-, [J~j ~ ' ALASKa. mlLAND GAS CONSERVATION £ vlMISSION ' IONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS:' 1. Drilling wellX~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-119 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20996 9. Unit or Lease Name FSL, 195' FWL, Sec. 26, T11N, R15E, UN Prudhoe Bay Unit 4. Location of Well 1206' at surface 5. Elevation in feet (indicate KB, DF, etc.) 57' RKB 17' GL 6. Lease Designation and Serial No. ADL 28322 10. Well No. 4-20 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of August ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0500 hfs, '08/13/83. Drlg 17-1/2" hole to 2535'. 13-3/8" csg w/shoe ~ 2528'. Drld 12-1/4" hole to 11,333'. Ran, csg as of 08/31/83. See Drilling History. Ran, cmted & tested cmted & tested 9-5/8" 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40, weld conductor set ~ 80' Cmted w/385 sxs Arctic Set 13-3/8" 72#/ft L-80 BTC csg w/FS ~ 2528'. Crated w/1935 sxs Fondu + 400 sxs PF "C". 9-5/8" 47#/ft L-80 BTC csg w/F5 @ 11,306'. Crated w/500 sxs "G" cmt. See Drilling Hi story. 14. Coring resume and brief description NoNE 15. Logs run and depth where run . NONE TO DATE 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer SIGNED ~ ~-TITLE DATE NOT,~l~el~t on this for,~ required for e c~h calendar month, regardless of the status of operations, and must I:~iled in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR28 Submit in duplicate DS 4-20 Drilling History NU 20" hydril and diverter system. Spudded well @ 0500 hrs, 08/13/83. Drlg 17-1/2" hole to 2535'. Ran 62 jts 13-3/8" 72#/ft, w/FS @ 2528' Cmtd 13-3/8" csg w/2335 sxs total - 1935 Fondu + 400 sxs PF "C". ND 20" h'ydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 11,333'. Ran 248 jts 9-5/8" 47//, w/FS @ 11, 306'. Cmtd 9-5/8" csg w/500 sxs "G" cmt as of 08/31/83. DRN/DH23 09/14/83 M EMORAN MUM State of Alaska ALASKa-IL AND GAS C©~$ERVATION COMMISSION lo: C. V On DA/E: August 24, 1983 .'~ Chai~f ~ Thru: Lonnie C. Smith FILE N'O: 10 8B:S 1 C~missioner ~LEPHONE_ NO: FROM: Ben LeNorman SUBJECT: Petroleum Inspector Witness BOPE Test on ARCO's DS 4-20, Sec. 26, TllN, R15E, 5%~, Prudhoe Bay Unit. Sunday, AUgUSt 14,._..!78.3: I deParted my home at 3:15 pm for a 3:45 pm showup and 4:45 pm departure via Alaska Airlines, Flight ~_'~. 341 for Deadhorse arriving at 7:10 pm. Weather: +36"F, light wind, fog. August. 15, 1983: BOPE tests began at 7:35 pm and were ~P/e~ed ~t~ 9~35 pm. BOPE inspection report is attached. Inspection of nine abandoned and thirty-two suspended ARCO wells began at 9:00 am and was completed at 3:30 p[;~ on Wednesday, August 17, subjects of separate reports. I departed Deadhorse via Alaska Airlines, Flight No. 56 at 4:30 pm arriving in Anchorage at 6:10 pm and at my home at 6:40 In s~ma~, I ~tnessed successful BOPE test on ARCO's DS 4-20. AttacP~ents 02-00IA(Rev. 10179) 4/81 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CCMM/SSION B .O.P.E. Inspection Report Operator_ ~~ Representative r Well _~ ~- ~-~-~O Permit #. Location: Sec ~ ~ T//~,/~M ~.F~ ~a~sing Set @,~y-~- ft. Drillinq Contractor /~.E~,~~~ig # -~-J Representative Location, General Well Sign_ Ceneral Housekeeping Reserve pit Rig BOPE Stack Annular Prevent.er Blind Rams Choke Line Valves.__ H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCO%~ULATOR SYSTEM Full Charge Pressure ~(p~ ~; Pressure After Closure .~D (:~ Pimp incr. clos. pres. 200 psig Full Charge Pressure Attained: psig psig min/Psec. min~ec. N2.~/(D~ ~~~~ ~/~ 6; psig Controls: Master ~/~ 'Remote~ Blinds switch cover/(~_~-_ Kelly and Floor Safety Valves · Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Upper. Kelly Lower Kelly.. · B~li Typ~ Inside BOP Choke Manifold No. Valves _/~/ No. f langeg ~/~P Adj ustab le Chokes Hydrauically operated choke Test Results: Failures ~ Test Time' J~ ~ hrs Repair or Replacement of failed equipment to be made within, days and Inspector/Ccmmission office notified. Distribution orig. - AO&OCC cc - Operator cc - Supervisor Inspector · ! August 2, 1'983 Mr. Mmrk A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 4-20 ARCO Alaska, Inc. Permit No. 83-119 Sur. Loc. 1206'FSL, 195'F%rL, See. 26, TllN, R15E, UM. Btmhole Loc, 1927'FSL, 1347'FEL, Sec. 22, TllN, R15E, UI1. Dear Mr. ~i~Jor: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuou~ directional survey is required aa per 20 AAC 25.050(b)(5). If available, a tape co~taining the digitized log information shall be submitted on all logs 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 16.05.870 and~th~ regulations promulgated thereunder (Title 5, Alaska AdministratiVe Code). Prior to commencinE 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 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Mark A, Major Prudhoe Bay Unit DS 4-20 -2- August 2, 1983 prevention equipment so that a representative of the Comraission .may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may w~itness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. //."'?; ........... Alaska Oil and Gas Conservation Cov~ission be: 6... H/A EnclOsure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. ~-'" Post Office B(.,_. i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 29, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 4-20, Permit to Drill Dear Mr. Chatterton- Enclosed is our application for Permit to Drill DS 4-20 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on August 15, 1983, your earliest approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG4LI' sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alas!t,.'., ,:,, & ~J~s Cons. Commissio~ /-',nchorag~ STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ]0[ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1206' FSL, 195' FWL, Sec. 26, T11N, R15E, UM At top of proposed producing interval 1820' FSL, 1320' FEL, Sec. 22, T11N, R15E, UH At total depth 1927' FSL, 1347' FEL, Sec. 22, T11N, R15E, UH 9. Unit or lease name Prudhoe Bay Unit 10. Wellnumber DS 4-20 11. Field and pool 0fi Prudhoe Bay Field Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 57', 17' GL ADL 28322 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount ,$500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 6 mi. NE of Deadhorse miles 1347' (~ TD feet 4-11 well 960' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 11558' MD, 8772' TVD feet 2560 08/15/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures .3300 psig@____ Surface KICK OFF POINT 2600 feet. oI (see 20 AAC 25.035 (c) (2) psig@ 8800 ft. TD (TVD) MAXIMUM HOLE ANGLE 51 4200 21 Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight ~0" 20" 91.5# H-40 7-1/2" 13-3/8" 72.0# 2-1/4" 9-5/8" 47.0# 8-1/2" 7" 29# 22. Describe proposed program: ;ASING AND LINER Grade Coupling Length We] ded L-80 Butt L-80 Butt 110948' L-80 Butt I 872 ' MD TOP TVD 80' 40' I 40' 2461' 39' I 39' I 38' ~ 38' I 10686' 18219' I MD BOTTOM TVD 120'I 120' 2500'12500' 10086']8409' I 11558' 118772' (include stage data) 385 sx AS II 2300 sx Fondu & 400 sx PF 500 sx G 1st Stage & 300 sx PF 1 2nd Stage 300 sx Class G cmt ARCO Alaska, Inc., proposes to directionally drill this well to 11558' MD (8772' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 4-20 will be 960' away from DS 4-11 at the surface. There are no closer wellbores anywhere downhole. 23. I hereby certify that the foregoing is true and corre~ct to the best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL DATE Samples required f-lYES [~0 Permit number APPROVED BY Form 10-401 / ~PD53 Mud Icg required I-lYES [~NO Approval date 3 .// Directional Survey required I APl number J~YES []NO I 50- O'/-,(~ - ~_O ~ 9(o SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE AuD]st 9~ 1_983 by order of the Commission Submit in triplicate ANNULAR PREVENTER BLIHI) P, NIS PIPE 0RILLII~ SPOOL PIPE 13-5/8" B0P STACK 0IAG~¢ / .o Accumulator Caoacit~, Tes~. lo C~eck and fill accumulator reserwoir 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 simultane- ously and record the time and pressure remaining after all units are closed with charging pu~p off. ¢. Record on IAOC report. (The acceptable lower limit is ¢$ seconds closing time and 1200 psi remaining pressure. 13-5/8' BOP Stack Test 1o Fill BOP stack and manifold with a non-freezing 1 iquido 2. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock · dow, scr~s. 3. Close annula~ preventbr and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, ZSO psi low pressure test for a minimum of '3, minutes, then test at the high pressure. $. Increase presure to 3000 psi and hold for a minimum of_ 3 minutes. B-leed p~*essure to zero. $. Open annular ~reventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves {if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe r~. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. I2. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14, TeStKoomeyKellyp~p.COCkS and inside BOP to 5000 psi 15. Check operation of Oegasser. 15. Record test information on blowout preventer test form. Sign and send to Drilling Super- v i sor. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. Rev. 5/13/81 SURFACE HOLE D IVERTER ARCO ALASKA ......-----I0" HYD. (3PR. BALL VALVE / p WE,L,L BORE . ./ /"~ I0 HYD. OPR. BALL VALVE / / / I ALL 90" TURNS ARE "TEE'' --_ ~ I CUSHION ! I~LL RESERVE AREA NOTE' SYSTEM ;[NC'. FLCANt_ INE SC HE MA-]- I C DR ILL ING R I SER ., :,.; -~F.:.,.' 20" 2OOO PSI WP ANNULAR PREVENTC~ I O" HYDRAULIC OPERATED BALL VALVES "-IO" I) IVERTER LINE --DRILLING SPOOL Valves on diverter lines open automati- cally when the annular vreventer is closed. 20" CONDUCTOR PIPE "DETAIL" 20~6C CHECK LIST FOR NEW WELL PERMITS ITEM ,APPROVE DATE (1) Fee (2) Loc ( 1) (4) Casg ~zf~ ~ ¥-~'-.~ (12 thru 20) (5) BO PE //~-# J{- (21 thru 24) 1. IS 2. Is 3. Is 4. Is 5. 6. 7. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Company '~. ., the permit fee attached ......................................... ,. well to be located in a defined pool ................. , .......... well located proper distance from property line ................. well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is well bore plat included .......... ,... Is operator the only affected party ................................ Can permit be approved before ten-day wait ......................... ," . . "£f, Lease & Well No. . YES NO REMARKS Does operator have a bond in for.ce ......................... , ........ Is a conservation order needed ............... · . Is administrative approval needed ................................... ~--~' 1 Is conductor string provided .................................... Is enough cement used to circulate on conductor and surface ..g.g Will cement tie in surface and intermediate or production str Will cement cover 'all known productive hor'izons'. .......... . .... Will surface casing protect fresh water zones .............. ' Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing welibore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ...........' Are necessary diagrams of 'diver;~'~d ~ ~i~;'~;;~ ...1... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: ~47-~ ~-/-~.~'~ 25. Additional requirements ............................................. Additional Remarks: o r..a ,-] Geology: Eng..$r(~~ng: HWK ~ L~ST/¢~ BEW J #,Zg JAL ~MTM~Z~/- rev: 12/06/82 INITIAL GEO. UNiT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATIDN LISTING VP 010.H02 YERIFIC,ATI£1f~ [,ISTING PAGE ! * REEL HEADER ** ER¥ICE NAME :EDIT 'ATE I87109/10 ~RIGIN EEL NAME :72438 'ONTINUATIOM # 'REVIOU$ REEL : !OMMENTS :LIS TAPE,ARCO PRUDHOE BAY D.$. 4-20,API # 50-029-20977 :* TAPE HEADER ** iERVICE NAME ~EDIT 'ATE :87/09/10 'RI~IN :724~ :AP.. ;ONTINU~TION ~ :01 'RE¥IOUS TAPE ~OMMENTS :LIS T~PE,ARCO PRUDHOE BAY D.S. 4-20,API ~ 50-029-20977 ********** EOF FILE MEADER ** 'ILE N~M~ :EDIT ,001 ER$IO~ # . ~AXI'~ LENGTH : 1024 ~ILE TYPE : ~REVIOUS FILE : INFORMATION RECORDS ** CONTENTS ARCO ALASKA INC. D.$. 4 - 2O PRUDHOE BAY NORTH SLOPE [.iSA ~.NEM CON, TEN ro UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 012 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 ONIT TYPE CATE SIZE CODE 000 000 001 065 VP 0~1.0,H02 VERI?"iC6TIO~ blS[riNG PAGE *********************************************************************************** SCHLI.I~BERGER * ALASKA CO.~,PUTING CEi".~TER *********************************************************************************** O~P~Y = ARCO AI,~SK,'~ Ii'~C, ELL = D S 4-20 IE[,D = PRUD~OE OUNTY = ~ORTH SLOPE BOROIlGH TATE = AD~$KA OF NUMBER AT AKCC~ 72438 UN #1, DATE bOGGED: 02-SEPT-87 DP: R, KRUWELL ASlNG ~YPE FLHID 9 625" @ 11306' 7:000" ~ 11888' 5.5" M 11072' DIESEL/9,$# NACb ' 'N ,ATRIX SANDS'T£.,. E ' 1,~CHANN~ELS~ ~.,ITH TM~ EXTENSIOI,,! ~S! AR~ FROM BbU.~LINE~.~ PASS ~OTE. 2, CHANNELS ~ITH THE EXTENSIO~ PS2 .~RE FROM BLU bINE PAS~ 3,)CHANNELS WITH THE EXTEMSIO~ PS3 ARE FROM BbUELINE PASS VP OlO,H02 VERIFICATION LISTING PAGE 3 4,)CHANNEL WITH THE EXTENSION MI,,A IS HODGE$ LEH)~A~4N AVERAGE NEUTRON POROSITY 5,)FILE EDIT,O01 CONTAINS DATA SAMPLED ~ ,5' )FILE EDIT 002 CASING COLLAR LOCATOR DATA ~AMPLED ~ 053' ************************************************************************ , , , , , , , , , , , , $ , , , , , , , * , , , , COMPENSATED NEUTRON LOG (PASSES 1,2,3,HLA) , · PASS i DATA AVAI[,ABI, E: 11740' TO 11250' · PASS 2 DATA AVAILABLE~ 11739' TO 11249' · PASS 3 DATA AVAILABLE~ 11739' TO 11249' , , * , , , , , , , , , , , , , , , , , , , , * DATA FBRMAT RECORD ** 'NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 8 4 73 60 9 4 65 ,lIS 16 1 66 0 ! 66 0 )ATU~ SPECIFICATION BLOCKS REPE PROCESS ~NEM SERVICE SERVICE UNIT AP1 API API API FIGE SIZE SP~ CODE (OCTAL) ID ORDER # bOG TYP~ CLASS MOD NO, !EPT FT O0 000 O0 0 0 4 I 68 00000000000000 ,R PS1 GAPI O0 310 O1 0 0 4 ! 68 00000000000000 ~PH! PSI PU O0 890 O0 0 0 4 I 68 00000000000000 VP OIO,H02 VER!IF.ICATIO!~ %ISTING PAGE 4 RAT PS1 OO 420 NRA PS1 O0 000 CNL PSI CPS O0 330 CNL PSi CPS O0 330 E~$ PSi LB O0 635 R PS2 GAPI O0 310 PHI P$2 PO O0 890 EAT PS2 O0 ~20 NRA PS2 O0 000 CNL PS2 CPS O0 ]30 CNt P$2 CPS O0 330 ENS PS2 LB O0 635 'E PS] GAPI O0 310 PHI PS3 PU 00 890 RAT P$3 O0 420 NRA PS3 O0 000 CNL PS3 CPS O0 33¢) CNL PS3 CPS O0 330 'EN$ PS3 bB O0 635 PHI H[,A PU 00 890 O1 0 0 4 O0 0 0 4 31 0 0 4 3O 0 0 4 21 0 0 4 01 0 0 4 O0 0 0 4 O! 0 0 4 O0 0 0 4 31 0 0 4 3o 0 0 4 21 0 0 4 O! 0 0 4 O0 0 0 4 01 0 0 4 OO 0 0 4 31 0 0 4 30 0 0 4 21 0 0 4 O0 0 0 4 'EPT 11806,5000 GR 30, 'NRA 2,2969 NCNb 1490, :R -999,2500 NPHX .-999, iCNL -999 ~500 FCNL -999, ipH! -999:~500 NEAT -999, 'CNL -999,2500 TENS -999, ~gPT ;R ~PH~ 11800 0000 GE 2 5762 NCNb -999 2500 NPHI -999 2500 FCNL -999 2500 NEAT -999 2500 TENS ~EPT NRA CI~ I., 117000000 GR 29531 NCNb 12~ 6250 NPHI 0000 FCN~ 26 0254 NEAT 460 2500 TENS )EPT ,R {PHI 116000000 GR 2 0059 NCNb. 20 6719 NPHI 22860000 FCN~ 1211 3770 ~RAT 000o TENS )EPT ~NRA 60000 G R 4844 NPH! 0000 FCNU 250O NEAT 2500 TENS 2500 RNRA 2500 NPH! 30 4844 NPHI 1582 0000 FCNL -999 2500 ~EAT -999 2500 TENS -999 2500 RNRA -999 2500 NPHX 600000 NPHI 11350000 FCNb 23 .~!81 NEAT 419 ~00 TE~S 2 830~ RNRA 1040 000 NPHI 11 2OO 0625 NPH! 0000 FCNL 3281 NRAT 0000 TENS 8672 RNRA 0000 14,2266 NPHI 2648.0000 FCN'L 1 68 00000000000000 I 68 nO000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ~ 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 t 68 00000000000000 i 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 170898 NRAT 6485000 TENS -999 2500 RNRA -9992500 GR -999 NCNb 17 ~0098 20e0195 NEAT *0000 TENS -~99,2500 GR 99,2500 NCNb 20,;0195 25,9766 NEAT 384.2500 TENS 2.7090 RNRA 1025.0000 GR 21,8379 NCNb ~4517 12.7930 NEAT 114~,0000 TENS .8623 RNRA 100 ,0000 GR 1.7822 NCN~ 11,7188 8.1055 NEAT 1626.0000 TENS 2,2891 395,0000 ,,,999,2500 ,,,999,2500 -999,2500 2,4863 665,0000 -999.2500 '999,2500 -999,2500 1065 O0 , 1307',0000 2204, O0 1,5928 965,0000 VP OlO,H02 YERIFICATION LISTING PAGE 5 R 18 4219 NPH! CNb 2762,0000 FCNb PHI 8,4473 NRAT CNL 1753,0000 TENS ?,bt72 NRAT 1757,0000 TENS 1,6230 RNRA 1030,0000 NPHI 'EP~ 11400,0000 GR NRA l:~lll NCN[, ;R 17 000 NPHI iCNb 2644 ~000 FCNL ;PHI. 7:613 NRAT 'CNL 1726,0000 TENS 17,]906 NPHI 2662,0000 FCN[, ]:2266 NRAT 176 0000 TENS 1,5703 RNRA 1070,0000 NPHI iCNb iPMI 'CNL 11300 0000 GR 4 6641 NCNb 63 0625 NPHI 69.4 5000 FCNL 66 4063 NRAT 166 3750 TENS 69 5000 NPHI 741 5000 FCNL 59 9609 NRAT 184 5000 TENS 5 0430 RNRA 1065 0000 NPHI )EPT ~NL ~PHI ~'CNb 11200,0000 GR -999,2500 NCNb -999,2500 NPHI -999,2500 FCNL -999,2500 NRAT -999,2500 TENS 69 6875 NPHI -99912500 FCNL -999 2500 NRAT -999 2500 TENS -999,2500 RNRA '999,2500 NPH! )EPT !,NRA ,R ~CNb ~PHI ~CNL 1~100,0000 GR '999 500 )}PHI -999,2500 FCNL -999,2500 NRAT -999,2500 TENS 58 8437 NPHI '999 2500 FCNL '999 2500 NRAT '999 2500 TENS '999 2500 RNRA '999 2500 NPHI ~CNt, ,PHI ~CNb 11000 0000 GR "999 2500 NCNb "999 2500 NPHI -999 2500 FCN5 -999 2500 NRAT -999 2500 TENS 43,0625 NPHI -999,,2500 FCNb -999,2500 NRAT "999,2500 TENS -999,2500 R.NRA -999,2500 NPHI ).EPT q~Nb ~tpHI 1~900 999 -999 -999 -999 -999 0000 GR 2500 NCNb 2500 NPHI 2500 FCNL 2500 NRAT 2500 TENS . 57, 999 -999 "999 "999 "999 4375 NPHI 2500 FCNL 2500 NRAT 2500 TENS 2500 RNRA 2500 NPH! 3EPT RNRA ~R ~CNL NpH I FCNL 10888 00o0 GR -999 2500 NCNb -Egg 2500 NPHI -999 2500 FCNL -999 2500 NRAT -999 2500 TENS -999,~:500 FCNL -999,2500 NRAT -'999,~500 TENS -999,~500 RNRA -999,2500 NP~I 1,5479 RNRA 910,0000 GR 1,5977 NCNb 8,0688 6,3477 NRAT 1886,0000 TENS , 5156 RNR~ 94 ,0000 GR ,5{71 NCNb 7,1655 56,738] NRAT 158,8750 TENS 4,6914 RNRA 945,0000 OR 4,7227 NCNb 60,7666 '999,2500 NRAT '999,~500 TENS '999, 500 RNRA -999,2500 OR -999,2500 NCN£, -999,2500 1,5713 18,~656 2802, 000 1 4316 1015 0000 1 4990 1 ~ 0625 2654 0000 4 5156 965 0000 3 7637 63 0625 786 0000 -999 2500 975 0000 -999 2500 -999 2500 -999 2500 '999,2500 NRAT '999,2500 '999,2500 TENS 990~,0000 -999,2500 RNRA -999,2500 =999,2500 GE -999,250'0 '~99,2500 NCN~ -999,2500 ' 99,2500 -999,2500 NRAT '999,2500 TENS -999,2500 RNRA -999,~500 GR '999, 500 NCND "999,2500 '999 '999 '999 '999 '999 '999 500 NRAT 500 TENS 2500 RNRA 2500 GR 2500 NCNb 2500 -999 2500 NRAT -999 2500 TENS '999 2500 RNRA -999 2500 GR -999 2500 NCN[, '999,2500 '999,2500 930,0000 '999,2500 -999,2500 '999,2500 '999,2500 95 ,0000 -99~,2500 -999,2,500 "9' 99,2500 -999 2500 840 0000 -999 2500 -999 2500 ,,999 2500 VP OIO,H02 VERIFICATION LISTING PAGE 6 FILE TRAILER ILE N~E :EDIT ,001 ERVICE NA~{E : ERSION ~ AXIMU~ LENGTH : 1024 ILE TYPE EXT FILE NAME EOF , FI6E HEADER ** 'ILE NAME JEDIT ,002 ,ERVICE NAME !ATE LAXI~U~ LENGTH : 1024 'ILK TYPE : 'REViOUS FILE DATA FORMAT RECORD ** :NTRY BLOCKS TYPE SiZE REPR CODE ENTRY 2 I. 66 0 4 1 ~6 1 B 4 73 10 .9 4 65 ,lin 1~ 1 66 I 66 ~ )ATU,~ SPECIFICATION BLOCKS API FILE SIZE SPL REPR PROCESS ~NEM SERVICE SERVICE UNIT API APl API ID ORDER # LOG TY'PE CLASS N CODE (OCtAb) FT O0 000 O0 0 4 ! 68 00000000000000 )EPT :Cb PS! 00 150 01 0 0 4 I 68 000000000000'00 i[~ PS2 00 150 Ol1 0 0 4 i 68 0000000000'0000 PS3 00 i50 0 0 0 4 1 68 0000000000000'0 DATA )~PT 1t806,9160 CCL -0,0732 CC~ -999,2500 CCh -999,2500 )EPT 118'00,2500 CCL -0,0732 CCL '999,2500 CCL -999,2500 )EPT 11700,2500 CCL -0,0244 CCL '0,0488 CCh '0,029~ )EPT I1600,2500 CC~ 0,0244 CC~ '0,0419 CC~ "0,0195 :)~PT 11500,2500 CCh -0,O391 CCG 0,0342 CCL "0,0488 )EPT 11400,2500 CCL '0,0342 CC5 '0,0342 CCh '0,0293 VP 01C,H02 VERIFIC4TIO~ LISflNG PAGE 7 EPT 11300,2500 CCL 0.0098 CCI., EPT 11200,2500 CCL -0,0244 CCI., EPT 11100,2500 CCL '0.0293 CCL EPT 11000,2500 CCL -0,0342 CCh EPT 10900,2500 CCL -0.0488 CCL EPT 10@85,0000 CCL -O.0O98 CC5 ILE NA~E IEDIT ,002 ERVICE NAME ER$ION # ATE : AXI~}.]~ LENGTH : 1024 'ILE TYPE EXT FILE NAME -0.0293 COL -999.2500 CCL -999.2500 CCL -999,2500 CCL -999.2500 CCh -999.2500 CCL -0,0146 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 TAPE TRAILER ** ;ERVICE NA~E iEDIT ~ATE :87/09/10 IRIGXN :724~ ~APE :ONTINUATIOM # :01 iEXT TAPE NAME ; ~O~ENTS :LIS TAPE,ARCO P~UD~{OE BAY' D,$. 4-20,API ~ 50-029-20977 )ATE_~87/09/IO )RIGIN : tEEL NAME :72438 ~ONTINUATION # IEXT_REEL NA~'E : ~O{~MENTS {hIS TAPE,ARCO PRUDHOE BAY D.S, 4-20,API # 50-029-20977 EOF EOF' * ALASKA COMPUTING CENTER * * ****************************** , ............................ * * ....... SCHLUMBERGER ....... * * ............................ * ****************************** SEP ?_4 1998 COMPANY NAME : ARCO ALASKA, INC. WELL NAI~IE : D.S. 04 -20 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUA1~ER : 500292099600 REFERF_J~CE NO : 98341 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/ 3 ORIGIN : FLIC REEL NAME : 98341 CONTINUATION # : PREVIOUS REEL : COM~EJFr : ARCO ALASKA, INC, DS 04-20, PRUDHOE BAY, # 50-029-20996-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/09/ 3 ORIGIN - FLIC TAPE NA~IE : 98341 CONTINUATION # : 1 PREVIOUS TAPE : COMFIEAUf : ARCO ALASKA, INC, DS 04-20, PRUDHOE BAY, # 50-029-20996-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAFIE: D.S. 04-20 API NUFiBER: 500292099600 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 3-SEP-98 JOB NUMBER: 98341 LOGGING ENGINEER: C. Yon OPERATOR WITNESS: Worthington SURFACE LOCATION SECTION: 26 TOWNSHIP: liN RANGE: 15E FNL: FSL: 1206 FEL: FWL : 195 ELEVATION(FT FROM MSL O) KELLY BUSHING: 57. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 17. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7.000 11888.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUMBER: PASS NUFI~ER : DATE LOGGED: 2-SEP-83 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 11701.0 11682.0 11674.5 11669.0 11651.5 11642.0 11633.5 11601.5 11599.5 11594.5 11586.5 11575.0 11574.5 11557.0 11555.5 11550.5 11547.5 11546.5 11537.0 11515.5 11515.0 11485.0 11483.5 11479.0 11454.5 11454.0 11428.0 11417.0 11374.0 11371.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88888.0 88888.5 11701.5 11682.0 11682.0 11674.5 11669.0 11651.5 11643.0 11634.0 11603.5 11600.5 11594.5 11586.0 11574.5 11574.5 11557.0 11556.5 11551.5 11547.5 11547.5 11538.0 11538.5 11517.5 11517.0 11487.0 11487.0 11481.5 11481.5 11457.0 11457.0 11431.0 11419.5 11375.0 11373.0 102.0 101.0 CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 04-20 ON 8-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GAMFiA RAY PROVIDED BY THE CLIENT (GR.DIL) ; AND RST SIGMA-MODE PASS #1 SIGM TO GR.DIL. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: **** FILE HEADER **** FILE NAlVlE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE19II~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMb~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11692.0 11370.0 RST 11712.0 11370.0 $ CURVE SHIFT DATA - PASS TO PASS (M~Jhg~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NTgM~ER : .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST ............................ THIS FILE CONTAINS THE CLIPPED ANDDEPTHCORRECTEDDATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1160729 O0 000 O0 0 1 1 1 4 68 NBAC RST CPS 1160729 O0 000 O0 0 1 1 1 4 68 FBAC RST CPS 1160729 O0 000 O0 0 1 1 1 4 68 SBNA FIL CU 1160729 O0 000 O0 0 1 1 1 4 68 SFNA FIL CU 1160729 O0 000 O0 0 1 1 1 4 68 SBFA FIL CU 1160729 O0 000 O0 0 1 1 1 4 68 SFFA FIL CU 1160729 O0 000 O0 0 1 1 1 4 68 TRAT FIL 1160729 O0 000 O0 0 1 1 1 4 68 IRAT FIL 1160729 O0 000 O0 0 1 1 1 4 68 CIRNFIL 1160729 O0 000 O0 0 1 1 1 4 68 CIRF FIL 1160729 O0 000 O0 0 1 1 1 4 68 BSALRST PPK 1160729 O0 000 O0 0 1 1 1 4 68 SIBF RST CU 1160729 O0 000 O0 0 1 1 1 4 68 TPHI RST PU-S 1160729 O0 000 O0 0 1 1 1 4 68 SFFC RST CU 1160729 O0 000 O0 0 1 1 1 4 68 SFNC RST CU 1160729 O0 000 O0 0 1 1 1 4 68 SIGM RST CU 1160729 O0 000 O0 0 1 1 1 4 68 DSIG RST CU 1160729 O0 000 O0 0 1 1 1 4 68 FBEF RST UA 1160729 O0 000 O0 0 1 1 1 4 68 CRRARST 1160729 O0 000 O0 0 1 1 1 4 68 GRCH RST GAPI 1160729 O0 000 O0 0 1 1 1 4 68 TENS RST LB 1160729 O0 000 O0 0 1 1 1 4 68 CCL RST V 1160729 O0 000 O0 0 1 1 1 4 68 GR DIL GAPI 1160729 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: DEPT. 11841.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST -999.250 TENS.RST DEPT. 11350.000 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST -999.250 TENS.RST -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 250 FBAC.RST 250 SFFA.FIL 250 CIRF. FIL 250 SFFC. RST 250 FBEF.RST 250 CCL.RST 250 FBAC. RST 250 SFFA.FIL 250 CIRF. FIL 250 SFFC.RST 250 FBEF.RST 250 CCL.RST -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 GR.DIL -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 GR.DIL -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 27 953 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUI4~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREFIENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11692.0 11378.0 RST 11712.0 11378.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11700 0 11690 5 11689 0 11681 5 11681 0 11670 0 11665.0 11664.5 11655.0 11648.0 11646.5 11643.0 11639.0 11632.0 11622.0 11614.5 11604.0 11598.5 11594.5 11592.0 11579.0 11575.0 11574.0 11568.0 11556.5 11553.0 11547.5 11547.0 11537.0 11517.0 11515 5 11507 5 11498 0 11485 0 11484 5 11479 5 11479.0 11465.5 11455.5 11454.5 11432.0 11417.5 11416.0 11393.5 11386.5 100.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88889.0 88889.5 11690.0 11682.0 11671.0 11665.0 11655.5 11648.0 11644.0 11639.0 11623.0 11604.0 11594.5 11575.0 11554.0 11547.5 11538.0 11519.0 11517.0 11486.5 11481.5 11457.5 11419.5 11395.5 102.0 11701.5 11691.5 11681.5 11665.5 11648.0 11633.0 11616.5 11600.5 11593.5 11579.0 11574.5 11567.5 11556.5 11547.5 11538.5 11509.0 11501.0 11487.0 11481.0 11467.5 11457.0 11434.5 11418.0 11387.5 101.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #2 GRCH TO RST SIGMA- MODE PASS #1 GRCH; AND RST SIGMA-MODE PASS #2 SIGM TO RST SIGMA-MODE PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAlVlE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160729 00 000 00 0 2 1 1 4 68 0000000000 NBAC RST CPS 1160729 00 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 8 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~ SAMP ELEM CODE (HEX) BSALRST PPK 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1160729 O0 000 O0 0 2 1 I 4 68 0000000000 SFFC RST CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1160729 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11713.500 NBAC.RST 2754.748 FBAC.RST 3425.637 SBNA.FIL SFNA.FIL 24.155 SBFA.FIL 42.284 SFFA.FIL 20.256 TRAT. FIL IRAT. FIL 0.498 CIRN. FIL 1.041 CIRF. FIL 2.015 BSAL.RST SIBF.RST 32.625 TPHI.RST 30.142 SFFC. RST 17.445 SFNC.RST SIGM. RST 17.499 DSIG.RST 2.196 FBEF. RST 69.505 CRRA.RST GRCH. RST -999.250 T}{NS.RST 1558.000 CCL.RST 0.000 DEPT. 11379.000 ArBAC.RST 2170.232 FBAC. RST 2969.519 SBNA.FIL SFNA.FIL 16.368 SBFA.FIL 48.062 SFFA.FIL 13.543 TRAT. FIL IRAT. FIL 0.535 CIRN. FIL 1.131 CIRF. FIL 2.894 BSAL.RST SIBF.RST 29.866 TPHI.RST 10.108 SFFC. RST 10.030 SFNC.RST SIGM. RST 10.029 DSIG.RST -1.145 FBEF. RST 56.168 CRRA.RST GRCH.RST -999.250 TENS.RST 1464.000 CCL.RST -0.244 51.187 1.025 30.087 20.148 1.987 57.101 O. 727 22.269 8. 742 1. 857 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS--ERS 1, 2, RST $ ~S: THE ARITH~ETIC AVERAGE OF THE TWO RST SIGMA-MODE PASSES WAS CALCULATED AFTER CLIPPING ANDDEPTHCORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 10 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1160729 O0 000 O0 0 3 1 1 4 68 NBAC RST CPS 1160729 O0 000 O0 0 3 1 1 4 68 FBAC RST CPS 1160729 O0 000 O0 0 3 1 1 4 68 SBNA RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 SFNA RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 SBFA RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 SFFA RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 TRAT RSAV 1160729 O0 000 O0 0 3 1 1 4 68 IRAT RSAV 1160729 O0 000 O0 0 3 1 1 4 68 CIRN RSAV 1160729 O0 000 O0 0 3 1 1 4 68 CIRF RSAV 1160729 O0 000 O0 0 3 1 1 4 68 BSAL RSAV PPK 1160729 O0 000 O0 0 3 1 1 4 68 SIBF RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 TPHI RSAV PU-S 1160729 O0 000 O0 0 3 1 1 4 68 SFFC RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 SFNC RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 SIGM RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 DSIG RSAV CU 1160729 O0 000 O0 0 3 1 1 4 68 FBEF RSAV UA 1160729 O0 000 O0 0 3 1 1 4 68 CRRA RSAV 1160729 O0 000 O0 0 3 1 1 4 68 GRCH RST GAPI 1160729 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 11712. 500 NBAC.RST 2520. 915 FBAC.RST 3362. 613 SBNA. RSAV SFNA.RSAV 23.355 SBFA.RSAV 44.065 SFFA.RSAV 20.190 TRAT. RSAV IRAT. RSAV O. 487 CIRN. RSAV 1 . 038 CIRF. RSAV 2. 081 BSAL. RSAV SIBF.RSAV 35. 496 TPHI.RSAV 31. 046 SFFC.RSAV 17. 341 SFNC. RSAV SIGM. RSAV 17. 332 DSIG.RSAV 1 . 948 FBEF.RSAV 69. 776 CRRA. RSAV GRCH. RST - 999.250 50.088 1.026 38.143 19.241 2.015 DEPT. 11371 . 000 NBAC.RST 2226. 344 FBAC. RST 2987. 344 SBNA. RSAV -999. 250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE :' FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREFiENT : 0.5000 FILE SUFk~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11736.5 11282.0 RST $ LOG HEADER DATA DATE LOGGED: 8 -MAY- 98 SOFTWARE VERSION: 8C0-609 TIME LOGGER ON BOTTOM: 2205 8-MAY-98 TD DRILLER (FT) : 11725.0 TD LOGGER (FT) : 11727.0 TOP LOG INTERVAL (FT) : 11450.0 BOTTOM LOG INTERVAL (FT) : 11727.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CGRS-A 862 RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 12 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 11888.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: This log was depth referenced to a SWS BHCS, dated 2-Sep-1983 Logging Program: Interval is 11727'-11450' Sigma Pass #1 @ 1800 FPH from Sigma Pass #2 @ 1800 FPH from C/O PASS #1 ® 175 FPH C/O PASS #2 ~ 175 FPH C/O PASS #3 @ 175 FPH LOGGING PROGRAM ACQUIRED FROM TOWN ALL DEPTH CORRELATIONS AND TIE-INS WITNESSED BY CO. REP. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NI]M~ SAMP ELEM CODE (HEX) DEPT FT 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1F/HR 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NPHVPS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RCAKPS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PSi S 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PS1 UA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) GDCU PS1 MA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 EXCUPS1 UA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 XP5V PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 X~2V PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 Ri~LC PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMSIG CU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 15 NAF~E SERV UNIT SERVICE API API API API FILE ~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) RDIX PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PS1 KHZ 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 KHZ 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TAV PS1 KV 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 FICU PS1 AMP 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CACUPS1 AMP 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PS1 V 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 1160729 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 DEPT. NPDE. PS1 AQTM. PS1 C~2 V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 11736.500 1558.076 0.661 -12.231 0 000 2 163 160 645 34 763 35 012 5 050 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6.679 64.453 2.622 -999.250 11281.500 1562.234 1.322 -12.221 0.000 2.236 160.645 CS.PS1 NSCE. PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 R3~C. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUST. PSi TPHI.SIG 1928. 227 2. 720 201. 823 0.000 0.000 0.253 37.500 69 814 1 152 12 056 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 61671.000 63.965 3.000 -999.250 TENS. PSi 1176.000 NPHV. PS1 CRRA.PS1 2.008 NSCR.PS1 CP5V. PS1 5.069 CP2V. PS1 RCLC. PS1 0.000 RCRC. PS1 FPHV. PS1 1494.142 FPDE. PS1 AQTF. PS1 0.661 SF6P.PS1 GDCU. PS1 59.684 EXCU. PS1 NPGF. PS1 0.997 FPGF. PS1 MARC. PSI 0.000 XHV. PS1 X~2V. PS1 -12.250 RXFR.PS1 RXAK. PS1 0.000 SHCU. PS1 CIRN. PS1 -999.250 CIRF. PS1 DSIG.PS1 -999.250 FBAC. PS1 NBAC. PS1 -999.250 SFNA.PS1 SBFA. PS1 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS1 SIGM. PS1 -999.250 SIBF. SIG TRAT. SIG -999.250 TRAT. FIL CRNI.PS1 448.571 CRFI.PS1 TAV. PS1 95.031 FICU. PS1 BUSP. PS1 3.000 RSXS.PS1 CCLC. PS1 0.029 RSCS.PS1 1557.618 -0.249 12.187 0.000 1485 940 117 579 1 973 0 992 2OO 854 0 000 37 398 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 223.357 2.505 8878.000 8463.000 CS.PS1 1824.463 TENS.PSi 1537.000 NPHV. PS1 1558.839 NSCE. PS1 2.756 CRRA.PS1 1.954 NSCR.PS1 -0.335 CHV. PS1 201.581 CP5V. PS1 5.060 CP2V. PS1 12.151 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1496.583 FPDE. PS1 1490.594 FSCR.PS1 -0.094 AQTF. PS1 1.322 SF6P. PS1 118.910 BMCU. PS1 34.472 GDCU. PS1 59.946 EXCU. PS1 3.551 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 16 NBEF. PS1 30.855 FBEF. PS1 60.301 NPGF. PS1 BSTR.PS1 37.269 BSPR.PS1 1.059 MARC.PSi XP5V. PS1 5.049 XP2V. PS1 12.056 XPI2V. PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 BSAL.PS1 27.674 BSAL.SIG 2.612 CIRN. PS1 CIRN. FIL 1.105 CIRF. FIL 2.899 DSIG.PS1 IRAT. PS1 0.507 IRAT. FIL 0.508 NBAC. PS1 SFFA.PS1 14.002 SBNA.PS1 57.364 SBFA.PS1 SFFA.SIG 0.253 SBNA.SIG 3.115 SBFA.SIG SFFA.FIL 13.864 SBNA.FIL 55.170 SBFA.FIL SFNC.PS1 10.353 SFFC.PS1 10.579 SIGM. PS1 SIGM. SIG 0.154 TRAT. PS1 0.755 TRAT. SIG GR.PS1 20.908 RDIX. PS1 72906.000 CRNI.PS1 CTM. PS1 64. 209 XTM. PS1 64. 095 TAV. PS1 CACU. PS1 2. 609 BUST. PS1 3. 000 BUSP. PS1 TPHI.PS1 12.223 TPHI.SIG O. 432 CCLC.PS1 1. 002 0 000 -1~ 251 0 000 1 109 -0 557 2224 205 42 483 4 408 43. 166 10. 515 O. 011 436. 824 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PSl SIBF. SIG TRAT.FIL CRFI.PS1 94.993 FICU. PS1 3.000 RSXS.PS1 -999.250 RSCS. PS1 0.989 200.693 0.000 38.980 2.942 2998.040 17.274 0.315 17.403 31.771 0.923 0.755 223.511 2.460 8878.000 8463.OOO ** END OF DATA ** **** FILE TRAILER **** FILE NAI~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUI4BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 2 DEPTH INCREMENt: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 11728.0 11283.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 17 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8-MAY-98 8C0- 609 2205 8-MAY-98 11725.0 11727.0 11450.0 11727.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A 862 RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11888.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): ~ COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: This log was depth referenced to a SWS BHCS, LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 18 dated 2-Sep-1983 Logging Program: Interval is 11727'-11450' Sigma Pass #1 @ 1800 FPH from Sigma Pass #2 @ 1800 FPH from C/O PASS #1 @ 175 FPH C/O PASS #2 @ 175 FPH C/O PASS #3 ® 175 FPH LOGGING PROGRAM ACQUIRED FROM TOWN ALL DEPTH CORRELATIONS AND TIE-INS WITNESSED BY CO. REP. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELI~4 CODE (HEX) DEPT FT 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 NPDE PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 19 NA~ SERV UNIT SERVICE API API API API FILE NUM~ NUF1B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) AQTMPS2 S 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CP5V PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 FSCR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 SF6P PS2 PSIG 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 BMCUPS2 UA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS2 UA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 FPGF PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 XHV PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 XFi2V PS2 V 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 RXFR PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 BSALPS2 PPK 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 BSALSIG PPK 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRF FIL 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 IRAT PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1160729 O0 000 O0 0 $ 1 1 4 68 0000000000 SBNA PS2 CU 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 2O NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP EL~ CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1160729 SFFA SIG CU 1160729 SBNA SIG CU 1160729 SBFA SIG CU 1160729 SFNA FIL CU 1160729 SFFA FIL CU 1160729 SBNA FIL CU 1160729 SBFA FIL CU 1160729 SIBF PS2 CU 1160729 SFNC PS2 CU 1160729 SFFC PS2 CU 1160729 SIGM PS2 CU 1160729 SIBF SIG CU 1160729 SIGM SIG CU 1160729 TRAT PS2 1160729 TRAT SIG 1160729 TRAT FIL 1160729 GR PS2 GAPI 1160729 RDIX PS2 1160729 CRNI PS2 KHZ 1160729 CRFI PS2 ~qZ 1160729 CTM PS2 DEGC 1160729 XTM PS2 DEGC 1160729 TAV PS2 KV 1160729 FICU PS2 AMP 1160729 CACU PS2 AMP 1160729 BUST PS2 1160729 BUSP PS2 1160729 RSXS PS2 1160729 TPHI PS2 PU 1160729 TPHI SIG PU 1160729 CCLC PS2 V 1160729 RSCS PS2 1160729 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 ! 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 ~ 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE.PS2 HVPV. PS2 NBEF. PS2 BSTR. PS2 XPSV. PS2 RX~C. PS2 BSAL. PS2 CIRN. FIL 11728.000 1562.272 0.661 -12.250 0.000 2.153 160.889 34.564 29.674 5.050 0.000 -999.250 -999.250 CS. PS2 2455.662 TENS. PS2 1453.000 NPHV. PS2 NSCE. PS2 2.733 CRRA.PS2 2.009 NSCR.PS2 CHV. PS2 201.339 CPSV. PS2 5.040 CP2V. PS2 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RTDF. PS2 0.000 FPHV. PS2 1496.583 FPDE. PS2 FSCR.PS2 -0.318 AQTF. PS2 0.661 SF6P. PS2 BMCU. PS2 38.086 GDCU. PS2 60.668 EXCU. PS2 FBEF. PS2 69.429 NPGF. PS2 1.000 FPGF. PS2 BSPR. PS2 1.215 MARC. PS2 0.000 XHV. PS2 XP2V. PS2 12.056 ~2~2V. PS2 -12.250 RXFR.PS2 RXRC. PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.SIG -999.250 CIRN. PS2 -999.250 CIRF. PS2 CIRF. FIL -999.250 DSIG. PS2 -999.250 FBAC. PS2 1562.501 0.570 12.217 0.000 1488.610 119.114 1.973 0.999 200.612 0.000 34.796 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 21 IRAT.PS2 -999.250 IRAT. FIL -999.250 NBAC. PS2 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC.PS2 -999.250 SFFC.PS2 -999.250 SIGM. PS2 SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT. SIG GR.PS2 53.835 RDIX.PS2 75816.000 CRNI.PS2 CTM. PS2 63.965 XTM. PS2 63.965 TAV. PS2 CACU. PS2 2.612 BUST. PS2 3.000 BUSP.PS2 TPHI.PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 DEPT. 11282.500 CS.PS2 NPDE. PS2 1561.547 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.231 RCFR.PS2 RCAK.PS2 3.000 RTDF. PS2 FSCE.PS2 2.180 FSCR.PS2 HVPV. PS2 160.662 BMCU. PS2 NBEF.PS2 30.448 FBEF. PS2 BSTR.PS2 38.507 BSPR.PS2 XP5V. PS2 5.050 XP2V. PS2 RXLC.PS2 0.000 RXRC. PS2 BSAL.PS2 22.555 BSAL.SIG CIRN. FIL 1.109 CIRF. FIL IRAT. PS2 0.541 IRAT. FIL SFFA.PS2 13.565 SBNA.PS2 SFFA.SIG 0.287 SBNA.SIG SFFA.FIL 13.873 SBNA.FIL SFNC. PS2 8.927 SFFC. PS2 SIGM. SIG 0.157 TRAT. PS2 GR.PS2 17.898 RDIX. PS2 CTM. PS2 64.453 XTM. PS2 CACU. PS2 2.610 BUST.PS2 TPHI.PS2 9.549 TPHI.SIG 1883.851 TENS.PS2 2.750 CRRA.PS2 201.339 CP5V. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 0.015 AQTF. PS2 33.838 GDCU. PS2 58.761 NPGF. PS2 1.057 MARC. PS2 12.066 X~2V. PS2 0.000 RXAK. PS2 2.704 CIRN. PS2 2.859 DSIG.PS2 0.539 NBAC.PS2 59.914 SBFA.PS2 2.841 SBFA.SIG 57.014 SBFA.FIL 10.319 SIGM. PS2 0.717 TRAT. SIG 86661.000 CRNI.PS2 64.383 TAV. PS2 3.000 BUSP. PS2 0.399 CCLC. PS2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 448.841 95.031 3.000 -0.010 1476.000 1.930 5.050 0.000 1496.583 0.661 59.754 O.999 0.000 -12.247 0.000 1.115 -1.045 2185.918 51.008 5.434 47.541 10.347 0.011 431.774 95.031 3.000 -999.250 SFNA. PS2 SFNA. SIG SFNA. FIL SIBF. PS2 SIBF.SIG TRAT.FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC.PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF.PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF.PS2 FBAC.PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 223 447 2 515 8878 000 8463 000 1555.177 -0.631 12.217 0.000 1490.899 119.699 4.002 0.997 200.733 0.000 39.395 2. 838 2965. 063 16. 711 0.278 16.754 29.967 0.950 0.720 223.731 2.451 8878.OOO 8459,000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-SEP-1998 17:13 PAGE: 22 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/ 3 ORIGIN : FLIC TAPE NAME : 98341 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA, INC, DS 04-20, PRUDH. OE BAY, # 50-029-20996-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/09/ 3 ORIGIN : FLIC REEL NAME : 98341 CONTINUATION # : PREVIOUS REEL : COM~IENT : ARCO ALASKA, INC, DS 04-20, PRUDHOE BAY, # 50-029-20996-00 I.,TS "FAPK VEI; I. F ! 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