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Home My WebLink About193-0097. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU AGI-06 Install new completion & patch csg Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-009 50-029-22333-00-00 ADL 0028301 11200 Conductor Surface Intermediate Production Liner 8468 76 4066 10547 764 10425 20" 13-3/8" 9-5/8" 7" 7931 38 - 114 37 - 4103 36 - 10583 10434 - 11198 2600 39 - 115 37 - 3511 36 - 8039 7937 - 8466 none 470 2260 4760 7020 10425 1490 5020 6870 8160 10817 - 11130 7" x 5-1/2" NT80s x L-80 33 - 104378200 - 8418 Structural 5-1/2" Baker SB-3 , 10357 , 7884 7 Camco WRDP-2 SSV , 2016 , 1959 2016, 1959 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 1-15-2026 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:46 am, Oct 21, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.10.17 13:28:53 - 08'00' Bo York (1248) 325-654 AOGCC witnessed BOP test to 4000 psi, Annular to 3500 psi. AOGCC witnessed MITIA to 4000 psi on rig after running completion. AOGCC witnessed MITIA post-stabilized injection. DSR-10/30/25 10-404 A.Dewhurst 30OCT25 X X J.Lau 11/03/25 11/03/25 RWO AGI-06 PTD: 193009 Well Name:AGI-06 API Number:50-02922333-00 Current Status:Shut-In Rig:Hilcorp Innovation Estimated Start Date:01/15/2026 Estimated Duration:11 days Reg.Approval Reqstd?10-403, 404 Date Reg. Approval Recvd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:193009 First Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer:Jerry Lau 907-564-5280 907-360-6233 Current Bottom Hole Pressure:3,480 psi @ 8,800 TVD 7.6 PPGE | calc from shut in WHP Max. Anticipated Surface Pressure:2,600 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,750 psi (Taken on 08/23/25, well shut in 8/15/25) Min ID:4.455 ID XN nipple @ 10,425 MD Max Angle:48 Deg @3,406 Brief Well Summary: AGI-06 was drilled in April 1993 and completed as a 7 monobore injector. An MIT-IA failed in August 15 th. A plug was set and the tubing was MIT-T to 2,700-psi, a CMIT-TxIA failed at 0.25bpm @ 800-psi. An LDL indicated a leakpoint at 8,042. The wellbore is currently loaded with 9.0 ppg completion fluid with a diesel freeze protect. We will now pursue a RWO to repair the PC leak and install a stacker packer completion with new injection tubing. Objective: Pull the existing 7 Injection tubing. Isolate leak (8,042ft) with test packer. Install the lower completion (PBR and packer). Set expandable clad across leak at 8,042ft. Run new 7 and 7-5/8 Injection tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD MIT-T 4,000-psi Cycle LDSs PPPOT-T 5,000-psi Slickline - Set junk catcher on PX plug. E-line/Fullbore -Cut tubing with welltech mechanical cutter at 10,314ft (10ft down on first full joint of tubing). Attempt to circ out wellbore with 9.8ppg brine and diesel cap (tubing may be in compression and will not allow circulation). Punch tubing if necessary. Valve Shop Set and test J TWC Pull wellhouse and injection line. RWO AGI-06 PTD: 193009 Proposed RWO Procedure: 1. MIRU Hilcorp Innovation Rig. 2. ND Tree and NU 13-5/8 BOPE with four preventers configured top down (annular, 2-7/8 x 5-1/2 VBRs, blinds, mud cross and 7 fixed rams. 3. Test BOPE to 250psi Low/4,000psi High, annular to 250psi Low/3,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Hilcorp Innovation BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8 x 5-1/2 VBRs with 5 test joint. Test the Annular preventer with a 5 test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC. Use lubricator is pressure is expected. 5. MU landing joint or spear (lift threads are 7 NSCC), BOLDS and pull hanger to the floor. PU weights are expected to be ~195K. Rig up control line spooler. There are two encapsulated ¼ control lines secured with 28 stainless steel bands. 6. Pull 7 tubing to floor, circulate bottoms up. LD 7 tubing. 7. RIH with drift / cleanout assembly in prep for running the expandable clad. 8. PU 5 DP with 9-5/8 RTTS. RIH and test above and below the casing leak at 8,042ft to4,000psi 9. RIH with lower completion packer and PBR, on PBR running tool. 10. Drop 1-7/8 ball-n-rod and set packer at ~10,208ft. 11. POOH with PBR running tool. SBDP 12. RIH Metal skin expandable clad assembly. Set clad across leak at 8,042ft. 13. MIT wellbore to 4,000-psi. 14. POOH LDDP 15. Set a test plug and change the upper rams to 7-5/8 fixed and test to 4,000-psi. Pull test plug. Notify AOGCC 24hrs before testing. 16. Run 7 x 7-5/8 L-80 Injection tubing with seal assembly as detailed on proposed schematic. 17. Reverse in corrosion inhibited 9.8ppg brine and diesel FP. 18. Land tubing hanger. 19. Perform MIT-T to 4,000 psi and MIT-IA to 4,000 psi for 30 charted minutes. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 20. Set TWC 21. ND BOPE and NU 7 tree and adapter. 22. Test the tree and adapter void to 5,000-psi. 23. Rig down Hilcorp Innovation. Post Rig Work 1. Pull Ball and rod and RHC profile, pull junk catcher, pull X plug. Set WRDP-2 Injection valve in landing nipple at 2,200ft. 2. Reconnect injection lines and set wellhouse. Stabilized MIT-IA to 2,500-psi. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 RWO AGI-06 PTD: 193009 Attachments: 1. Wellbore Schematic 2. Existing Tally 3. Proposed Wellbore Schematic 4. BOP Drawing 5. MOC form RWO AGI-06 PTD: 193009 Wellbore Schematic 8,042ft LLR 0.25bpm at 800 psi RWO AGI-06 PTD: 193009 Existing Tally RWO AGI-06 PTD: 193009 Proposed Wellbore Schematic RWO AGI-06 PTD: 193009 Innovation Rig BOPs Innovation Rig Choke Manifold RWO AGI-06 PTD: 193009 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-06 PRUDHOE BAY UNIT AGI-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 AGI-06 50-029-22333-00-00 193-009-0 G SPT 7884 1930090 1971 3389 39 4YRTST F Guy Cook 8/15/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. Could not get the well to test pressure. At 1000 psi the well was leaking at approximately 1 bbl/minute. The well was shut in. 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 AGI-06 Inspection Date: Tubing OA Packer Depth 442IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250815170823 BBL Pumped:BBL Returned: Tuesday, September 23, 2025 Page 1 of 1         Hilcorp requested to send TIO pressure plots for past 30 days and past year for review - J. Regg, 9/22/2025 From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Date:Tuesday, September 23, 2025 3:11:42 PM Attachments:AGI-06.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, September 23, 2025 10:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Mr. Wallace, Please see attached 1 year and 90 day TIO plots for AGI-06 as requested. AGI-06 is an emergency field fuel gas well that remains online as much as practical to provide backflow for field restart in the event of a field shutdown. As such, there is minimal annular fluid expansion bleeds related to well start / stop on AGI-06 though it is susceptible to changes in IA and OA pressure due to ambient or injection temperature changes. Specific to AGI, the typical gas injection temperature is ~70° F – 100° F during routine operations. When the gas compression facility has an operational upset, the injection gas temperature at AGI will increase rapidly closer to 160° F, which causes pressure to increase on the annuli. Operators try to maintain low IA and OA pressures on AGI injection wells to give themselves more response time to an operational upset. All of this to say, annulus pressure bleeds at AGI are common post routine operational upsets or in the summer with ambient temperature increases or injection temperature increases. The need for the operator to bleed the IA pressure on 06/12/25 and 06/13/25 from ~500 psi to 300 psi was not abnormal as ambient temperatures from 6/11-6/13 increased from 46 degF to 51 degF to 60 degF over the course of those days. Nor was the bleed response abnormal where the pressure was able to be bled in 10 minutes. A typical anomalous PC leak bleed response is that the sustained pressure is unable to be bled down at surface, which did not occur here according to the operator record of the event. Operator notes / Well service records for AGI-06 09/22/24-09/22/25 in bold, well status changes italicized. 11/11/24: Shut in for CCP high stage issues. BOI once issues were fixed 01/22/25: Bled IAP to 100 psi 05/26/25: State tested: Passed 06/12/25: Bled IAP from 470 to 300 psi 10 mins .25 bbls, bled OAP from 170 psi to 25 psi in 10 mins 06/13/25: Bled IAP form 470 psi to 300 psi in 10 mins .25 bbls. 07/27/25: IA FL @ surface pre AOGCC MIT-IA T/I/O – 3450/450/60 08/15/25: AOGCC MIT-IA failed, LLR 1 BPM @ 1000 psi. Well shut in 08/16/25: Well status changed to under evaluation. AOGCC notification sent with plan for secure/ diagnostics.. 08/24/25: TTP set MIT-T Passed CMIT-TxIA Failed 8/26/25: Well status changed to not operable. AOGCC notification sent. 08/27/25: LDL ID PC leak @ 8042’ MD Our daily exception reports for identifying annular communication issues on injection wells flag the following scenarios. Injectors bled in the past 7 days Injectors bled 2 or more times in the past 30 days Online injectors with IA > 1000 psi Online injectors with TxIA differential pressure < 250 psi Online injectors with IAxOA differential pressure < 100 psi AGI-06 flagged on the compliance report sections for injectors bled in the past 7 days and injectors bled 2 or more times in the past 30 days on 6/14/25. Again, noting the increased ambient temperatures during that period gas injector bleeds are common. The compliance report on 6/14/25 flagged 26 wells as being bleed in the last 7 days, 12 wells for 2 or more bleeds in the last 30 days with 17 gas injectors having been bled on 6/13/25, all for what was deemed at the time to be thermal pressure responses due to the large increase in ambient temperature over the previous few days. After the failing MIT-IA on AGI-06, I did look at all the TIO plots for the other gas injection wells in Prudhoe with a similar trend as far as IA casing pressure relatively static between 400 psi – 600 psi and found no other examples. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 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. M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 22, 2025 1:19 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Andy/Ryan, Please provide the 90 day TIO, and 1 year TIO plot, including bleeds or additional activity details, and also your explanation of why this pressure communication was not in effect before the testing confirmed it. 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, August 26, 2025 12:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Mr. Wallace, Slickline set a TTP on 08/24 and performed a passing MIT-T. As expected, a subsequent CMIT-TxIA failed. The well is now classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity Sent: Saturday, August 16, 2025 3:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed Mr. Wallace, Gas injector AGI-06 (PTD #193009) failed AOGCC witnessed MIT-IA on 08/15 as the pump was unable to reach test pressure, indicating a failed secondary well barrier. AGI- 06 was shut in. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. A secure / diagnostics program will be drafted and executed. 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. 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, 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 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: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Date:Tuesday, August 26, 2025 1:45:21 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 26, 2025 12:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed - secured with TTP Mr. Wallace, Slickline set a TTP on 08/24 and performed a passing MIT-T. As expected, a subsequent CMIT-TxIA failed. The well is now classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity Sent: Saturday, August 16, 2025 3:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed Mr. Wallace, Gas injector AGI-06 (PTD #193009) failed AOGCC witnessed MIT-IA on 08/15 as the pump was unable to reach test pressure, indicating a failed secondary well barrier. AGI- 06 was shut in. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. A secure / diagnostics program will be drafted and executed. 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 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: UNDER EVALUATION: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed Date:Monday, August 18, 2025 9:22:42 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, August 16, 2025 3:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector AGI-06 (PTD #193009) AOGCC MIT-IA Failed Mr. Wallace, Gas injector AGI-06 (PTD #193009) failed AOGCC witnessed MIT-IA on 08/15 as the pump was unable to reach test pressure, indicating a failed secondary well barrier. AGI-06 was shut in. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. A secure / diagnostics program will be drafted and executed. 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 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. MEMORANDUM TO: Jim Regg P.I. Supervisory FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -06 PRUDHOE BAY UNIT AGI -06 Sre: Inspector Reviewed By: P.I. Suprvj Comm Well Name PRUDHOE BAY UNIT AGI -06 API Well Number 50-029-22333-00-00 Inspector Name: Brian Bixby Permit Number: 193-009-0 Inspection Date: 8/4/2021 Insp Num: mitBDB210804151518 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1 Well AGI -06 Type Inj G ITVD "Test 7884 --' Tubing 3283 3284 - 3285- 3288 ' 221��2176 2166 ' PTD 1930090 Type SPT set psi tg Te BBL Pumped: 7.5 :BBL Returned: ��i 1971 IEj 285 4.5' ! p� 44 86 85 84— Interval - - _— 4YRTST P/F - Notes: Thursday, August 5, 2021 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:193-009 6.50-029-22333-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11200 11176 8451 10357 , 104417 none none 7884 , 7942 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 38 - 114 38 - 114 1490 470 Surface 4065 13-3/8" 37 - 4103 37 - 3512 5020 2260 Intermediate Production 10547 9-5/8" 36 - 10583 36 - 8039 6870 4760 Perforation Depth: Measured depth: 10817 - 11130 feet True vertical depth:8200 - 8418 feet Tubing (size, grade, measured and true vertical depth)7 x 5-1/2" NT 80 x L-80 33 - 10437 / 33 - 7939 Packers and SSSV (type, measured and true vertical depth) Liner 764 7" 10434 - 11198 7937 - 8466 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 34728900 0226287 89 265474 0 3380 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David. Bjork@ hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8468 Sundry Number or N/A if C.O. Exempt: 320-466 7 Camco WRDP-2 SSV 2016 1959 Junk Packer Printed and Electronic Fracture Stimulation Data 5 water wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034628 & 028301 PBU AGI-06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.08 09:56:35 -09'00' Bo York By Samantha Carlisle at 12:23 pm, Dec 08, 2020 SFD 12/9/2020DSR-12/9/2020 RBDMS HEW 12/9/2020 MGR04FEB2021 ACTIVITYDATE SUMMARY 11/16/2020 Tbg Flush (TUBGING WASH/PICKLE) Pumped 10 bbls 60/40 meth, 50 bbls 120* DSL and 359 bbls 140* fresh water w/ F-103 down Tbg. Let soak for 2 hours. Pumped 216 bbls 140* fresh water w/ F-103 and 15 bbls 60/40 meth down Tbg. DSO notified to bring well back on injection. SV,WV=C SSV,MV=O IA,OA=OTG Daily Report of Well Operations PBU AGI-06 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:193-009 6.API Number:50-029-22333-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034628 Property Designation (Lease Number):10. n/a 8. PBU AGI-06 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown water wash Op Shutdown GAS GSTORWAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11200 Effective Depth MD: NT80 x L-80 11. 11-7-2020 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7 Camco WRDP-2 SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8468 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10357 , 7884 / 10441, 7942 2016, 1959 Date: Liner 764 7" 10434 - 11198 7937 - 8466 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 4103 37 - 3512 14. Estimated Date for Commencing Operations: BOP Sketch 38 - 114 Structural Proposal Summary 13. Well Class after proposed work: 5-1/2" Baker SB-3 & 7" Baker H Isolation 10817 - 11130 8200 - 8418 7" x 5-1/2"33 - 10437 Production 11176 8451 none none 39 - 115 470 13-3/8" Contact Phone:907-564-4672 Date: 10/26/2020 76 149020"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4065 5020 Intermediate 10547 9-5/8" 36 - 10583 36 - 8039 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:15 am, Oct 29, 2020 320-466 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.29 08:24:37 -08'00' Bo York ; ADL 0028301 DLB 29OCT2020 10-404X DLB 10/29/2020 DSR-11/10/2020 Yes n Required? Comm 11/12/2020 dts 11/12/2020 JLC 11/12/2020 RBDMS HEW 11/12/2020 Well Work Prognosis Well Name:AGI-06 API Number:50-029-22333-00 Current Status:Gas Injector Leg: Estimated Start Date:Nov 7, 2020 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:193-009 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: 202,070 Mscf/Day Injection Pressure: 3,360 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): AGI-06 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2014. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 09,2017 TO: Jim Regg P.I.SupervisorS t l of to(! SUBJECT: Mechanical Integrity Tests C` BP EXPLORATION(ALASKA)INC. AGI-06 FROM: Guy Cook PRUDHOE BAY UNIT AGI-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-06 API Well Number 50-029-22333-00-00 Inspector Name: Guy Cook Permit Number: 193-009-0 Inspection Date: 8/5/2017 Insp Num: mitGDC170805184847 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-06 ' Type Inj G TVD 7884 ' Tubing 3310 - 3307 ' 3302 • 3305 • PTD 1930090 Type Test SPT Test psi 1971 IA 236 2496, 2460 - 2450 BBL Pumped: 6.4 BBL Returned: 4.8 ' OA 43 72 • 74 ' 74 - Interval 4YRTST --_P/F P Notes: MIT-IA. A fluid level shot was taken to show the fluid level at 100'. Little Red Services heated the diesel up to 100 degrees Fahrenheit before pumping to lessen the effect of thermal expansion during the testing process. ✓ SCANNED t 2 s Wednesday,August 09,2017 Page 1 of 1 . • 7"<bF �A\��7% �` THE STATE a !:r. . t,-4-----se.,i,-'-'-'-=-"'7__:-_-- _-_--) I .) .... -1: L _ ) .i . \_.,.) :'iii014.-1-:__-_,�__ -- - ---- 33:; `✓dc:st �cven'h Avenue (;ovEIZ\OR SEAN 1'A1<\1;L1. Anchorage, Alaska 995G1 3572 �� - `s � Nair C7 'i7y 1433 Javier Farinez W\- f� j` Petroleum Engineer IaNNEo 3 C7 oq BP Exploration (Alaska), 1 . P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-06 Sundry Number: 314-169 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 sir Daniel T. Seamount, Jr. Commissioner DATED this ZZ ci day of March, 2014. Encl. '- k ,w 0 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION rn,l,f1, 4 % 2611 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 -C) `-�� " 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate Q • tAlter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 11 Ut,Y3(14)4i 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 193-009-0 • 3.Address: 6.API Number. Stratigraphic ❑ Service ❑ , P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22333-00-00' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? – PBU AGI-06 ,- Will Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034628 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11200 ' 8468 • 11176 8451 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 76 20"91.5#H-40 38-114 38-114 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10547 9-5/8"47#NT8OS 36-10583 36-8039.28 6870 4760 Liner 764 7"29#NT8OS 10434-11198 7936.83-8466.25 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7 Camco WRDP-2 SSV 2016',1958.48' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑, BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑✓ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true • cor =ct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name Javier F. • -z Title Petroleum Engineer Signature �1 Phone 564-5043 Date3 _\L`\R. Prepared by Garry Catron 564-4424 COMMISSION USE ONLY lo Conditions of approval: Notify Commission so that a representative may witness Sundry Number t i"l.. \ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSV MAY 10 2014 Spacing Exception Required? Yes ❑ No © Subsequent Form Required: J/9—4 tj APPROVED BY Approved by: lilly/ COMMISSIONER THE COMMISSION Date: 312 II 4— Form 10-403 Revised 10/2012 oRrivetNi0A3 alid for 12 months from the date of approval. Submit Form and Attachments in buplicDateUri 3//1 / 14- S-Sc,fw c?F 519o1'N31�/� Perforation Attachment ADL0034628 Well Date Perf Code MD Top MD Base TVD Top TVD Base AGI-06 _ 6/14/93 PER 10817 10837 8200 8214 AGI-06 6/14/93 PER 10856 10866 8227 8234 AGI-06 _ 6/14/93 PER 10888 10898 8249 8256 AGI-06 6/14/93 PER 10963 10983 8302 8316 AGI-06 6/14/93 PER 11013 11023 8337 8344 AGI-06 6/14/93 PER 11051 11061 8363 8370 AGI-06 6/14/93 PER 11110 11130 8404 8418 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED 1 BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET 01-1 OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF CD coco Lo 0 co ) CO co Ur Z Z Z Z J cu p 0 o O o 0 0 0 0 N CD CO LO 1- CO O N- N O) 't N p • N- • N LC) CO U y 0) O ti N 1.0 Nr N- CO 0 N I� N- CO CD CCS CO N- N- a) N (0CD O) ) m V" CD CO Cr) gM O ' CO O) W O M N- Q 0 CO CO CO 000 CO Cr) M `- CO CO COC N cCU 03 (O N CO M M N N- m O M u) 00 0 7j. 0 0 Cl)13) . n HCNI 0o CO co CD N- M M U a M O M r. M C 0 Lo CD• m co 0? Lnrt 2 ZO O Z CO N Z *k o0 Z r fn 4 CD - 4 1- _• N - 00 - N NM M to M M 1� O) r L N N ti O O) ONO MO 00 J � M ! c Z _O O O I- W W U U U UOa. ou_ L. ZZ Z W O w w m m O ZrxDDDD OJn. v) COHH Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top Description TVD Top AGI-06 SSSV 2016 7 Camco WRDP-2 SSV 1958 AGI-06 PACKER 10357 5-1/2" Baker SB-3 Packer 7884 AGI-06 PACKER 10441 7" Baker H-Isolation Packer 7942 TREE "ACTUATOR= BAKER A G'-06 REQUIRES LINER NOT CEMENTED. ALL TBG IS IPC WITH KB.ELEV= 49' I NSCC THREAD. BF.ELEV= 120"CONDUCTOR H ? X KOP= 801' Mix Angle= 48 @ 3406 13-3/8"CSG,68#, H 119' 2013' —17"CAMC:O BAL-O SSSV NP,ID=5.937" Datum MD= 11707' K-55,113=12415' 1 0 Datum TVD 8800'SS 13-3/8'CSG,68#,NT-80,ID=12.415" —H 4103' HA ' 7'TBG,26#,NT-80-S-PC,NSCC,1—I 10352' - 10352' —17"X 5-1/2"XO,D=4.875' .0383 bpf,D=6.276" 10356'—{ANCHOR D=4.875" Minimum ID = 4.455" @ 10425' 10357' --I9-5/8"X 5-1/2"BKR SB-3A PKR,D=4 874" x >< 5-1/2" OTIS XN NIPPLE ' , 10404' H 5-1/2"PARKER SWS NP,D=4.562" TOP OF 7"LNR— 10422' - ' , 10425' —5-1/2"OTIS XN NP,D=4.455" 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892' H 10437' / \ 10437' H 5-1/2'WLEG,D=4.892" 10433' —ELMD TT LOGGED 05/10/93 9-5/8"CSG,47#,NT-80-S,D=8.681" — 10583' , PERFORATION SUMMARY I REF LOG'. GR CCL ON 06/08/93 ANGLE AT TOP PERF- 47'@ 10817' Note. Refer to Production DB for historical perf data i SIZE SPF I4TBWAL Opn/Sqz SI-OT SQZ 3 3/8" 6 10817- 10837 0 6/14/93 3 3/8" 6 10856- 10866 0 6/14/93 3 3/8" 6 10888- 10898 0 6/14/93 I 3 3/8" 6 10963-10983 0 '6/14/93 3 3/8" 6 11013-11023 0 '6/14/93 3 3/8" 6 11051 -11061 0 '6/14/93 3 3/8" 6 11110-11130 0 '6/14/93 I PBTD J I 11176' - 7'LNR,29#,NT-80-S, .0371 bpf,ID=6.184" — 11198' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY IJ'IT 04/27/93 LAST VVOFRKOVER WELL: AGI-06 01/26/01 SIS-LG REVISION PERMIT No:'1930090 05/22/01 R4KAK CORRECTIONS AR No 50-029-22333-00 03/13/03 AS/TP ADD PC/THREAD FOR TBG SEC 36,T12N,R14E,695.24'FEL&1674.37'FNL 02/11/11 MB/JMD ADCED SSSV SAFETY NOTE 03/11/13 PJC DRAWING CORRECTIONS _ BP Exploration • J Fullbore Pumping Program for Field Well Name AGI-06 Job Scope Select Job Scope _ Well Type GI AFE APBinjec Date 3/11/2014 IOR 30 Engineer Javier Farinez Phone 564-5043 H2S !n RPr'nrds Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate(bpm) Max Pressure 1 Pre-Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 200 5 2500 3 Load Select Fluid Type Tbg 600 5 1500 4 Freeze Protect Methanol (60/40) Tbg 10 5 1500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 200 bbls 50/50 diesel/xylene 3 600 bbls of fresh water with 0.02% F-103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level(ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level(ft) No Input Depth If Applicable Recent OA Fluid Level(ft) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 22,2013 TO: Jim Regg ��. �(z4-+(3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC AGI-06 FROM: Chuck Scheve PRUDHOE BAY UNIT AG1-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 33e NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-06 API Well Number 50-029-22333-00-00 Inspector Name: Chuck Scheve Permit Number: 193-009-0 Inspection Date: 8/18/2013 Insp Num: mitCS130819094757 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min � -- - - - - - � za76 � zaso I Well] 1Type Inj TVD 7884 � IA 638 1 2495 AGI-O6 G 1971 75 97 99 100 T e Test Test sl} " I i — 1 1930090 ,Type OA Interval 14YRTST 4P/F i P ' i Tubin 1 3202 3202 3204 ` 3203 " I I Notes: Thursday,August 22,2013 Page 1 of 1 STATE OF ALASKA • A KA OIL AND GAS CONSERVATION COMMOON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L. Repair Well ❑ Plug Perforations U Perforate U Other L] Water Wash Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 193 -009 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22333 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 ., PBU AGI -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11200 feet Plugs measured None feet RECEIVE 1 true vertical 8467.66 feet Junk measured None feet JAN 3 11 2013 Effective Depth measured 11176 feet Packer measured 10357 feet true vertical 8450.77 feet true vertical 7883.71 feet AOG CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H -40 30 - 106 30 - 106 1490 470 Surface 4075 13 -3/8" 68# NTS -80 28 - 4103 28 - 3511.75 None None Intermediate None None None None None None Production 10556 9 -5/8" 47# NT8OS 27 - 10583 27 - 8039.28 6870 4760 Liner 776 7" 29# NT8OS 10422 - 11198 7928.58 - 8466.25 8160 7020 Perforation depth Measured depth 10817 - 10837 feet 10856 - 10866 feet 10888 - 10898 feet 10963 - 10983 feet 11013 - 11023 feet 11051 - 11061 feet 11110 - 11130 feet True Vertical depth 8200 - 8213.87 feet 8227.08 - 8234 03 feet 8249.36 - 8256.33 feet 8301.63 - 8315.58 feet 8336.53 - 8343.51 feet 8363.07 - 8370.05 feet 8404.37 - 8418.41 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker SB -3 Packer 10357 7883.71 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): a p ,p (1, 20�� Treatment descriptions including volumes used and final pressure: WI AR vv 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ' ❑ Gas ❑ WDSPLIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 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: 312 -228 Contact Nita Summerhays Email Nita.Summerh b Printed Name Nita s f Title Petrotechnical Data Technician Signature A f � ;f / / % Phone 564 -4035 Date 1/31/2013 VLF RBDMS FEB 01201 ! 1 Z /i i � J �4 Submit Original Only Form 10 -404 Revised 10/2012 `� / �j� Daily Report of Well Operations ADL0034628 ACTIVITYDATE SUMMARY o= • • , S ryas I : , ry , umpe. • bbls meth followed by 205 bbls 50/50 diesel /xylene, 617 bbls FW w/ .02% F- 103 surfactant, 10 bbls meth to dissolve any salts /asphaltenes. DSO /PE notified to POI. Valve positions =SV closed WV SSV MV open CVs OTG 10/6/2012 FWHP = 0/350/40 FLUIDS PUMPED BBLS 20 METH 205 DSL /XYLENE 617 1% KCL 842 TOTAL Casing / Tubing Attachment ADL0034628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 30 - 106 30 - 106 1490 470 LINER 776 7" 29# NT80S 10422 - 11198 7928.58 - 8466.25 8160 7020 PRODUCTION 10556 9 -5/8" 47# NT80S 27 - 10583 27 - 8039.28 6870 4760 TUBING 10326 7" 26# NT80S 26 - 10352 26 - 7880.27 7240 5410 TUBING 85 5 -1/2" 17# L -80 10352 - 10437 7880.27 - 7938.9 7740 6280 s • TREE = WELL REQUIRES A SSSV. WELLHEAD= CM/ LINER NOT CEMENTED. ALL TBG IS IPC WITH ACTUATOR= BAKER AGI-06 NSCC THREAD. KB. ELEV = 49' BF. ELEV = KOP = 801' Max Angle = 48 @ 3406' Datum MD = 11707'' 2013' HT CAMCO BAL -O SSSV NIP, ID = 5.937" Datum TV D= 8800' SS 13 -3/8" CSG, 68#, K -55, ID = 12.415" I 119' I— 13 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 4103' I 7" TBG, 26 #, NT -80 -S -IPC, NSCC, 10352' .0383 bpf, ID = 6.276" I 10352' HT X 5-1/2" XO, ID = 4.875" 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I- -I 10352' 1 10356' HI ANCHOR, ID = 4.875" I X x I 1035T H9-5/8" X 5-1/2" BAKER SB -3A PKR, ID = 4.874" I Minimum ID = 4.455" @ 10425' 5 -1/2" OTIS XN NIPPLE I I I 10404' H5 -1/2" PARKERSWS NIP, ID= 4.562" I TOP OF 7" LNR 1 10422' I . ■ I I 10425' H5 -1/2" 011S XN NIP, ID = 4.455" I / \ I 10437' H 5-1/2" WLEG, ID = 4.892" I I 10433' H ELMD TT LOGGED 05/10/93 I 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 10583' I A PERFORATION SUMMARY REF LOG: GR CCL ON 06/08/93 ANGLE AT TOP PERF: 47 @ 10817 Note: Refer to Production DB for historical pert data — SIZE SPF INTERVAL Opn /Sqz DATE 3 3/8" 6 10817 - 10837 0 6/14/93 3 3/8" 6 10856 - 10866 0 6/14/93 3 3/8" 6 10888 - 10898 0 6/14/93 3 3/8" 6 10963 - 10983 0 6/14/93 3 3/8" 6 11013 - 11023 0 6/14/93 — 3 3/8" 6 11051 - 11061 0 6/14/93 3 3/8" 6 11110 - 11130 0 6/14/93 1 PBTD H 11176' I 7" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" H 11198' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/27/93 LAST WORKOVER WELL: AGI-06 01/26/01 SIS -LG REVISION PERMIT No: '1930090 05/22/01 RN /KAK CORRECTIONS API No: 50- 029 - 22333 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 695.24' FEL & 1674.37' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission ST.MINEDAUG 0 7 2012 333 West 7 Avenue Anchorage, Alaska 99501 3 0 © 1 Subject: Corrosion Inhibitor Treatments of GPB AGI �� d 9. Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • i BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI-01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI -04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 AGI-05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 ---- t -06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 AGI-07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 AGI-08 1930330 50029223480000 1.8 NA _ 1.8 NA 15.3 7/24/2011 AGI-09 1930350 50029223500000 Spit conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA • • ' j .• SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Javier Farinez Petroleum Engineer BP Exploration (Alaska), Inc. 1q3-00/ P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -06 Sundry Number: 312 -228 c�piZ SL f NED JUN 62, Dear Mr. Farinez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. P. Foerster Chair DATED this day of June, 2012. Encl. STATE OF ALASKA ` "O' " ‘ I REC GI " ED E AL, OIL AND GAS CONSERVATION COMMI•N JUN 1 9 C612 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 /A.� � 1. Type of Request: Abandon ❑ Plug for Redrill 111 Perforate New Pool ❑ Repair Well ❑ h ve Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Water Wash • is 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 193 -0090 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 . 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22333 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU AGI -06 • Spacing Exception Required? Yes III No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL- 034628 • PRUDHOE BAY Field / PRUDHOE BAY Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11200 , 8468 • 11176 8451 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H -40 30' 106' 30' 106' 1490 470 Surface 4075' 13 -3/8" 68# NTS -80 28' 4103' 28' 3511' Production 10556' 9 -5/8" 47# NT8OS 27' 10583' 27' 8039' 6870 4760 Liner 776' 7" 29# NT8OS 10422' 11198' 7928' 8466' 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# NT -80S 26 10352 - - 5 -1/2" 17# L -80 10352 10437 Packers and SSSV Tvoe: 5 -1/2" BAKER SB -3A PKR Packers and SSSV MD and TVD (ft): 10357' 7884' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/2/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ El • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Printed Name Javier Farine', Title PE Signature �// Phone Date i / 564 -5043 6/18/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 312 - -nl i , Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: ) 10 -4-04 APPROVED BY Approved by: 1 95, y --^•` /� COMMISSIONER E COMMISSION Date: (t ` 2 Z / — ` 2 -" i,l Y O R t ( P\J1 ILUN4c)11 r q \ v Form 10 -403 Re ised 1/2010 6 ` y // 2 // Submit in Duplicate ,� 0w'>> D D' D I D D »4/) i c/n 'x 17 I WI m' r!r i r TITI Z 0 0, 0 010 0 0, 1 o of o) O E,� � D 1"' I �0 m'm m F r XIX'WW m'nIn C ,— , 'I va 0 D , CD Z2II nG)',G1'�Z o) i,>,> I,z' ' m'mlm :mlp'' I o Z co O D1� �I w O,ol 0'° r'Ic�e)5 I Zrrl m' �� -a v m ' �,'i CC v' 4, �I�I� A'A1A t O co''m'co co m ml col 0D ' c N - 0 Iww T `DD rl mmmm'm m :m0 m 73'73I7J 7J X170 ' v v I I ' a , TU l U O ' 3 ' I rn 1 1 vI C. o cnNNN N N N� Em ��DJfJ'mmrmm co p m m''Z y a�w� _ � ' '_� �1-i_0 0 O al 1 I l .00coIo00o0op co IO, :' w i w 00', � o* ,Vl m c/) u�' c 1 1 N N N N 1 x m I 3 Z , - C— CO30 >,D,r m m � —1 �D°cclz',zlo'm70 �, mm'vv -.m m w v,v'IMm -o - 0 ' — i''73 ', , 0 v!DIN''N'rlr M''Im' 11D r r m'mlc''ci ' N �1Z' I�'� -L 000,0 0 0 Im 'Im'm1 r^, OO<o0o cocols X'X 0 , _ II O O'�,W'w 03,o)'VI� i0 nI � C 1 I < rn 0 mv zl a �' m I I v 'I I IUD 0 co oo 4.! G . ) w i I1 ba' 0 0 : � ) C o4aNl_ •ta I w w --I. m .i' N C I wlciroiao0-o ".1.-.114),G.,03 1 '' w 11 < 15 I oo ao 1 1 oo' ao, ao oo 1 , w' 0- l i ',, 1 - , A III W ', . co I 1 1 o010w,cnwl4.w,y '.1ao iTI'u c.'000,cD ," 0 ' "'�Ow'�w ' • • . Version 1.1 04/28/2010 Fullbore Pumping Design Template Well Nam AGI -06 Job Scope Select Job Scope No Records H2S (ppm /date) WBL Cat IOR 2500 Max Pumping Pressure (psi) Well Type GI AFE APBinjec Main Fluid Type Date 6/14/2012 IOR 30 600 Main Fluid Volume (bbls) Engineer Javier Farinez Phone 564 -5043 Methanol (60/40) Freeze Protect Type Job Objective 10 Freeze Protect Volume (bbls) If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the • If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 407 Welibore Volume to Perfs (bbls) Fullbore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max Select I Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst /Collapse 80% Burst /Collapse Tubing Burst (psi) 7 7240 / 5410 5792 / 4328 Pre -Flush 1 I Methanol (60/40) 11 Tbg 11 101 51 2500 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab Solvent 1 Select Fluid Type 1 Tbg I I 200 ( 51 1 25001 Casing Collapse (psi) size See helpful tips tab 1 Load 11 Select Fluid Type 11 Tbg 1 6001 1 5 15001 Select Input Depth • Integrity Issues? No unknown 1 Freeze Protect 1 1 Methanol (60/40) 11 Tbg 11 101 1 51 1 15001 No Input Depth 1 Select Stage 1 1 Select Fluid Type 11 Select 1 1 1 1 1 No I Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Select Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 200 bbls 50/50 diesel /xylene 1 Not Necessary I Hold Pressure on Other Strings? 3 600 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Fullbore Pumping Program for Field Well Name AGI -06 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 6/14/2012 IOR 30 Engineer Javier Farinez Phone 564 -5043 H2S No Record Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel /Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush Methanol (60/40) I Tbg I 10 5 2500 2 Solvent Select Fluid Type Tbg 200 5 2500 3 Load Select Fluid Type Tbg 600 5 I 1500 4 Freeze Protect I Methanol (60/40) 1 1 Tbg 10 5 1500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 200 bbls 50/50 diesel /xylene 3 600 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) . Freeze Protection - see PE manual for additional information • • Freeze Protect to 2500' TVD in ID. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -8 dimensions mechanical inner capacity outer capacity size lb/ft od id drift id collapse burst bbls /ft ft/bbls bbls /ft ft/bbls 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280.00 7740.00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 8.68 8.53 4760.00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 , - NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 • 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines ao - KCI / CaCI ! NaCI / • 20 "� •,♦ / s ,__,_ / NaBr s o I- ` / ■ -20 - �, - -♦ - NaCI -40 `� -h-- C aCI - ` �� ---F -KCI i -60 41- NaBr 8.5 9.5 Density, PPG 10.5 11.5 - -- i 12.5 TREE = NOTES: WELL REQUIRES A SSSV. WELLHEAD= CNN • AG I 0 6 NSCC THREAD. CEMENTED. ALL TBG IS IPC WITH ACTUATOR= BAKER KB. ELEV = 49' BF. ELEV = KOP = 801' Max Angle = 48 @ 3406' • Datum MD = 11707' 2013' H 7" CAMCO BAL-0 SSSV NIP, ID = 5.937" Datum TV D= 8800' SS 13 -3/8" CSG, 68#, K -55, ID = 12.415" —1 119' I-- 113 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 4103' 7" TBG, 26 #, NT- 80- S-IPC, NSCC, 10352' .0383 bpf, ID = 6.276" / 1 10352' HT 1 7" X 5-1/2" XO, ID = 4.875" 1 I5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 10352' 1 10356' 1 -1ANCHOR, ID = 4.875" 1 X X I 10357' H9-5/8" X 5-1/2" BAKER SB -3A PKR, ID = 4.874" Minimum ID = 4.455" @ 10425' 5-1/2" OTIS XN NIPPLE 1 1 I 10404' I 15 -1/2" PARKER SWS NIP, ID = 4.562" I TOP OF 7" LNR 1 10422' 1 ® ■ 1 1 10425' -15 -1/2" O11S )N NIP, ID = 4.455" / \ 1 10437' H5-1/2" WLEG, ID = 4.892" 1 1 10433' H ELMD TT LOGGED 05/10/93 1 19 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 10583' ( , PERFORATION SUMMARY REF LOG: GR CCL ON 06/08/93 ANGLE AT TOP PERF: 47 @ 10817' Note: Refer to Production DB for historical pert data — SIZE SPF INTERVAL Opn /Sqz DATE 3 3/8" 6 10817 - 10837 0 6/14/93 3 3/8" 6 10856 - 10866 0 6/14/93 3 3/8" 6 10888 - 10898 0 6/14/93 3 3/8" 6 10963 - 10983 0 6/14/93 3 3/8" 6 11013 - 11023 0 6/14/93 — 3 3/8" 6 11051 - 11061 0 6/14/93 3 3/8" 6 11110 - 11130 0 6/14/93 PBTD H 11176' 1 7" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" H 11198' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/27/93 LAST WORKOVER WELL: AGI-06 01/26/01 SIS -LG REVISION PERMIT No: '1930090 05/22/01 RN/KAK CORRECTIONS API No: 50- 029 - 22333 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 695.24' FEL & 1674.37' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 To: Jim Regg l P.I. Supervisor ~~~ 1 I~I~ SUBJECT: Mechanical Integrity Tests 1 ~ BP EXPLORATION (ALASKA) INC AGI-06 FROM: Jeff Jones PRUDHOE BAY iJNIT AGI-06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ ~- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY L1NIT AGI-06 Insp Num: miUJ090906175330 Rel Insp Num: API Well Number: 50-029-22333-00-00 Permit Number: 193-009-0 .. Inspector Name: Jeff Jones Inspection Date: g~21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 AGI-06 Type Inj. G T~ 7884 ~ jt1 560 2200 ~ 2170 2170 P.T.D 1930090 TypeTest SPT Test psi 1971 ~/ QA 390 550 550 550 ~ - Interval 4YRTST P~' P / Tubing ~ 3360 3360 3360 3360 I ~ Notes: 3•6 BBLS diesel pumped. +~ t~~d, p . ~li~~~~ :.°a.. . . ~HU~« ~:. r ~ ~. Tuesday, September 08, 2009 Page 1 of 1 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity 7est Email to: Winton_Aubert@admin.state.ak.us; Bob_Fieckenstein@admin.state.ak.us; Jim_Regg~admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / AGI DATE: 08/20/09 OPERATOR REP: Torin Roschinger AOGCC REP: `q3-ooq ~ ~- 0 ~0 ~ Packer De th Pretest Initial 15 Min. 30 Min. Weil AGI-02 Ty e In'. G TVD 7,862' Tubing 3370 3360 3360 3360 Interval 4 P.T.D. 1921200 Type test P Test si 1965.5 Casin 970 2210 2190 2190 P/F P Notes: MIT-IA for 4 year regulatory compliance OA 600 710 710 710 Well AGI-03 T e In'. G TVD 7,885' Tubin 3450 3460 3460 3440 Interval 4 P.T.D. 1921350 Type test P Test si 1971.25 Casing 475 2200 2170 2180 P/F P Notes: OA 200 390 380 375 Well AGI-04 Ty e Inj. G ND 7,920' Tubin 3410 3400 3400 3400 Interval 4 P.T.D. 1921460 T e test P Test si 1980 Casin 590 2210 2240 2280 P/F F Notes: OA 300 415 430 450 Well AGI-06 T e In'. G TVD 7,853' Tubin 3360 3360 3360 3360 Interval 4 P.T.D. 1930090 T e test P Test psi 1970.75 Casin 360 ~2200 2170 2170 P!F P Notes: OA 390 550 550 550 Well T e In . TVD Tubin Interval P.T.D. T e test Test psi Casin P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test ~l r., t / ~~!t~~;i ~p~. $„'~„~y ~~~~' !"~. k~ ~ ' - ~'~,~ ~~~f~~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other(describein notes) MIT Report Form BFL 9/1/05 MIT PBU AGI 02, 03, 04, O6 08-22-09.x1s Re: WGI-06 (PTD # 1900300) Slow 1A Repressurization " , BP notified the Commission about varying degrees of pressure communication affecting 6 PBU gas injectors. Wells are: AGI-06; TxIA NGI-01; TxIA NGI-06; IAxOA NGI-10; IAxOA NGI-13; TxIA WGI-06; TxIA BP intends no repairs to correct the pressure communication, instead relying on human intervention to manage the pressures. The correct mechanism for reviewing continued operation of these wells is the administrative approval process under AIO 4D Rule 9. Please submit admin approval requests to the Commissioner's attention. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and Winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and lA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. Tþis pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and wellbore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com ~~?:gt:.<:):ì.'1:§!2~º~~~l::LI_~t:.~gE~_t::Y~I!.~l~:!.l~~E~!?E:_<:;<:)~?_ 1 of 1 3/24/2006 9:36 AM ) MEMORANDUM TO: Jim Regg P.I. Supervisor .--:-¡ C( I'..... Ke{1 ,( IS DS FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE SAY UNIT AGI-06 Insp N urn: mitJCr050825 13060 1 Rei Insp Num Packer Well !_ ,~~I-Ö6 I Type__I~l:T·'G'T TVD 'I" P.T. 119-1009~_J!rpeTest ¡ SPT !_,1.:~~t._p~! I ~ter:yªt_, 4YRTST __''_p.æ P Notes 4 bbls pumped for test. Tuesday, August 30, 2005 ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) rNC AGI-06 PRUDHOE SAY UNIT AGI-06 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22333-00-00 Permit Number: 193-009-0 Depth Pretest 7884--- , r' 'ÏA'-T-- 197-i--- -1-_ 0 ~..J Tubing! Initial 2180 110 3500 15 Min. ~). ".',:: t).'"n. D \,'_:1 .;:' 11'" ~~\ Ä~ Nt.:: " \ ~:·.i !:.'. )1) ( _ L ~ - ,,,~ \,,~.{: ,J ' ~\t 'ì; '-, f(~" l _ ¡,~ 2180 110 3500 (þ \~?/ t;Ú , Reviewed By: P.I. Suprv-.::jBf--- Comm Inspector Name: John Crisp Inspection Date: 8/23/2005 30 Min. 45 Min. 60 Min. 2180 I .dl-· --- 'i --r--..----·--- 110 3500 . 1'--'-- 1""---' I _.,. _."__~__L_... .,."___. ,..._ Page 1 of 1 MEMORANDU~vl State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~,\q~' DATE: May 27, 2001 Commissioner Maunder. _~'~ SUBJECT:BPxMechanical Integrity Tests THRU: Tom P.I. SupervisOr:J~~(c~,O' ~, AGI Pad AGI-06, 07, 08, 09, 10 FROM: Jeff JOnes PBU Petroleum Inspector PBF NON- CONFIDENTIAL paCker Depth Pretest Initial 15 Min. 30 Min. We,,IAGI-06 I Type,nJ.I G I ~.V.~. I~0 I Tubing13500 I 3800 I 3500 13500 I,nterva, I 4 P.T.D.I 193-009 ITypetestl P I T~stpsil' 1970 Icasingl 8°° I 21001 21001 2°9° I PIE I' P Notes: . WellI AGI,07 ITypelnj.I G I T.V.D. I 7840 I Tubingl 3400 I 3400 I 3400 I' 3400'llntervalJ' 4 P.T.D.I 193-027 ITypeteStl P ITestpsil 1960 I CasingI 850 I 2130 I 2130 I 2130 I PIE I P Notes: WellI AGI-08 I Typelnj. I G I T.V.D. I 7861 I Tubingl 3500 I 3500 ) 3~00I 3500 I lntervalJ 4 P.T.D.I 193-033 ITypetestl P ITestpsil 1965 ICasingI 890 I 21201 21201 21101 P/F ! P Notes: WellI AGI-09I Typelnj. I G I ~.V.O. 17887 I TUbing 13400 13400 I 3400'I'3400 I lnterVall 4 P'T-D'I 193-035 ITypeteStl P ITestPsil 1972 ICasingl 1120 I 2100 I 2100 I 2100 I..PIE. I '__P. Notes: We,,IAG"10 IType,nj.l' G I T.V.D. 17824 I Tubi.gI 3~00 I~00 I Ilntervall 4 P.T.D.I 193-039 Type testI P I Testpsil 1956 I CasingI 700 I 21001 20801 20801 P/F I -P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, May 27, 2001: I traveled to BPX's AGI Pad to witness 4 year MIT's on gas injection wells AGI-06, 07, 08, 09, and 10. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MITs. The test data above indicates these wells are suitable for continued injection. Summary:, I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: 0_ Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-06,07,08,09,10 5-27-01 JJ 6/9/01 ON OR BEFORE DECEMBER 01 2000 c:LOi~Xl~IL,I'4.DOC AOGCC IndS'vfdua'] ~,,!e] '1 G e o ] o 9 'i' c a '] N a t: e. r' 'i o "i: ::15: n v e n t: o r" y P E R H I T D A T A T D A T,&_.F:' L IJ S 9.:3. 009 .... , H ~ D L l.. / H L L/' ,A C / G R 93'---'009 5867 /-~ OH .....H~,?D~8928--"10590 93 "-'009 40? ~'~ C ON F' DATE;O6fla. t93 93 ..... 009 DALLY WELL OF' ~02/03,/93""04/27/93 9~ .... 009 SURVEY ~'~'~,'/P DIRECTIONAL 93"'009 SURVEY ~SS DZR ECTZONAI... 9~ 009 AC/CBT ~"Ot"t~ R I 93""009 AC a'l" 93 .... 009 COI','IP 9 ?, ..-. 009 DLL/GR/'S P , . /S F'/" G IR 9 ,:'..¢ ..... 009 D L L/H L L ,, 93 "009 D PR//,3 93 ..... 009 DPR/GR 93 ..... 009 GR/'CCL 9 ;3 ..... 009 G F,:/C C I... 93 *.009 SB L/G R/C:C !.... f:~ U N I?, A 'T' E ..... F~'. E C V D 08/3 'i/" 1993 09/' 08// 'i 993 0s/s'l/'199s 09/08//1993 1 05/10/' '199 07/"3 O/1993 1 05/ '10/' I 993 1 0'//'30/I 993 OH,,.R1 ~5 :~ 'i 05,/'i0,/1993 RUN 1,~ 5:: 07/"30/'1993 'i 0 '?/' ."~ 0 ,/'i 99 .:.3 -' ,~) '~ I I "' l 01"1 ,. I~ 1 ,. ~. e:. 5 '1 0 '.:.'.,/ I 0/' 'i 9 9 3 MD 6&? 0?/30/ 1993 TVD 8&? 07//:30/'i 993 RLIN I ~ 5 I~ 06/2'.8/lCJ93 10310 .... 1 t190 '1 0 '1/ 'i 4/"1994 Ct-'I ~ R 'i ~.5~ 't 05/'06/1993 ~?_} R e c e 'i v e d ye s n c, l'q O ~'~ STATE OF ALASKA ~' ALASKA ~)~L AND GAS CONSERVATION COiv. vllSSlON WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Stalus of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ Apex Gas Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-09 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22333 4. Location of well at surface 9. Unit or Lease Name 2174' NSL, 2495' WEL, SEC. 36, T12N, R14E 'i~~i Prudhoe Bay Unit ' ' 1 10. Well Number At Top Producing Interval ~i~ ~ 1~. · I AGI-6 3537' NSL, 3755' EWL, SEC. 31, T12N, R15E~. .t 11. Field and Pool Al Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 3608' NSL, 4171'EWL, SEC. 31, T12N, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 49.5' I ADL 34628 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 2/3/93 4/24/93 6/14/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J2.0. Depth where SSSV set ~1. Thickness of Permafrost 11200' MD/8468' TVD 11176' MD/8451' TVD YES [] NO []! 2013' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run BHCS/DLL/MLL/GR/MWD 23. CASING, LINER AND CEMENTING RECORD SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 106' 30" 11 yds Arcticset 13-3/8" 68# NTS-80 37' 4103' 16" 2580 cufl PF "E"/460 cu ft Class "G" 9-5/8" 47# NTS-80 36' 10583' 12-1/4" 575 cu ft Class "G" 7" 29# L-80 10422' 11198' 8-1/2" Uncemen ted 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 (MDI Gun Diameter 3-3/8" 6 spf 7"x 5-1/2" 10437' 10357' MD TVD 10817'-10837' 8150'-8164' NT-80 x L-80 10856'- 10866' 8178'-8185' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10888'-10898' 8200'-8207' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10963'- 10983' 8252'-8266' 11013'-11023' 8287'-8294' 11110'- 11130' 8355'-8369' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/14/93 I Gas Injection Date of Test Hours Tested ~)RODUCTION FOR OIL-BBL ,..~AS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I rEST PERIOD Flow Tubing Casing Pressure .?,ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28, CORE DATA Brief description of lithology, porosity, lractures, apparent dips, and presence ol oil, gas or waler. Submit core chips. RECEIV£D SEP 1 9 1994 Alaska 0il & Gas Cons. Commission Anch0ra~e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS F~n,VIATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP'IH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10613' 8005' Base Sadlerochit 11143' 8380' REEEIVED S EP 1 9 1994 Alaska 0il & Gas Cons. Commission Anch0r~e 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~: [~-~: ~-~';;~¢J~Z Title Orillino Enoineer Suoervisor 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI-6 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/02/93 11:00 SPUD: 02/03/93 01:00 RELEASE: 04/27/93 06:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 02/03/93 (1) TD: 307'( 0) 02/04/93 ( 2) TD: 2020' (1713) DRLG. MW: 8.6 VIS: 42 SKID RIG. RIG ACCEPTED @ 11:00 HRS, 2/2/93. N/U DIVERTER. TEST SAME. M/U BHA. SPUD WELL @ 01:00 HRS, 2/3/93. DRLG F/ 110'-307' DRLG. DRLG F/ 307'-2020' MW: 9.4 VIS:143 02/05/93 ( 3) TD: 3734' (1714) 02/06/93 (4) TD: 4115' ( 381) 02/07/93 ( 5) TD: 4115' ( 0) 02/08/93 (6) TD: 4775' ( 660) 02/09/93 (7) TD: 7096'(2321) 02/10/93 (8) TD: 7956'( 860) 02/11/93 ( 9) TD: 8843' ( 887) POOH. MW: 9.4 VIS:ll0 DRLG TO 2145' CBU. WIPER TRIP. DRLG TO 3640' CIRC. DROP SINGLE SHOT SURVEY. DRLG TO 3734'. DROP SINGLE SHOT SURVEY. CIRC. POOH FOR MWD FAILURE. CIRC. MW: 9.4 VIS:ll5 POOH. CHANGE MWD. RIH. DRLG TO 4115' CBU. SHORT TRIP 10 STDS. CIRC. POOH. RIH W/ 13-3/8" CSG. CIRC. RIH. MW: 9.5 VIS: 55 LAND CSG. CIRC. R/U HOWCO. PUMP 90 BBLS WATER, 1200 SX LITE CMT, 400 SX PREM CMT. BUMP PLUG W/ 2000 PSI. N/D RISWER, DIVERTER. 250 SX TOP JOB. N/U BOPE. TEST BOPE. RIH W/ BHA. DRLG. MW: 8.8 VIS: 35 RIH TO FC. CIRC. TEST CSG. DRLG FLOAT EQUIP, CMT, 10' NEW HOLE. CBU. LOT (12.9 PPG EMW). DRLG 2 STDS. CBU. POOH. CHANGE MWD. RIH. DRLG TO 4667' CIRC. POOH. CHANGE MWD. RIH. WASH 100' TO BTM. DRLG TO 4775' SHORT TRIP. MW: 9.4 VIS: 40 DRLG TO 5709' CBU. SHORT TRIP TO SHOE. DRLG TO 6924' CIRC. DRLG TO 7096'. CIRC. POOH TO SHOE & WORK ON TOP DRIVE. DRLG. MW: 9.4 VIS: 40 RIH. DRLG TO 7635'. CBU. DROP SURVEY. POOH. CHANGE BIT. RIH. WASH 230' TO BTM. DRLG TO 7956'. DRLG. MW: 9.7 VIS: 42 DRLG TO 8490' POOH WET TO FIND WASHOUT. FOUND. RIH. DRLG TO 8843' RE£EIVED ._p 8 993 Alaska Oil & Bas Cons. Anchorago WELL : AGI-6 OPERATION: RIG : AUDI 2 PAGE: 2 02/12/93 (10) POOH. MW: 9.8 VIS: 43 TD: 9550' ( 707) \ DRLG TO 9550' CBU. SURVEY. POOH. CHANGE MTR, BIT. 02/13/93 (11) TD:10590' (1040) 02/14/93 (12) TD:10590' ( 0) 02/15/93 (13) TD:10590' ( 0) 04/23/93 (14) TD:10767' ( 177) 04/24/93 (15) TD:10780' ( 13) 04/25/93 (16) TD:ll200' ( 420) 04/26/93 (17) TD:ll200 PB:ll200 04/27/93 (18) TD:ll200 PB:ll200 SHORT TRIP. MW: 9.9 VIS: 42 RIH. REAM 75' TO BTM. DRLG TO 10590'. TD 12-1/4" HOLE. CBU. 15 STDS SHORT TRIP. CMT 9-5/8" CSG. MW: 9.9 VIS: 44 CIRC SWEEP. POOH. R/U WOTCO. RIH W/ 9-5/8" CSG. WASH TO TD. CIRC. RIG RELEASED. MW: 9.9 VIS: 0 R/U HOWCO. PUMP 105 BBLS SLURRY. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. R/D CSG EQUIP. SET PACKOFF. TEST SAME. OK. RIH TO 2000'. DISP W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. OK. RIG RELEASED @ 19:00 HRS, 2/14/93. MONITOR WELL. MW: 9.5 VIS: 57 MOVE TO AGI-6. RIG ACCEPTED @ 07:00 HRS, 4/22/93. N/D TREE. N/U BOPE. TEST BOPE. RIH W/ BIT, BHA. CIRC. TAG FC. CBU. TEST CSG. OK. DRLG FLOAT EQUIP, CMT TO 10590'. CIRC. DISP WELL TO FLO-PRO. FIT (12.9 PPG EMW) . DRLG F/ 10600'-107670'. DRLG. MW: 9.1 VIS: 55 DISP WELL TO FLO-PRO. POOH TO 6272'. RIH. CIRC. SPOT LCM PILL. POOH 15 STDS. RIH. DRLG F/ 10767'-10780'. LOGGING. MW: 9.1 VIS: 55 DRILL TO 11200' TD WELL @ 19:30 HRS, 4/24/93. CIRC. POOH TO SHOE. RUH. CIRC. POOH. m/u ATLAS. LOG RUN: DLL/MLL/GR. POOH. MW: 9.0 NaC1 LOG WELL. R/D ATLAS. RIH W/ 7" LNR ON DP. CIRC. RIH. CIRC. PUMP 100 BBLS XANVIS, 200 BBLS SEAWATER, 50 BBLS BRINE, 50 BBLS BLEACH. RELEASE DART. DISP W/ BRINE. SET HGR W/ 3000 PSI, PKR W/ 4000 PSI. TEST ANNULUS. DISP WELL W/ BRINE. POOH. RIG RELEASED. MW: 9.0 NaC1 RIH W/ TBG, COMP ASS'Y. SPACE OUT. M/U HGR. F/P TBG TO 2000'. DROP BALL. SET PKR. TEST PKR. OK. LAND TBG. TEST TBG, ANNULUS. OK. N/D BOPE. N/U TREE. TTEST TREE. SECURE WELL. RIG RELEASED @ 06:00 HRS, 4/27/93. SIGNATURE: (drilling superintendent) DATE: E( E VED $ 5 P - 8 Alaska Oi~ & Gas Cons. (;ommissio~ Anchorag~ ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS J-~ OOL REEEIVED S E P - 8 199~, Alaska .OJJ .& Gas CoFm. Commissio~ Company Well Name Field/Location ARCO ALASKA, INC. AGI-6 (2173' FSL, 2495' FEL, SEC 36, T12N, R14E) PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 93252 Loaqed BV: RE~ED W/DEPTH CORBECTIO#S Date lO-HAY-93 Computed By: SARBER SINES SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. AGI - 6 (RECOMPUTED WITH DEPTH CORRECTION) PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' MAY-lO-1993 ENGINEER' G. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINI~ CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 79 DEG 39 MIN EAST COMPUTATION DATE' 8-JUN-93 PAGE I ARCO ALASKA INC. AGI - 6 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' MAY-lO-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 0 O0 100 O0 2O0 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 399 99 499 98 599 93 699 63 798 74 897 21 -49 O0 51 O0 151 O0 251 O0 350 450 550 650 749 848 0 0 N 0 0 E 0 14 S 56 41E 0 18 S 63 37 E 0 19 S 65 20 E 99 0 39 S 76 37 E 98 I 13 N 86 40 E 93 2 38 N 79 15 E 63 5 59 N 73 6 E 74 9 1 N 75 41E 21 11 11 N 75 54 E 0 O0 0 15 0 52 0 94 1 68 3 33 6 42 '13 86 27 O0 44 40 0 O0 0 16 0 04 0 16 0 37 0 54 2.46 3.31 2.31 2.40 0 O0 N 0 13 S 0 36 S 0 59 S 0 87S 0 94 S 053S 1 47 N 501 N 9 22 N 0 O0 E 0 17 E 0 59 E 10TE 187 E 3 55 E 6 62E 13 82 E 26 53 E 43 45 E 0 O0 N 0 0 E 0 0 1 2 3 6 13 27 44 22 S 52 21 E 69 S 58 42 E 22 S 6O 53 E O6 S 65 5 E 67 S 75 11 E 64 S 85 25 E 9O N 83 55 E O0 N 79 19 E 42 N 78 1 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 994 78 O0 1091 O0 1188 O0 1285 O0 1381 O0 1477 O0 1573 O0 1669 O0 1763 O0 1855 945.78 13 48 77 1042.77 14 11 63 1139.63 14 47 O0 1236.00 15 57 13 1332.13 15 53 45 1428.45 15 23 77 1524.77 16 5 11 1620.11 19 6 03 1714.03 20 44 53 1806.53 24 33 N 73 22 E N 73 27 E N 73 31E N 73 17 E N 73 55 E N 75 50 E N 77 35 E N 75 29 E N 74 0 E N 76 33 E 66.16 90.35 115,07 141.60 168.98 195.76 222.61 252.67 286.87 324.66 I 39 0 22 1 35 0 37 0 65 0 53 2 O1 3 O0 1 37 5 41 15 10 N 22 29 36 44 51 57 64 73 83 64 50 E 12 N 87 18 N 111 80 N 137 61N 163 64 N 189 80 N 215 70 N 245 86 N 278 58 N 314 66.24 N 76 49 E 80 E 90.55 N 75 52 E 65 E 115.40 N 75 21 E 22 E 142.07 N 74 59 E 63 E 169.60 N 74 45 E 57 E 196.47 N 74 46 E 73 E 223.34 N 75 0 E 03 E 253.43 N 75 13 E 13 E 287.77 N 75 8 E 76 E 325.67 N 75 8 E 2000 O0 1944 58 1895.58 29 38 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2030 O0 2114 O0 2199 O0 2281 O0 2362 O0 2441 O0 2518 O0 2594 O0 2666 O0 1981.00 32 7 64 2065.64 32 12 04 2150.04 32 52 72 2232.72 35 26 14 2313.14 37 23 07 2392.07 38 21 72 2469.72 39 56 17 2545.17 42 18 30 2617.30 44 37 N 73 15 E N68 0 E N 68 42 E N 69 27 E N71 27 E N 71 14 E N 7O 42 E N 67 59 E N 67 16 E N 68 12 E 369 96 421 12 473 33 526 05 581 58 640 38 701 10 763 04 827 18 894 96 6 15 0 82 0 50 2 11 2 31 1 24 1 90 2 38 3 44 0 85 94 80 N 358 76 E 371.07 N 75 12 E 112 132 151 170 189 209 231 256 282 83 N 407 55 N 456 72 N 507 38 N 560 43 N 616 25 N 674 64 N 733 79 N 793 96 N 858 48 E 422.81 N 74 31E 96 E 475.79 N 73 49 E 04 E 529.25 N 73 20 E 08 E 585,42 N 73 5 E 37 E 644.82 N 72 55 E' 48 E 706.19 N 72 46 E 36 E 769.07 N 72 28 E 97 E 834.46 N 72 5 E 08 E 903.53 N 71 45 E 3000.00 2737 17 2688 17 45 8 3100.00 2807 3200.00 2876 3300.00 2945 3400.00 3013 3500.00 3081 3600.00 3151 3700.O0 3221 3800.00 3292 3900.00 3364 23 2758 70 2827 41 2896 03 2964 22 3032 15 3102 12 3172 O7 3243 88 3315 23 45 51 70 46 12 41 47 03 47 5O 22 45 46 15 45 42 12 45 21 07 44 8 88 42 46 N 67 17 E N 66 46 E 1033 N 67 55 E 1103 N 70 15 E 1175 N 72 50 E 1248 N 7O 4 E 1320 N 68 53 E 1390 N 69 0 E 1461 N 69 29 E 1530 N 74 29 E 1598 964 06 62 87 28 21 67 96 15 44 32 I 52 0 63 1 45 2 O6 0 92 3 27 0 19 0 78 2 67 1 98 309 38 N 923 50 E 973 95 N 71 29 E 337 365 391 414 437 462 488 513 534 52 N 989 29 N 1055 29 N 1123 57 N 1193 19 N 1262 64 N 1329 31N 1396 44 N 1461 76 N 1527 07 E 1045 42 E 1116 26 E 1189 14 E 1263 67 E 1336 47 E 1407 14 E 1479 98 E 1549 09 E 1618 08 N 71 9 E 85 N 70 55 E 46 N 70 48 E 11 N 70 50 E 22 N 70 54 E 67 N 70 49 E 07 N 70 43 E 52 N 70 39 E 02 N 70 42 E COMPUTATION DATE- 8-JUN-93 PAGE 2 ARCO ALASKA INC. AGI - 6 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' MAY-lO-1993 KELLY BUSHING ELEVATION. 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3437 33 3388.33 44 14 4100.00 3508 4200.00 3580 4300.00 3652 4400.00 3722 4500.00 3793 4600.00 3863 4700.00 3935 4800.00 4007 4900.00 4080 99 3459 99 44 79 3531 03 3603 61 3673 02 3744 99 3814 77 3886 81 3958 O0 4031 79 44 21 03 44 50 61 45 18 O2 45 8 99 44 29 77 43 56 81 43 51 O0 43 45 N 75 19 E 1667 01 N 75 54 E 1736 N 76 36 E 1806 N 77 7 E 1876 N 76 3 E 1946 N 75 18 E 2017 N 75 28 E 2087 N 77 23 E 2157 N 78 2O E 2226 N 78 25 E 2295 58 06 16 90 73 98 47 80 98 0 84 0 64 0 60 0 66 1 40 0 48 0 83 1 65 0 22 0 18 552.62 N 1593 65 E 1686 75 N 70 53 E 569.99 N 1661 586.52 N 1728 602.48 N 1797 618.62 N 1866 636.42 N 1934 654.23 N 2003 670.85 N 2070 685.25 N 2138 699.18 N 2206 21E 1756 82 E 1825 16 E 1895 13 E 1965 87 E 2036 04 E 2107 63 E 2176 48 E 2245 27 E 2314 27 N 71 4 E 60 N 71 16 E 45 N 71 28 E 99 N 71 40 E 85 N 71 48 E 17 N 71 55 E 60 N 72 3 E 59 N 72 14 E 40 N 72 25 E 5000 O0 4152 14 4103 14 43 49 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4223 O0 4293 O0 4364 O0 4435 O0 4506 O0 4577 O0 4647 O0 4717 O0 4786 63 4174 92 4244 28 4315 11 4386 26 4457 52 4528 67 4598 34 4668 90 4737 63 45 13 92 45 21 28 45 6 11 44 53 26 44 32 52 44 40 67 45 58 34 45 46 90 46 25 N 78 20 E 2365.21 N 80 23 E 2435.12 N 80 52 E 2506.24 N 80 49 E 2577.28 N 81 17 E 2647.86 N 81 27 E 2718.09 N 81 18 E 2788.22 N 81 10 E 2859.45 N 81 10 E 2931.16 N 80 47 E 3002.98 0 52 2 15 0 17 0 59 0 43 0 10 1 O6 0 33 0 O8 1.43 713.10 N 2274 10 E 2383 28 N 72 35 E 726.43 N 2342 737.76 N 2412 749 11N 2483 760 11N 2552 770 57 N 2622 781 09 N 2691 791 98 N 2762 802 99 N 2832 814 16 N 2903 73 E 2452 96 E 2523 10 E 2593 83 E 2663 31E 2733 68 E 28O2 11E 2873 99 E 2944 96 E 3015 77 N 72 46 E 22 N 73 0 E 64 N 73 13 E 59 N 73 25 E 19 N 73 37 E 72 N 73 49 E 41 N 74 0 E 59 N 74 11E 93 N 74 20 E 6000 O0 4855.42 4806.42 46 45 6100 6200 6300 6400 6500 660O 6700 6800 6900 O0 4924.10 4875.10 46 30 O0 4992.87 4943.87 46 39 O0 5061.68 5012.68 46 34 O0 5130.22 5081.22 46 43 O0 5198.74 5149.74 46 48 O0 5267.57 5218.57 46 13 O0 5336.53 5287.53 46 39 00. 5405.22 5356.22 46 35 O0 5473.75 5424.75 46 55 N 80 30 E 3075.81 N 80 37 E 3148.48 N 80 43 E 3221.07 N 80 59 E 3293 62 N 81 26 E 3366 41 N 81 45 E 3439 20 N 81 56 E 3511 69 N 82 9 E 3584 O4 N 80 57 E 3656 67 N 80 51 E 3729 48 0 27 0 19 0 23 0 64 0 24 0 38 0 38 0 60 0 54 0 11 826 12 N 2975 81 E 3088.35 N 74 29 E 838 849 861 872 883 893 903 914 925 09 N 3047 86 N 3119 48 N 3190 54 N 3262 17 N 3334 48 N 3406 45 N 3478 14 N 3550 67 N 3622 50 E 3160.64 N 74 37 E 14 E 3232.84 N 74 46 E 77 E 3305 02 N 74 53 E 74 E 3377 39 N 75 2 E 79 E 3449 76 N 75 10 E' 60 E 3521 82 N 75 18 E 32 E 3593 74 N 75 26 E 20 E 3666 01 N 75 34 E 11 E 3738.53 N 75 40 E 7000.00 5542.13 5493.13 46 54 7100.00 5610 39 5561.39 46 51 7200.00 5678 7300 O0 5747 7400 O0 5815 7500 O0 5885 7600 O0 5954 7700 O0 6022 7800 O0 6091 7900 O0 6161 69 5629.69 46 56 11 5698 11 46 44 89 5766 89 46 21 18 5836 18 46 11 21 5905 21 46 30 96 5973 96 46 29 91 6042 91 46 16 19 6112 19 46 2 N 8O 54 E 3802 44 N 80 59 E 3875 N 81 g E 3948 N 81 7 E 4021 N 80 32 E 4093 N 80 21E 4166 N 80 17 E 4238 N 80 30 E 4311 N 80 33 E 4383 N 8O 34 E 4455 50 52 42 99 O9 44 O5 47 57 0 33 0 35 0 24 0 39 0 83 0 49 0 43 0 19 0 35 0 27 937 24 N 3694.16 E 3811.20 N 75 46 E 948 960 971 982 994 1007 1019 1031 1042 81 N 3766.32 E 3883.99 N 75 52 E 09 N 3838.48 E 3956.73 N 75 57 E 30 N 3910.54 E 4029.36 N 76 3 E 78 N 3982.22 E 4101.70 N 76 8 E 89 N 4053.30 E 4173.61 N 76 13 E 06 N 4124.62 E 4245.78 N 76 17 E 17 N 4196.22 E 4318.21 N 76 21 E 09 N 4267.67 E 4390.46 N 76 25 E 93 N 4338.80 E 4462.39 N 76 29 E COMPUTATION DATE' 8-JUN-93 PAGE 3 ARCO ALASKA INC. AGI - 6 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- MAY-lO-1993 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG BIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTIJRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 6230.84 6181.84 45 38 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6300.91 6251.91 45 27 O0 6370.57 6321.57 46 4 O0 6440.13 6391.13 45 49 O0 6509.97 6460.97 45 34 O0 6579.98 6530.98 45 36 O0 6649.98 6600.98 45 34 O0 6719.42 6670.42 46 17 O0 6788.71 6739.71 45 58 O0 6858.55 6809.55 45 28 N 80 33 E 4527 31 N 80 3O E 4598 N 80 35 E 467O N 80 58 E 4742 N 81 17 E 4813 N 80 43 E 4885 N 80 26 E 4956 N 78 45 E 5028 N 78 41E 5100 N 79 6 E 5172 66 39 22 76 15 55 51 60 16 0 39 0 32 0 47 0 35 0 40 0 17 1 40 0 46 0 50 0 74 1054.68 N 4409 58 E 4533 95 N 76 33 E 1066.43 N 4479 1078.28 N 4550 1089.77 N 4621 1100.72 N 4692 1111.98 N 4762 1123.51 N 4833 1136.83 N 4904 1150.92 N 4974 1164.80 N 5044 96 E 4605 71E 4676 64 E 4748 35 E 4819 87 E 4890 35 E 4962 06 E 5034 77 E 5106 98 E 5177 14 n 76 37 E 71 N 76 40 E 38 N 76 44 E 73 N 76 48 E 96 N 76 52 E 21 N 76 55 E 10 N 76 57 E 17 N 76 58 E 70 N 77 0 E 9000 O0 6929 02 6880 02 44 54 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7000 O0 7072 O0 7145 O0 7217 O0 7287 O0 7358 O0 7428 O0 7498 O0 7568 28 6951 48 7023 54 7096 27 7168 89 7238 45 7309 73 7379 55 7449 14 7519 28 44 12 48 43 14 54 43 34 27 44 26 89 45 6 45 45 8 73 45 31 55 45 51 14 45 57 N 79 45 E 5243 11 N 80 39 E 5313 N 81 25 E 5382 N 80 49 E 5450 N 80 29 E 5520 N 8O 55 E 5591 N 81 7 E 5661 N 80 58 E 5733 N 80 55 E 5804 N 80 53 E 5876 26 42 68 35 13 98 09 67 46 0 79 0 99 1 25 1 92 1 O4 0 55 0 33 0 36 0 24 0 24 1177.76 N 5114 74 E 5248 58 N 77 2 E 1189.76 N 5183 1200.49 N 5252 1210 91N 5319 1222 46 N 5388 1233 96 N 5458 1244 92 N 5528 1256 06 N 5598 1267 42 N 5669 1278 76 N 5740 86 E 5318 20 E 5387 68 E 5455 40 E 5525 25 E 5595 27 E 5666 53 E 5737 21E 5809 12 E 5880 64 N 77 4 E 65 N 77 8 E 76 N 77 11E 33 N 77 13 E 99 N 77 16 E 70 N 77 19 E 70 N 77 21E 15 N 77 24 E 83 N 77 26 E 10000 O0 7637 49 7588 49 46 10 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 7706 O0 7775 O0 7844 O0 7913 O0 7982 O0 8050 O0 8119 O0 8188 O0 8257 61 7657 49 7726 32 7795 33 7864 24 7933 80 8001 23 8070 17 8139 65 8208 61 46 26 49 46 32 32 46 23 33 46 16 24 46 32 80 47 6 23 46 35 17 46 14 65 45 48 N 80 54 E 5948.49 N 80 50 E 6020.74 N 80 40 E 6093.22 N 80 30 E 6165.75 N 80 28 E 6238 12 N 80 29 E 6310 58 N 80 51 E 6383 37 N 80 54 E 6456 26 N 80 50 E 6528 69 N 80 27 E 6600 59 0 17 0 13 0 17 0 38 0 78 0 33 1 03 0 52 0 53 0 39 1290 10 N 5811 27 E 5952.75 N 77 29 E 1301 1313 1325 1337 1349 1361 1372 1383 1395 62 N 5882 22 N 5954 08 N 6025 04 N 6097 03 N 6168 08 N 6240 37 N 6312 90 N 6383 57 N 6454 61 E 6024.89 N 77 31 E 17 E 6097.27 N 77 34 E 73 E 6169.71 N 77 36 E 11 E 6241299 N 77 38 E 58 E 6314.37 N 77 40 E' 37 E 6387.08 N 77 42 E 41E 6459.87 N 77 44 E 93 E 6532.21 N 77 46 E 89 E 6604.03 N 77 48 E 11000.00 8327.39 8278.39 45 41 11100.00 8397.29 8348.29 45 28 11200.00 8467.59 8418.59 45 17 N 80 1E 6672.26 N 79 32 E 6743.77 N 79 11 E 6814.88 0.31 0.72 0. O0 1407.81N 6525.51E 6675.64 N 77 50 E 1420.50 N 6595.88 E 6747.11 N 77 51 E 1433.75 N 6665.75 E 6818.21 N 77 52 E COMPUTATION DATE: 8-JUN-93 PASE 4 ARCO ALASKA INC. agI - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: MAY-lO-1993 KELLY BUSHINg ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEg RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEg MIN 0 O0 1000 2OOO 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 994 O0 1944 O0 2737 O0 3437 O0 4152 O0 4855 O0 5542 O0 6230 O0 6929 -49 O0 78 945 58 1895 17 2688 33 3388 14 4103 42 4806 13 5493 84 6181 02 6880 0 0 78 13 48 58 29 38 17 45 8 33 44 14 14 43 49 42 46 45 13 46 54 84 45 38 02 44 54 N 0 0 E N 73 22 E 66 N 73 15 E 369 n 67 17 E 964 N 75 19 E 1667 N 78 20 E 2365 N 80 30 E 3075 N 80 54 E 3802 N 80 33 E 4527 N 79 45 E 5243 0 O0 16 96 06 O1 2I 81 44 3I 11 0 O0 1 39 6 15 1 52 0 84 0 52 0 27 0 33 0 39 0 79 0 O0 N 15 94 309 552 713 826 937 1054 1177 0 O0 E lO N 64 80 N 358 38 N 923 62 N 1593 10 N 2274 12 N 2975 24 N 3694 68 N 4409 76 N 5114 0 O0 N' 0 0 E 50 E 66 76 E 371 50 E 973 65 E 1686 10 E 2383 81E 3088 16 E 3811 58 E 4533 74 E 5248 24 N 76 49 E O7 N 75 12 E 95 N 71 29 E 75 N 70 53 E 28 N 72 35 E 35 N 74 29 E 20 N 75 46 E 95 N 76 33 E 58 N 77 2 E 10000.00 7637.49 7588.49 46 10 11000.00 8327.39 8278.39 45 41 11200.00 8467.59 8418.59 45 17 N 80 54 E 5948.49 N 80 I E 6672.26 N 79 11E 6814.88 0.17 0.31 O. O0 1290.10 N 5811.27 E 5952.75 N 77 29 E 1407.81 N 6525.51 E 6675.64 N 77 50 E 1433.75 N 6665.75 E 6818.21 N 77 52 E COMPUTATION DATE' 8-JUN-93 PAGE ARCO ALASKA INC. AGI - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY- MAY-lO-1993 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 49 O0 149 O0 249 O0 349 O0 449 01 549 04 649 16 749 72 850 95 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 7O0.00 0 0 N 0 0 E 0 7 S 73 37 E 0 18 S 61 33 E 0 19 S 63 I E 0 29 S 69 47 E I 3 S 86 25 E I 41 N 83 10 E 4 17 N 74 2 E 7 37 N 74 27 E N 76 9 E 800.00 10 2 0.00 0 O4 0 32 0 72 1 23 2 32 4 54 9 32 19 74 35 36 0 O0 0 21 0 07 0 08 0 42 0 95 1 44 3 62 3 12 2 45 0 O0 N 0 04S 0 25 S 0 47 S 0 71S 0 95S 0 83S 0 16 N 3 13 N 7 05 N 0 O0 E 0 05 E 037 E 0 82 E 1 38 E 253 E 476 E 945 E 19.50 E 34.65 E 0.00 N 0 0 E 0.06 S 51 44 E 0.44 S 55 59 E O.95 S 6O 7 E I 55 S 62 34 E 2 71 S 69 23 E 4 84 S 8O 6 E 9 45 N 89 1E 19 75 N 8O 52 E 35 36 N 78 30 E 952 95 949.00 go0.o0 12 48 1055 89 1049.00 1000 O0 14 9 1159 06 1149.00 1100 1262 58 1249.00 1200 1366 58 1349.00 1300 1470 48 1449.00 1400 1574 24 1549.00 1500 1678.75 1649.00 1600 1785.01 1749.00 1700 1892.81 1849.00 1800 O0 14 22 O0 15 45 O0 16 2 O0 15 27 O0 15 40 O0 18 26 O0 20 37 O0 24 8 N 74 13 E N 73 8 E N 73 31E N 73 2O E N 73 34 E N 75 15 E N 77 13 E N 76 7 E N 74 4 E N 76 23 E 55 36 79 62 104 83 131 44 159 85 187 93 215 54 245 85 281 62 321 66 2 87 0 26 0 65 0 97 0 34 0 66 1 25 3 31 1 3O 5 49 12 05 N 19 26 33 42 49 56 63 72 82 54.07 E O1N 77.46 E 79 26 N 101.77 E 105 87 N 127.43 E 131 04 N 154.81E 160 67 N 181.97 E 188 26 N 208:83 E 216 02 N 238.40 E 246 41 N 273.06 E 282 88 N 311.85 E 322 55 40 N 77 26 E 76 N 76 13 E 11 N 75 32 E 85 N 75 7 E 42 N 74 49 E 62 N 74 44 E 28 N 74 55 E 59 N 75 12 E 50 N 75 9 E 67 N 75 7 E 2005.13 1949 O0 1900 O0 29 52 2122.43 2049 2240.63 2149 2360 07 2249 2483 51 2349 2610 09 2449 2739 74 2549 2875 71 2649 3016 80 2749 3160 06 2849 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 28O0 O0 32 11 O0 32 19 O0 34 30 O0 37 9 O0 38 27 O0 4O 49 O0 44 27 O0 45 17 O0 45 59 N 72 48 E N 68 0 E N 69 0 E N 7O 54 E N 71 13 E N 70 29 E N 67 26 E N 68 3 E N 66 55 E 372 53 432 81 494 64 558 94 630 52 707 27 788 23 878 25 975 70 N 67 21E 1075.73 5 96 0 3O 0 65 2 84 1 52 2 17 2 32 1 30 1 32 0 94 95.62 N 361 22 E 373.67 N 75 lO E 117.29 N 418 140.38 N 477 163.00 N 538 186.22 N 606 211.29 N 680 241.42 N 757 276.62 N 842 314.03 N 934 354.34 N 1028 54 E 434.67 N 74 21E 18 E 497.40 N 73 36 E 41E 562.55 N 73 9 E 94 E 534,87 N 72 57 E 38 E 712.44 N 72 45 E 18 E 794.73 N 72 19 E 26 E 886.52 N 71 49 E 49 E 985.84 N 71 26 E 81E 1088.12 N 71 0 E 3305 28 2949 O0 2900.00 47 4 3453 3596 3739 3878 4016 4155 4295 4437 4578 29 3049 O0 3000.00 47 10 92 3149 O0 3100.00 45 42 54 3249 O0 3200.00 44 59 36 3349 O0 3300.00 42 49 28 3449 O0 3400.00 44 21 65 3549.00 3500.00 44 6 73 3649.00 3600.00 44 48 51 3749.00 3700.00 45 17 98 3849.00 3800.00 44 36 N 70 23 E 1179.10 N 72 22 E 1287.24 N 68 52 E 1388.79 N 69 1E 1488 71 N 73 33 E 1583 69 N 75 23 E 1678 32 N 76 20 E 1775 19 N 77 5 E 1873 15 N 75 24 E 1973 49 N 75 26 E 2073 29 2.09 3.46 0.19 1 09 3 17 0 55 0 68 0 67 0 74 0 67 392 58 N 1126 91 E 1193.33 N 70 48 E 426 461 498 530 555 579 601 625 650 28 N 1230 84 N 1327 35 N 1422 63 N 1512 49 N 1604 28 N 1698 80 N 1794 19 N 1891 53 N 1988 68 E 1302.41 N 70 54 E 42 E 1405.47 N 70 49 E 32 E 1507.10 N 70 41E 98 E 1603.33 N 70 40 E 63 E 1698.06 N 70 54 E 75 E 1794.81 N 71 10 E 22 E 1892.46 N 71 27 E 96 E 1992.58 N 71 43 E 77 E 2092.46 N 71 53 E COMPUTATION DATE' 8-JUN-93 PAGE 6 ARCO ALASKA INC. AGI - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' MAY-lO-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4718 36 3949 O0 3900 O0 43 55 4857 4995 5136 5278 5419 5559 5701 5845 5990 08 4049 64 4149 07 4249 34 4349 57 4449 95 4549 92 4649 40 4749 63 4849 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 43 46 O0 43 49 O0 45 25 O0 45 14 O0 44 46 O0 44 31 O0 45 59 O0 45 49 O0 4800.00 46 47 N 77 50 E 2170 2O N 78 25 E 2266 N 78 21E 2362 N 8O 57 E 2460 N 80 47 E 2561 N 81 23 E 2661 N 81 20 E 2760 N 81 10 E 2860 N 81 6 E 2963 N 80 30 E 3068 31 20 76 94 63 11 83 69 98 I 20 0 13 0 42 0 63 0 50 0 46 0 21 0 29 0 56 0 25 673 61 N 2083 07 E 2189 28 N 72 5 E 693 712 730 746 762 776 792 808 825 22 N 2177 49 n 2271 59 N 2368 65 N 2467 17 N 2566 85 n 2663 19 N 2763 O0 N 2865 O0 N 2969 19 E 2284 15 E 2380 03 E 2478 95 E 2578 46 E 2677 89 E 2774 47 E 2874 15 E 2976 07 E 3081 88 N 72 20 E 28 N 72 35 E 17 N 72 51E 42 N 73 10 E 24 N 73 28 E 85 N 73 45 E 77 N 74 0 E 90 N 74 15 E 56 N 74 28 E 6136 18 4949 O0 4900.00 46 30 6281 6427 6573 6718 6863 7010 7156 7302 7447 56 5049 39 5149 13 5249 16 5349 81 5449 06 5549 51 5649 76 5749 84 5849 O0 5000.00 46 28 O0 5100.00 46 42 O0 5200.00 46 20 O0 5300,.00 46 40 O0 5400.00 46 48 O0 5500.00 46 56 O0 5600.00 46 58 O0 5700.00 46 43 O0 5800.00 46 1 N 80 40 E 3174.72 N 80 50 E 3280 24 N 81 30 E 3386 N 81 51E 3492 N 81 59 E 3597 N 80 53 E 3703 N 80 53 E 3809 N 81 11E 3916 N 81 6 E 4023 N 8O 15 E 4128 34 28 23 08 79 75 43 51 0 12 0 57 0 29 0 55 0 70 0 36 0 34 0 15 0 42 0 26 842 35 N 3073 39 E 3186 74 N 74 40 E 859 875 890 905 921 938 955 971 988 38 N 3177 49 N 3282 75 N 3387 29 N 3491 48 N 3596 40 N 3701 21N 3807 61N 3912 55 N 4016 55 E 3291 45 E 3397 37 E 3502 39 E 3606 04 E 3712 42 E 3818 08 E 3925 53 E 4031 26 E 4136 71 N 74 52 E 20 N 75 4 E 52 N 75 16 E 85 N 75 28 E 23 N 75 38 E 52 N 75 46 E 08 N 75 55 E 37 N 76 3 E 13 N 76 10 E 7592 44 5949 O0 5900 O0 46 28 7737 7882 8025 8168 8312 8455 8598 8742 8886 81 6049 43 6149 95 6249 91 6349 73 6449 74 6549 60 6649 76 6749 36 6849 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 650O O0 6600 O0 67OO O0 6800 O0 46 28 O0 46 5 O0 45 32 O0 46 6 O0 45 49 O0 45 34 O0 45 33 O0 46 10 O0 45 32 N 80 17 E 4232 96 N 8O 32 E 4338 N 8O 33 E 4442 N 8O 30 E 4545 N 80 27 E 4648 N 81 2 E 4751 N 80 51E 4853 N 80 28 E 4955 N 78 45 E 5059 N 79 0 E 5162 46 92 85 O0 35 55 55 38 43 0 39 0 18 0 24 0 27 0 52 0 41 0 43 1 38 0 29 0 68 1006.14 N 4119 22 E 4240.32 N 76 16 E 1023.69 N 4223 1040.85 N 4326 1057.72 N 4427 1074.60 N 4528 1091.20 N 4630 1106.92 N 4731 1123.34 N 4832 1142.85 N 4934 1162.94 N 5035 26 E 4345.55 N 76 22 E 32 E 4449.76 N 76 28 E 87 E 4552 45 N 76 34 E 63 E 4654 38 N 76 39 E 65 E 4757 48 N 76 44 E' 67 E 4859 42 N 76 50 E 36 E 4961 21 N 76 55 E 35 E 5064 97 N 76 58 E 42 E 5167 97 N 77 0 E 9028 17 6949 O0 6900 O0 44 43 9167 9304 9444 9586 9728 9872 10016 10161 10306 67 7049 78 7149 76 7249 61 7349 98 7449 48 7549 62 7649 52 7749 78 7849 O0 7000 O0 43 4O O0 7100 O0 43 41 O0 7200 O0 45 11 O0 7300 O0 45 7 O0 7400 O0 45 41 O0 7500 O0 45 54 O0 7600 O0 46 10 O0 7700.00 46 29 O0 7800.00 46 20 N 79 57 E 5262 96 N 81 16 E 5360 N 80 45 E 5453 N 80 37 E 5551 N 81 13 E 5652 N 80 52 E 5753 N 80 53 E 5856 N 80 52 E 5960 N 80 47 E 6065 N 80 30 E 6170 21 97 gl 48 8O 69 47 31 65 0 89 1 2O 1 89 I 13 0 21 0 40 0 12 0 25 0 24 0 25 1181 26 N 5134 28 E 5268 41 N 77 3 E 1197 1211 1227 1243 1259 1275 1292 1308 1325 15 N 5230 44 N 5322 64 N 5419 45 N 5518 33 N 5618 63 N 5720 01N 5823 73 N 5926 89 N 6030 23 E 5365 93 E 5459 54 E 5556 88 E 5657 97 E 5758 60 E 5861 10 E 5964 62 E 6069 57 E 6174 49 N 77 6 E 05 N 77 11E 84 N 77 14 E 23 N 77 18 E 36 N 77 22 E 10 N 77 26 E 71 N 77 29 E 39 N 77 33 E 60 N 77 36 E COMPUTATION DATE: 8-JUN-93 PAGE 7 ARCO ALASKA INC. aGI - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: MAY-lO-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/iO0 FEET FEET FEET DEG 10451.75 7949 O0 7900.00 46 24 N 80 30 E 6275 61 10597.36 8049 O0 8000.00 47 7 N 80 48 E 6381 44 10743.25 8149 O0 8100.00 46 26 N 80 49 E 6487 62 10887.58 8249 O0 8200.00 45 49 N 80 30 E 6591 68 11030.94 8349 O0 8300.00 45 43 N 79 49 E 6694 40 11173.58 8449 O0 8400.00 45 17 N 79 11E 6796 11 11200.00 8467 59 8418.59 45 17 N 79 11 E 6814 88 0.43 1343.28 N 6134.09 E 6279 44 N 77 39 E 1.06 1360.77 N 6238.47 E 6385 15 N 77 42 E 0.29 1377,36 N 6343.38 E 6491 19 N 77 45 E 0.44 1394.10 N 6446.10 E 6595 13 N 77 48 E 0.35 1411.68 N 6547.31 E 6697 77 N 77 50 E 0.00 1430.23 N 6647.31 E 6799 44 N 77 51 E 0.00 1433.75 N 6665.75 E 6818 21 N 77 52 E -) ARCO ALASKA INC. AGI - $ PRUDHOE BAY NORTH SLOPE, ALASKA MARKEr GCT LAST READING TD COMPUTATION DATE: 8-JUN-93 PAGE 8 DATE OF SURVEY: MAY-lO-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2173' FSL, 2495' FEL, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11149.00 8431.71 8382.71 1426.95 N 6630.16 E 11200.00 8467.59 8418.59 1433.75 N 6665.75 E ARCO ALASKA INC. AGI - 6 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 8-JUN-93 PaGE 9 DATE OF SURVEY: MAY-lO-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER · ~~~ STRATIGRAPHIC SUMMARY ~~~ SURFACE LOCATION = 2173' FSL, 2495' FEL, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11200.00 8467.59 8418.59 1433.75 N 6665.75 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11200.00 8467.59 8418.59 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6818.21 N 77 52 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA INC. FIELD PRUDHOE BAY WELL AGI - 6 COUNTRY USA RUN I DATE LOGGED 10 - MAY - 93 DEPTH UNIT FEET REFERENCE 93225 All Interpretations are opinions based on Inferences from electrical or other measurements and wa cannot, and do not guarantee tile accuracy or correctness of any Interpretations. and we shall not. except In the case of gross or wllfutl negligence on our part, be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our offlcer~, agents or employees. These interpretations are also subject to our (~eneral Terms and Conditions as set out In our current pdce Schedule. -zz-;.;_--.' 7 '. ii ~. : ." ' I~ELL: AGI-6 (2173' FSL, 2495' FEL, SEC 36, T12#, R14E) HORIZ~IITAL PRO~CTZOI 6OOO 4OOO 2OOO -2000 -4000 sou'r~ -8000 ~4000 WF_~T ~CALE = I / 2000 :.:: :::; :::~ :::~ :::: ........ :.:. :::: :,: ........ ....... ~ ..... ~ ........ ~.~ i.~ ~;~:..~ii.~. ~:~i ~.~:i ~..~.~ iii~ ii!, ~:. 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' , :. i: i :ii i:i; . - : ...... ~ ...... .:.. ::.: ~ :... !.: ......... · ;.i. ~.i: ' :..: :.:i ilii i,,i i.:i :: ..... :i .:i .ii~. i.i ..... :: :.!: : ~_ .. : : . . : ---- . : · :,, .. i i ..i, .!.!.. :.~ ....... · ....... : :.i .... ........ :i..i. i!ii ..~':. ; ..... i ~.!i.i. .i :!~ : : · ............ ~__. ; : · : ........ . .*. : ! .... ~._~_ ....... ::' . .. ~=~ ~.~ : ., · .~. , ; .~ ~ ...... i ;!; ii,; :;~; i~;: i.; ~ .... ~ ..il ......... .... ::~.: ..... i:.:...;.i:: i,.i..i .... :..i.i..., .,,..: .;; ................ : ................ ! *- ::. .... .... :: -' ::i! !i;! :!:! ~ ...... ~ ---- ..... : ........ : · : .. :: : ~ :i i: : · ~ .~ i,! i ....... i..i i ! :.~ !..i.,...i.!,: i.. i :.! .. i ~ .! : i i : : : ; : ~ : : ~ : . . i . . : ..: . . i . ., : . .: ; ..i...~...i...i...!..i ............. : L.:..:..i.;;.i .... :.::. ;!i.~.:;.. .;i; ::: :: i:: ''': i::' :'; · : :.:: : '-: · : : ~ .............. ~ .......... i--~..-~ .... i...i..-i...! ..... i...i.--i-..! .... i-..i-..i..i .... i...~..i: .i..i:.: : i.i .i...i .............. i ....... i..i .... :..i..~.: .... i.!.: i..iii .... !-~'!-ii'!.!-"i"i-i'-'i'~-!.i-.!..! i'!-.-i--!-.i.'!.i!, ii'!: i~ii ~':: '!!'! :::i "ii'~i.i!:' ~,",:' -2000 0 2000 4000 6000 8000 10000 12000 ilELL: AGI-6 (2173' FSL, 2495' FEL, SEC 36, T12N, R14E) VERTICAL PRO~IECTIOII -4000 .2000 0 0 2000 4000 6000 8000 10000 12000 ::ii~ii:.i.L..ili i}i.i..}.i.~x.} }[.i~. i;;.~;..~i;.i;i..i.~. ii; i!!i-.i.!,!..i..i. -.i.!~-i- ?i;?;?3ooo'?ii?, : . : . ! i i i ~ i i i i: ! : i i i ~ ! ;x! 40001 . . . ..... · : : ! .... ~ ! i ~ : ~QOI~) i i i i ~ ~ i ~ ~ ! ! i : ~ i i i i !- ! : : ! -~ i i .............. L; .... : ..... ; .... ........ ? ..... ~ , ~ ! ~ , ! ~ i i .... i i t i i-×!ScOr,.)i : : . . i i i : .~ ; : :. ........... . :: :: ::.. :.:: :~:: :,:: : ..... ~ ~.;..~ .~.~: !!~i i!i~ i~! x! ............. . : i ! i. : . ! :'i : i i i' ' '~ i i!:i ,. m..~ .: _ _ ...................... : · . . : . . : ~ : ~ ~ : : ~ : ~ .~ ~ ~ ~..~ ~ ~ ~ ~ ~ ~ : ~ · : : :: : .~ :~ ~ '~ .... .::. ,.: ..... : .. :: , .. . . .............. ' ''::.2 , ~ -~- : : . : :.:: ~ .: .:.: :: ...... : : . ............. , ..................... ..... ~ ................. :..~.~ ....... :..~ ~...}..}.~.~'.~ ~.~ ........... ' :~3~ ~ ~:~:~:~m(~ ~-.2-;~' ~;~ ~ ~ ............. . ............. , : : ~ . . : ~ ~...~..~.~ .... ~..~..:..~.. ~.;.:.~.i.~..~.~ ...... : ~ : ~ ~..: ~ ~ : ; ~ ,.. : : ' ~::I}~:~ :;:~ ~:~ }~ :~:' : ·: '' : ' :. ,:;:.: ..: ::, :: : ........... ~ , , , ::: :::, .: : :::: ::~. : .. . : ..... ~..:_.:._: ...... i...h..~..: ...... :.4.:~ .... ~...h,:..~ h~..4..: ..... :..~4 :..4 .... :: ...... ~...~...~ ..... ::,4: .......... 80.00 PROJECTION ON VERTICAL PLANE 260.00 80.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE -- I / 2000 INtFT Eeo Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 ORI611VAL EASTMAN TELECO MWD SURVEY APEX GAS INJECTION PAD PRUDHOE BAY DRILLING GROUP Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · MWD Survey Listing · Composite 100' MD Interpolated · Composite 100' TVD Interpolated Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : Apex Gas Injection Pad : : : Feb. 16, 1993 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. ........................... COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : No Interpolation Date Feb. 16, 1993 Filename : AGI6 Plane of Vertical Section : 79.9° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-6 +0° 0' 0' ' (T) Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : No Interpolation Page 1 of 2 Date Feb. 16, 1993 Filename : AGI6 MD C~L INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 385 385 0.4 98.7 385 598 213 2.7 80.8 598 778 180 8.8 77.3 777 958 180 13.2 76.9 954 VS ft 0 1 7 25 59 LAT ft 0 -0 0 4 12 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 1 0.1 0.1 25.6 7 1.1 1.1 -8.4 25 3.4 3.4 -1.9 58 2.4 2.4 -0.2 1142 184 14.1 77.3 1132 1329 187 16.6 76.6 1313 1517 188 15.7 80.4 1493 1704 187 19.5 80.1 1671 1892. 188 23.3 82.9 1846 103 152 204 261 329 22 100 0.5 0.5 0.2 33 149 1.3 1.3 -0.4 43 200 0.7 -0.5 2.0 53 256 2.0 2.0 -0.2 63 323 2.1 2.0 1.5 2080 188 31.6 76.2 2013 2267 187 32.3 75.5 2172 2454 187 36.7 78.0 2326 2641 187 38.8 77.6 2474 2828 187 43.3 76.2 2615 416 515 620 735 857 .79 408 4.7 4.4 -3.6 103 504 0.4 0.4 -0.4 128 607 2.5 2.4 1.3 152 719 1.1 1.1 -0.2 180 839 2.5 2.4 -0.7 3015 187 45.3 75.5 2749 3295 280 46.9 80.4 2943 3540 245 46.0 70.0 3112 3861 321 43.6 76.6 3340 4045 184 44.3 76.6 3472 988 1189 1366 1590 1718 212 254 299 364 393 965 1.1 1.1 -0.4 1163 1.4 0.6 1.7 1334 3.1 -0.4 -4.2 1550 1.6 -0.7 2.1 1674 0.4 0.4 0.0 4405 360 45.4 76.6 3727 4701 296 43.9 78.0 3938 4983 282 43.9 78.3 4141 5265 282 45.4 82.2 4342 5546 281 44.6 81.8 4541 1971 2179 2374 2572 2771 452 498 538 572 599 1921 0.3 0.3 0.0 2124 0.6 -0.5 0.5 2316 0.1 0.0 0.1 2511 1.1 0.5 1.4 2708 0.3 -0.3 -0.1 5825 279 45.8 81.8 4737 6106 281 46.8 81.8 4931 6389 283 46.9 82.2 5125 6669 280 46.5 83.2 5317 6951 282 46.9 82.5 5510 2969 3172 3378 3582 3787 628 657 685 711 737 2904 0.4 0.4 0.0 3105 0.4 0.4 0.0 3309 0.1 0.0 0.1 3511 0.3 -0.1 0.4 3715 0.2 0.1 -0.2 7233 282 46.8 82.2 5703 7512 279 46.3 81.1 5895 7794 282 46.4 81.8 6090 8074 280 45.6 80.4 6284 8356 282 45.8 82.2 6481 3992 4195 4399 4600 4802 764 793 824 855 885 3919 0.1 -0.0 4119 0.3 -0.2 4321 0.2 0.0 4520 0.5 -0.3 4719 0.5 0.1 -0.1 -0.4 0.2 -0.5 0.6 8637 281 45.8 80.8 6677 8918 281 45.4 79.4 6874 9199 281 43.3 82.5 7075 9480 281 45.4 81.8 7276 9781 301 45.9 81.8 7486 5OO3 5204 5400 5596 5811 915 950 981 1008 1038 4919 0.4 0.0 5116 0.4 -0.1 5310 1.1 -0.7 5505 0.8 0.7 5718 0.2 0.2 -0.5 -0.5 1.1 -0.2 0.0 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : No Interpolation MD C~L INC DIR TVD VS ft ft deg deg ft ft 10062 281 46.3 81.5 7681 6014 10343 281 46.4 81.5 7875 6217 10520 177 46.7 81.1 7996 6346 LAT ft 1068 1098 1117 Page 2 Date Feb. Filename of 2 16, 1993 : AGI6 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 5918 0.2 0.1 -0.1 6119 0.0 0.0 0.0 6246 0.2 0.2 -0.2 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 6346 ft 79.9° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By · Apex Gas Injection Pad : : : Feb. 16, 1993 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of MD Plane of Vertical Section : 79.9° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER. Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-6 +0° 0' 0'' (T) Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Pad Page 1 of 3 Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of MD MD ft 0 100 200 3OO 400 5OO 600 700 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OOO 3100 3200 3300 3400 35OO 3600 3700 3800 3900 CkL INC DIR TVD VS ft deg deg ft ft 0 0.0 0.0 0 0 100 0.1 25.6 100 0 100 0.2 51.3 200 1 100 0.3 76.9 300 1 100 0.6 97.4 400 2 100 1.6 89.0 500 4 100 2.8 80.8 600 7 100 6.2 78.8 699 17 100 9.3 77.3 799 29 100 11.8 77.0 897 48 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 13.4 77.0 994 69 13.9 77.2 1092 93 14.9 77.1 1188 118 16.2 76.7 1285 144 16.3 78.0 1381 172 15.8 80.1 1477 200 17.4 80.3 1572 229 19.4 80.1 1668 260 21.4 81.5 1761 296 23.7 82.6 1854 333 28.1 79.1 1942 379 31.7 76.1 2030 426 32.0 75.8 2115 479 33.1 75.9 2199 533 35.4 77.3 2281 590 37.2 77.9 2362 648 38.3 77.7 2441 710 40.2 77.2 2518 773 42.6 76.4 2594 839 44.1 75.9 2666 907 45.1 75.6 2738 977 45.8 77.0 2808 1049 46.4 78.7 2877 1121 46.9 80.2 2946 1193 46.5 75.9 3015 1265 46.1 71.7 3084 1337 45.6 71.2 3154 1408 44.8 73.3 3225 1477 44.1 75.3 3296 1547 43.7 76.6 3368 1617 LAT ft 0 -0 -0 -0 -0 14 19 25 31 37 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.1 0.1 25.6 1 0.1 0.1 25.6 1 0.2 0.1 25.6 2 0.3 0.3 20.5 4 1.1 1.1 -8.4 7 1.2 1.1 -8.3 17 3.4 3.4 -1.9 29 3.2 3.2 -1.6 47 2.4 2.4 -0.2 68 1.6 1.6 -0.0 91 0.5 0.5 0.2 115 1.0 1.0 -0.1 141 1.3 1.3 -0.4 168 0.4 0.0 1.3 42 195 0.7 -0.5 2.0 47 225 1.6 1.6 0.2 53 254 2.0 2.0 -0.2 58 290 2 . 1 2 . 0 1.4 64 327 2.3 2.2 1.1 72 82 95 108 121 133 146 161 1'75 192 209 224 239 254 273 291 311 331 351 370 372 4.7 4.4 -3.6 419 3.9 3.6 -2.9 470 0.4 0.4 -0.4 522 1.0 1.0 0.2 578 2.5 2.4 1.3 635 1.8 1.8 0.6 695 1.1 1.1 -0.2 757 1.9 1.9 -0.5 821 2.5 2.4 -0.7 888 1.5 1.4 -0.5 955 1.1 1.1 -0.4 1025 1.2 0.6 1.4 1096 1.4 0.6 1.7 1166 1.2 0.5 1.5 1236 3.1 -0.4 -4.2 1306 3.1 -0.4 -4.2 1374 0.7 -0.6 -0.5 1442 1.6 -0.7 2.1 1509 1.6 -0.7 2.1 1577 0.9 -0.3 1.3 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Pad Page 2 of 3 Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 4000 100 44.1 76.6 3440 1686 4100 100 44.5 76.6 3511 1756 4200 100 44.8 76.6 3582 1827 4300 100 45.1 76.6 3653 1897 4400 100 45.4 76.6 3724 1967 4500 100 44.9 77.0 3795 2038 4600 100 44.4 77.5 3866 2108 4700 100 43.9 78.0 3937 2178 4800 100 43.9 78.1 4009 2247 4900 100 43.9 78.2 4081 2317 5000 100 44.0 78.5 4153 2386 5100 100 44.5 79.9 4224 2456 5200 100 45.1 81.3 4296 2527 5300 100 45.3 82.2 4367 2597 5400 100 45.0 82.0 4437 2668 5500 100 44.7 81.9 4508 2738 5600 100 44.8 81.8 4579 2809 5700 100 45.3 81.8 4649 2880 5800 100 45.7 81.8 4720 2951 5900 100 46.1 81.8 4789 3023 6000 100 46.4 81.8 4858 3095 6100 100 46.8 81.8 4927 3167 6200 100 46.8 81.9 4996 3240 6300 100 46.9 82.1 5064 3313 6400 100 46.9 82.2 5132 3386 6500 100 46.7 82.6 5201 3459 6600 100 46.6 83.0 5270 3531 6700 100 46.5 83.1 5338 3604 6800 100 46.7 82.9 5407 3677 6900 100 46.8 82.6 5475 3750 7000 100 46.9 82.4 5544 3822 7100 100 46.8 82.3 5612 3895 7200 100 46.8 82.2 5681 3968 7300 100 46.7 81.9 5749 4041 7400 100 46.5 81.5 5818 4113 7500 100 46.3 81.1 5887 4186 7600 100 46.3 81.3 5956 4258 7700 100 46.4 81.6 6025 4331 7800 100 46.4 81.8 6094 4403 7900 100 46.1 81.3 6163 4475 LAT DEP D'LEG BUILD TURN ft ft °/100 °/100 °/100 386 1644 0.4 0.4 0.0 402 1712 0.3 0.3 0.0 4,19 1781 0.3 0.3 0.0 435 1849 0.3 0.3 0.0 451 1918 0.3 0.3 0.0 467 1987 0.6 -0.5 0.4 482 2055 0.6 -0.5 0.5 498 2124 0.6 -0.5 0.5 512 2191 0.1 -0.0 0.1 526 2259 0.1 0.0 0.1 540 2327 0.2 0.1 0.3 552 2397 1.1 0.5 1.4 564 2466 1.1 0.5 1.4 575 2535 0.7 0.2 0.8 585 2605 0.3 -0.3 -0.1 595 2675 0.3 -0.3 -0.1 605 2746 0.1 0.1 -0.1 615 2816 0.4 0.4 0.0 625 2886 0.4 0.4 0.0 635 2957 0.4 0.4 0.0 6.46 3029 0.4 0.4 0.0 656 3100 0.4 0.4 0.0 666 3173 0.1 0.1 0.1 676 3245 0.1 0.0 0.1 686 3317 0.1 0.0 0.2 696 3389 0.3 -0.1 0.4 705 3461 0.3 -0.1 0,4 714 3534 0.1 -0.1 0.2 723 3606 0.2 0.1 -0.2 732 3678 0.2 0.1 -0.2 741 3750 0.1 0.1 -0.2 751 3823 0.1 -0.0 -0.1 761 3895 0.1 -0.0 -0.1 771 3967 0.3 -0.1 -0.3 782 4039 0.3 -0.2 -0.4 792 4111 0.3 -0.2 -0.4 803 4182 0.1 0.0 0.2 814 4254 0.2 0.0 0.2 824 4325 0.1 0.0 0.2 836 4396 0.5 -0.3 -0.5 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Pad Page 3 of 3 Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 8000 100 45.8 80.8 6233 4547 8100 100 45.6 80.6 6302 4618 8200 100 45.7 81.2 6372 4690 8300 100 45.8 81.8 6442 4762 8400 100 45.8 82.0 6512 4833 8500 100 45.8 81.5 6582 4905 8600 100 45.8 81.0 6651 4976 8700 100 45.7 80.5 6721 5048 8800 100 45.6 80.0 6791 5119 8900 100 45.4 79.5 6861 5191 9000 100 44.8 80.3 6932 5261 9100 100 44.0 81.4 7004 5331 9200 100 43.3 82.5 7075 5401 9300 100 44.1 82.2 7147 5471 9400 100 44.8 82.0 7218 5540 9500 100 45.4 81.8 7290 5611 9600 100 45.6 81.8 7359 5682 9700 100 45.8 81.8 7429 5754 9800 100 45.9 81.8 7499 5825 9900 100 46.1 81.7 7568 5897 10000 100 46.2 81.6 7638 5969 10100 100 46.3 81.5 7707 6041 10200 100 46.3 81.5 7776 6114 10300 100 46.4 81.5 7845 6186 10400 100 46.5 81.4 7914 6258 10500 100 46.7 81.1 7983 6331 10520 20 46.7 81.1 7996 6346 LAT ft 847 858 869 879 890 901 911 923 935 948 959 970 981 990 1000 1010 1020 1030 1040 1051 1061 1072 1082 1093 1104 1115 1117 DEP D ' LEG BUILD TURN o o o ft /100 /100 /100 4467 0.5 -0.3 -0.5 4538 0.2 -0.2 -0.2 4609 0.5 0.1 0.6 4680 0.5 0.1 0.6 4751 0.1 0.0 0.i 4822 0.4 0.0 -0.5 4892 0.4 0.0 -0.5 4963 0.4 -0.1 -0.5 5033 0.4 -0.1 -0.5 5104 0.4 -0.1 -0.5 5173 0.9 -0.6 0.8 5242 1.1 -0.7 1.1 5311 1.1 -0.7 t.1 5380 0.8 0.7 -0.2 5450 0.8 0.7 -0.2 5519 0.6 0.6 -0.2 5590 0.2 0.2 0.0 5661 0.2 0.2 0.0 5732 0.2 0.2 -0.0 5803 0.2 0.1 -0.1 5874 0.2 0.1 -0.1 5945 0.1 0.1 -0.1 6017 0.0 0.0 0.0 6089 0.0 0.0 0.0 6160 0.1 0.1 -0.1 6232 0.2 0.2 -0.2 6246 0.3 0.2 -0.3 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 6346 ft 79.9° TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : Apex Gas Injection Pad : : : Feb. 16, 1993 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of TVD Plane of Vertical Section : 79.9° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-6 +0° 0' 0'' (T) Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Pad Page 1 Date Feb. Filename Interpolated of 3 16, 1993 : AGI6 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 100 100 0.1 25.6 100 200 100 0.2 51.3 200 300 100 0.3 76.9 300 400 100 0.6 97.4 400 5OO 600 701 802 903 1006 1109 1212 1316 1420 1524 1629 1735 1842 1952 2065 2182 2301 2422 2548 2676 2808 2947 3089 3233 3378 3523 3664 3805 3945 4084 4225 4366 4507 4648 100 100 101 101 102 102 103 103 104 104 104 105 106 107 110 113 117 119 121 125 128 133 139 142 144 145 145 141 141 140 139 141 141 141 141 VS ft 0 0 1 1 2 LAT ft 0 -0 -0 -0 -0 DEP D'LEG ft °/100 0 0.0 0 0.1 1 0.1 1 0.2 2 0.3 1.6 89.0 500 4 0 4 1.1 2.8 80.8 600 7 1 7 1.2 6.2 78.8 700 17 3 17 3.4 9.4 77.2 800 29 5 29 3.2 11.9 77.0 900 49 10 48 2.4 13.4 77.0 1000 13.9 77.2 1100 15.0 77.0 1200 16.4 76.6 1300 16.2 78.4 1400 15.8 80.4 1500 18.0 80.2 1600 20.1 80.6 1700 22.3 82.2 1800 26.0 80.7 1900 30.9 76.7 2000 32.0 75.8 2100 33.1 76.0 2200 36.0 77.6 2300 37.8 77.8 2400 39.6 77.3 2500 42.8 76.3 2600 44.6 75.8 2700 45.7 76.8 2800 46.5 79.3 2900 71 14 69 1.5 95 20 93 0.5 121 26 119 1.1 149 32 145 1.3 177 38 173 0.5 206 238 272 311 357 BU I LD TURN °/100 °/100 0.0 0.0 0.1 25.6 0.1 25.6 0.1 25.6 0.3 20.5 1.1 -8.4 1.1 -8.3 3.4 -1.9 3.2 -1.5 2.4 -0.2 1.5 -0.0 0.5 0.2 1.1 -0.2 1.3 -0.4 -0.2 1.7 44 202 0.6 -0.3 1.9 49 233 2.0 2.0 -0.2 54 267 2.0 2.0 0.3 60 305 2.1 2.0 1.5 68 351 3.4 3.3 -1.3 46.6 76.9 3000 46.1 70.7 3100 45.1 72.6 3200 44.0 75.4 3300 43.9 76.6 3400 409 78 402 4.7 4.4 -3.6 470 92 461 1.0 0.9 -0.8 534 108 523 0.9 0.9 0.1 602 123 590 2.5 2.4 1.3 678 140 663 1.4 1.4 0.2 757 157 741 1.5 844 177 826 2.5 940 200 919 1.3 1041 223 1018 1.0 1145 244 1119 1.4 44.4 76.6 3500 44.9 76.6 3600 45.3 76.6 3700 44.9 77.1 3800 44.2 77.7 3900 1.5 -0.4 2.4 -0.7 1.3 -0.4 0.8 0.7 0.6 1.7 1745 400 1701 0.4 0.4 0.0 1844 423 1798 0.3 0.3 0.0 1944 446 1895 0.3 0.3 0.0 2043 4'68 1991 0.4 -0.3 0.3 2141 490 2088 0.6 -0.5 0.5 1249 1353 1452 1551 1648 269 1221 1.2 0.0 -1.7 295 1322 3.1 -0.4 -4.2 324 1418 1.2 -0.7 1.3 352 1512 1.6 -0.7 2.1 377 1607 0.6 -0.1 0.8 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Pad Page 2 of 3 Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of TVD MD CkL INC DIR TVD VS LAT ft ft deg deg ft ft ft 4787 139 43.9 78.1 4000 2238 510 4926 139 43.9 78.2 4100 2335 530 5066 140 44.3 79.4 4200 2432 548 5206 141 45.1 81.4 4300 2531 565 5347 141 45.2 82.1 4400 2630 580 5489 141 44.8 81.9 4500 2730 5630 142 45.0 81.8 4600 2831 5772 142 45.6 81.8 4700 2931 5916 144 46.1 81.8 4800 3034 6061 145 46.6 81.8 4900 3139 6206 146 46.8 81.9 5000 3245 6353 146 46.9 82.1 5100 3352 6499 146 46.7 82.6 5200 3458 6644 146 46.5 83.1 5300 3564 6790 146 46.7 82.9 5400 3670 6936 146 46.9 82.5 5500 3776 7082 146 46.9 82.4 5600 3882 7228 146 46.8 82.2 5700 3989 7374 145 46.5 81.6 5800 4094 7519 145 46.3 81.1 5900 4200 7664 145 46.4 81.5 6000 4305 7809 145 46.4 81.7 6100 4409 7953 144 45.9 81.0 6200 4513 8097 144 45.6 80.5 6300 4616 8240 143 45.7 81.5 6400 4719 8383 143 45.8 82.1 6500 4821 8526 143 45.8 81.4 6600 4924 8670 143 45.8 80.6 6700 5026 8813 143 45.5 79.9 6800 5129 8955 142 45.1 79.8 6900 5229 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 2183 0.3 -0.2 0.2 2277 0.1 0.0 0.1 2373 0.7 0.3 0.9 2470 1.1 0.5 1.4 2568 0.4 0.1 0.5 594 2667 0.3 -0.3 -0.1 608 2767 0.1 0.1 -0.1 622 2867 0.4 0.4 0.0 637 2969 0.4 0.4 0.0 652 3072 0.4 0.4 0.0 667 3177 0.2 0.1 0.1 682 3283 0.1 0.0 0.1 695 3388 0.2 -0.1 0.3 709 3494 0.3 -0.1 0.4 722 3599 0.1 0.1 -0.1 735 3704 0.2 0.1 -0.2 749 3810 0.1 -0.0 -0.1 764 3915 0.1 -0.0 -0.1 779 4020 0.3 -0.2 -0.4 794 4124 0.3 -0.2 -0.4 810 4228 0.2 0.0 0.2 825 4332 0.1 0.0 0.2 841 4434 0.5 -0.3 -0.5 857 4536 0.3 -0.2 -0.3 873 4637 0.5 0.1 0.6 888 4739 0.3 0.1 0.4 904 4840 0.4 0.0 -0.5 919 4942 0.4 -0.0 -0.5 937 5042 0.4 -0.1 -0.5 954 5142 0.3 -0.3 -0.1 9095 140 44.1 81.3 7000 5327 969 9234 140 43.6 82.4 7100 5425 984 9374 140 44.6 82.1 7200 5523 998 9515 141 45.5 81.8 7300 5621 1011 9658 143 45.7 81.8 7400 5724 1026 9801 143 45.9 81.8 7500 5826 1040 9945 144 46.1 81.6 7600 5930 1056 10090 144 46.3 81.5 7700 6034 1071 10235 145 46.4 81.5 7800 6139 1086 10380 145 46.5 81.4 7900 6244 1102 5238 1.1 -0.7 1.1 5335 0.6 -0.4 0.8 5432 0.8 0.7 -0.2 5530 0.6 0.6 -0.2 5631 0.2 0.2 0.0 5732 0.2 0.2 -0.0 5835 0.2 0.1 -0.1 5938 0.1 0.1 -0.1 6042 0.0 0.0 0.0 6146 0.1 0.1 -0.1 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Location : Apex Gas Injection Pad : : Page 3 of 3 Date Feb. 16, 1993 Filename : AGI6 Interpolated 100 ft of TVD MD C~L INC DIR TVD ft ft deg deg ft 10520 140 46.7 81.1 7996 VS ft 6346 LAT ft 1117 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 6246 0.3 0.2 -0.3 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 6346 ft 79.9° ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: 'ARC~ FINAI~ ~-L~ 5-03A ct'~-5~5 * 9-31A 4/16 -17/93 qb-'b~ · · 9-36A 3/31.4/6/93 ~2_~!~ I *** 16-4A 02-19-93 c~.~oz AGI-5 05-10-93 ~ ~--C9 AGI-6 05-10-93 Slim I GR ~0~ ~ i~ Run~l&2, MWD: GR ~ ~q~ ~" SSTVD ~ oo~o- I GR/CCL %0o-- 2"&5" Aha Ana R~_m 1, l"&2" Arias R~_m 1, 5" Sch Run 1, 5" Sch Please sign and return the attached copy as receipt of data. .I ~ / .,'~.~ ~.,..- RECEIVED BY Have A Nice Day! John DeGrey AT0-1529 APPROVED__...~ Trans# 94005 # CENTRAL FILES # CHEVRON #D&M # ANO8 GEOLOGY # EXXON # MOBIL # PHILLIPS # PB WELL FILES # BPX # STATE OF ALASKA The corrected API# for 9-31A is 50-029-21396-01. The corrected API# for 9o36A is 50-029-21429-01. The corrected API# for 16-4A is 50-029-20561-01. A'l~ka Oil ,& Gas Cons. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 4-17-93 o~ 10-7-93 pa 3-31-93 11/18-30/92 11-23-92 4-15-93 1-29-93 2-13-93 4-28-93 3-6-93 5-8-93 3-28-93 MWD: DPR/GR Dn /AC/CN/GR MWD: DPR/GR MWD "tT~-~O MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR. MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR Job#1209 Job#6055 Job# 1202 Job#A~/~211~8 Job#1152 Job# 1168-450 Job# 1172-450 Job# 1181 Job# 1185-450 Job#1190 Job# 1195-450 Job# 1205-450 Please sign and return the attached copy as receipt of data. RECEIVED BY__ Have A Nice Day! /~ Sonya Wallace 'APPROVED_J.~ ATO-1529 Trans# 9312~-' Sperry BHI 0il ~.e~s Co,,. # PHILLIPS # BOB OCANAS (OH/GCT) # EXXON # BPX # STATE OF ALASKA The correct API# for 3-18A is 50-029-20421-01. The correct API# for 9-28A is 50-029-21292-01. The correct API# for AGI-1 is 50-029-22307-00. INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL --. -- 93-009 AC/CBT 93-009 ACBT 93-009 BHCA/GR 93-009 BHCA/GR 93-009 BHCA/GR 93-009 BHPF 93-009 COMP 93-009 DLL/GR/SP 93-009 DLL/MLL/SP/GR 93-009 DPR/GR 93-009 DPR/GR 93-009 GR/CCL 93-009 SBL/GR/CCL 93-009 407 93-009 DAILY WELL OP 93-009 SURVEY 93-009 SURVEY 93-009 5756 Are well tests required? Was well cored? Yes No... Yes No OH,R1,5" RUN1, 5" OH,R1,2&5" RUN 1, 2&5" RUN 1, 5" OH,R1,5" RUN 1, 5" RUN 1, 2&5" OH,R1,2&5" RUNS 6&7,2&5"MD RUNS 6&7,2&5"TVD RUN 1, 5" CH,R1,5" COMP DATE:06/14/93 02/03/93-04/27/93 MWD DIRECTIONAL SS DIRECTIONAL OH,DLL/MLL/AC/GR If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No 09/10/1993 PAGE: 1 WELL IS ON COMPLIANCE. INITIAL COMMENTS: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 7, 1993 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 93-0002 PRUDHOE BAY UNIT AGI-5 COMPLETION REPORT. 93-0009 PRUDHOE BAY UNIT AGI-6 COMPLETION REPORT 93-0082 PRUDHOE BAY UNIT DS5-14A COMPLETION REPORT 93-0047 PRUDHOE BAY UNIT DS3-20A COMPLETION REPORT 93-0057 PRUDHOE BAY UNIT DS6-22A COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. MAY AND JUNES MONTHLY PRODUCTION 3'~REPORTS INDICATE THAT THESE WELLS ARE GAS INJECTORS AND OIL PRODUCERS FOR YEAR 1993. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE MENTIONED WELLS. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN 5 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS DLL/BCS/~ Run 1 J~196 8ch DLL/MLL/AC/CN/GR l~_m I Job~5949 Atlas CDN/CDR Run 1 Job#93127 8ch DLLIMLLIACIGR O~ ........~ ....... I~n 1,. .Job~~.O ~ ," ~tla~ DLL/MLL/AC/GR Run1 Job45915.01 Atlas Please sign and return ~he attached copy as receipt of data. RECEIVED " - T--U~---- ~-----' AUG 5 1 1993 Have A Nice Day! ~, Ala//ska Oil & Gas Cons. Commission Sonya Wallace APPR OVED~ Anchorage ATO- 1529 Trans# 93087 CENTRAL FILES (CH) CHEVRON D&M # BOB OCANAS (OH/GCT) # EXXON MARA~ON MOBIL # ptTTT.T.TPS PB WEI2. FILES R&D # BPX # STATE OF ALAS~ TEXACO * This is a revised tape, please replace one previously issued. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Job#AKEI30010 Sperry Job# 1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Ana Ana Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Teleco Job#AILM M911128 Sperry Job#AILMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job# 1168 Teleco Job# 1172 Tele co Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job# 1195-450 Teleco Job#1205 BHI Please sign and return the attached copy as receipt of data. RECEIVED BY_~~~/~ rmve ~ i~lce Day. ~n~ W~ll~ce ~PPROV~D__~~~o, C~~ON ~ PB ~LL F~ES ~ CLOT C~~ ~ BPX ~ E~ON ~ ST. OF ~. (2 COP~) MOB~ i LUC~LE JO~STON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'? ~-18-93 3-25A f~'23 6-17-93 3-31 ~ V-fz 6-16-93 3-32 ~ ~/-~7 6-15-93 3-33 ~ ¥- ~,o 6-16-93 4-8 ?~-,~ 6-11-93 5-14 ??-~3 6-12-93 6-22A ~ I.~6-6-93 6-22A ~ -6-10-93 7-25 ~-Y ~. 6-6-93 9-44 ~ ~ ~ ~ z~6-6-93 11-18 f&-In6-7-93 14-6 I' ~- ~o f6-8-93 14-8 7~'-/,7 6-10-93 14-13 ~-"id 16-13-93 14-15 f}~ 6-8-93 16-4A tz-1¢~6-9-93 16-17 ~" zz~6-14-93 16-31 9~-~{ 6-7-93 17-4 ~ 0 -~ 6-14-93 AGI-5 5~-~-6-13-93 AGI-6 ~$'~9 6-14-93 AGI-7 _6-8-93 AGI-7 ~ ~a-t6-15-93 AGI-7 6-17-93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Le-k Detect Leak Detect Perf Record Perf Record Production Log PITS/Leak Detect Leak Detect Inj Profile Completion Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record Run 1, 5" Sch Rn_n 1, 5" Sch Rnn 1, 5" Sch R.n 1, 5" Sch Run 1, 5" Sch Run 1, 5" $ch Run 1, 5" Sch Run I 2" Sch Run 1, 5" Sch R~m 1, 5" Sch Run 1, 5" Sch R._n 1, 5" Sch Run 1, 5" Sch Run 1, 2"&5" Sch Rl~n 1, 5" Sch Run 1, 5" Sch R.n 1, 1"&5" Sch R-n 1, 2"&5" Sch R-n 1, 5" Sch Run 1, 5" Sch Rn_n 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Rn_n 1, 5" Sch AGI-8 ~ ~3 3/6-9-93 GR/CCL Rn_n 1, 5" Sch AGI-97 6-9-93 GR/CCL R~m 1.5" Sch AGI-9/~ }'~ 6-17-93 Pe~ Record R-n 1, 5" Sch · . ~d ret~~~che~~ ~ease RECEIVED B~/~~~~/~- ~~ Sonya W~ace APPROVED_~ ATO-1529 ~~ 93073 ~ON ~ MOB~ #BPX # STATE OF ALASKA * The correct API# for 3-32 is 50-029-21141-00, ** The correct well -sine for tbh log is ~22~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO OPEN HOLE FINALS 3-18A/ 4/10-17/93 5-~..~ 6-13-93 5-3A ~C~ 6-13-93 5-3A ~ 6-13-/)3 .~A) 6-13-93 ~6-13-93 A I-5; AGI-5~ ~93 MWD: DPR/GR Runs 1-3, 2'&5'~D MWD: DPR/GR R,m~_ 1-3, 2"&5'TVD LWD: CDN Run 1, LWD: CDR Run 1, LWD: CDN N/F Rim 1, LWD: CDN N/F OverlayRtln 1, 2"&5' LWD: CDN Run 1, 2'&5'TVD LWIk. CDR Run 1, 2'&5'TVD ~DLL/GR/SP Rim 1, 2'&i~' BHCA/GR Run 1. 2"&5" BH Profile Run 1, 5" AGI-6"i ~ 4-25-93 DLL/GR/SP AGI-6/ a/°~ 4-25-93 BHCA/GR . AGI-6 ~ q'] 4-25-93 BH Prome AGI-6 ] ~ 2/11-13/93 DPR/GR AGI-6r a;t 2/11-13/93 DPR/GR AaI.7~¢l~,-v ~-/15-4/28/9S ]~/al~ AaI-7' . )~) ~-/1.",-4/~.S/93 I)pa/al~ 'j 3/5.6/93 -DI'R/C,R a~-8' ~, a,{ 3/5-6/93- ~)PI~/Ca~ AGI-9'~/~'~/~ 3/9-5/7/93DPR/GR AGI-9' 3/9-5/7/93 DPR/GR Rim 1, 2"&5" Run 1, 2'&5" Run 1, 5" Rtms 6&7, 2"&5'MD Runs 6&7. 2'&5"TVD Runs 6&7, 2'&5"MD Runs 6&7, 2"&5"TVD Run 4, ~'&5'~KD Run 4, 2'&5'TVD Runs 4&5, :~'&5'~D Runs 4&5, 2'&5'TVD AGI-10 ~ ~.~ 3/24-28/93 DFR/GR Rtms 3&4, ~'&5'~D .a~aI-lO t' ~%, , 3/24-28/93 ~Pi~./c.~ sign and re~ched~ as receipt of data~ Please ATO-1529 JUL t 0 199t # CENTRAL FILES # # CHEVRON Alaska 0il & ~as C~P~~~ FILES # D & M Anct~°r~eCLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # TEXACO # MOBIL BHI BHI Sch Sch Sch Sch Sch Sch Atlas Atlas Atlas Atlas Atlas Atlas Teleco Te!eco BHI Bill BHI BHI BHI Bill BHI BHI * The correct _n_~e for this well is 5-3A, and the logs are finals. ~*w These logs are revised final prints, please replace previous logs. ARCO ~]_~-~., Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: 14-22A ~8-16A ~/18-29A -.18-29A 6-9-93 5-6-93 Static Pressure Run 5-8-93 Prod Profile Run 5-10-93 Production Run 5-11-93 CBT/New TBG/Jewelry Run 5-10-93 Leak Detect/Spin/Temp/Press Run 5-4-93 USIT (Cement & Corrosion) (Color) Run 5-3-93 InJ Profile/Spin/Temp/Press Run 5-2-93 InJ Profile/PITS Run 4-24-93 Leak Detect/Spin/Temp/Press Run 5-7-93 Dual Burst/TDT-P (Borax) Run 5-6-93 Vertilog Run 5-8-93 GR/Collar Run 5-6-93 Perf Record Run 5-7-93 GR/C~ Run 5-10-93 CNL Run 5-11-93 Leak Detect Run 5-7-93 Pelf Record Run 5-9-93 TDT-P (Borax) Run 5-3-93 Leak Detect/Spin/Temp/Press Run 5-3-93 Perf Record Run 5-4-93 Production 1~_~ 5-5-93 CCL/Perf Reco~ Run 5-8-93 SBT/GR/CCL cl:~.~~I-4 5-7-93 GR/CCL (Color) '~~AGIo5 5-10-93 GR/CCL (Color) ~/~i~/AGI-6 5-10-93 GR/CCL, (Color) ~Am.S 5-3-9S S~r/GR/CC~ Please sign and return the attached copy as receipt of data. RECEIVED BY__~~.~~ # STATE OF ALASKA Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch 8ch ~ch Atlas ARCO J~IA~IrA, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO ~ FINALS 4-25-93 SSTVD Run 1, 1"&2' 4-25-93 DLL/MIA,/GR/SP/Cal · Run 1, 4-25-93 BHC&/GR Run 1, 4-25-93 CNL/GR/CCL Run 1, 4-25-93 Z-DEN/CNL/GR/Cal Run 1, 4-25-93 BH Profile Run 1, 4-25-93 Dielectric/GR Run 1, 4-25-93 Spectralog Run 1, 4-22-93 DLL/MSFL Color Run 1, 4-22-93 BHCS/GR Color Run 1, 4-22-93 CNL/GR Color Run 1, ~'&~' 4-25-93 DLL/I~.T~/SP/GR Run 1, 4-25-93 BHCA/GR Run 1, 4-25-93 BH Profile Run 1, 4-25-93 Acoustic CBT Run 1, · ~ ...... . Please sign and return the attached copy as receipt of data. RECEIVED B¥-~~~.~_~ Have A Nice Day! Sonya Wallace . ATO-1529 RECEIVED MAY 1 0 199 Naska 011 & Gas Cons. Commission Anchorage # CENTRAL FILES # CHEVRON #D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL APPROVED_ff Trans# 93057 # PHILLIPS # PB WELL FILES R&D # BPX # STATE OF ALASKA Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas 8ch 8ch Sch Atlas Atlas Atlas Atlas ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-30-93 REFERENCE: ARCO ~/Z~'-l-9 4-16-93 Inflatable IBP Setting Run 1,1~' Seh 1-20 ~" } ~ ~ 4-11-93 Dual Burst TDTP (Borax) l~m 1, ~' Sch --- 1-16 4-13-93 Production l~_m 1, I~' Sch ~3~-- aT~ 4-9-93 Static Press/Temp Run 1, ~' Sch 4-10-93 Perf Recmd l~_m 1,1~' Sch --- 3-10 4-1-93 Tubing Cutter Run 1, ~' Atlas 3-31 l~q-~Z~ 4-11-93 Production Run 1, 2~'&5" Sch --4-19 4-8-93 Static Pressure/Temp Run 1. ~' Sch 9-SAg~-~-/d 4-1-93 PedRecord Run 1, 1~' Sch /9-28A 4-3-93 SBL/C~/CCL Run 1, [~' Atlas "-9-~A _ 4-4-93 PFC/CCL (packer Setting) Run 1, ~' Atlas 14-23 ~-$~ 4-7-93 Dual Burst TDTP/Temp (Borax) Run 1, ~' Sch ~3 -14-34 4-12-93 Production Run 1, [~' Sch 14-41c/;~--~ ¥ 4-10-93 Dual Burst TDTP (Borax) Run 1, ~' Sch -- 14-43 4-9-93 Dual Burst TDTP (Borax) ~an 1, 5" Seh 16-31/~'~ 4-8-93 Production Run 1, ~' Seh AGI,6 3-24-93 .emi./GR/CCL Run 1, 5~' Atlas A~I-? 3-24-93 Sm./~~ ~hm ~, S' Atlas Please sign and return tl~ attached copy a~ receipt of data. RECEIVED BY ~~~I~~ Have A Nice Day! RECEIVED Sonya Wallace ATO-1529 # CENTRAL FILES # CIt~VRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL · APPROVED '/" [/~y 0 6 19~ Trans# 9305~-~z~-~-- # PHILLIPS PB ~~ ~ R&D ~ BPX ~ STATE OF ~~ ~CO ' I; STATE OF ALASKA ~'-~SKA OIL AND GAS CONSERVATION COMMioolON /~"'/~.~,~ REPORT OF SUNDRY WELL OPERATIONS Plugging Perforate Pull tubing Alter casing Repair well Other. 1. Operations performed: Operation shutdown X Stimulate 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2173' NSL, 2495' WEL, SEC. 36, T12N, R14E, UM At top of productive interval N/A At effective depth N/A At total depth 3298' NSL, 1477' WEL, SEC. 31, T12N, R15E, UM 5. Type of Well: Development __ Exploratory Strafigraphic Service X 6. Datum elevation (DF or KB) KBE = 49.2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number AGI-6 9. Permit number/approval number 93-09 10. APl number 50- 029-22327 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10590 feet 8044' feet feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 76' 20" Surface 4064' 13-3/8" Intermediate Production 10546' 9-5/8" Liner Perforation depth: measured None Cemented Measured depth True vertical depth 27 cuft Arctic'set 106' 106' 2580 ct/ft "E"/460 cuft "G" 4104' 3514' 575 CU fl Class "G" 10583' 8039' true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and S,,urve/~/s run Daily R~port of/~l ¢h3e/'ations x Oil Gas Suspended 17. I hereb~ ~,~htl'~¥;; Cregoing is/rue ancl~c~rrect to,the best of my knowledge. SignedJ" "~'~,/~~ ~/~.. ~,~ Title Drilling Engineer Supervisor Form 10-404 Rev d6/1~/8§ / ~ Service Dat~'~.~?J SUBMIT IN bUPLICATE BP/AAIJ~'HARED SERVICE~ WELL: AGI-6 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATION ~ PAGE: 1 ACCEPT: 02/02/93 11:00 SPUD: 02/03/93 01:00 RELEASE: 02/14/93 07:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 02/03/93 (1) TD: 307'( 0) 02/04/93 (2) TD: 2020' (1713) DRLG. MW: 8.6 VIS: 42 SKID RIG. RIG ACCEPTED @ 11:00 HRS, 2/2/93. N/U DIVERTER. TEST SAME. M/U BHA. SPUD WELL @ 01:00 HRS, 2/3/93. DRLG F/ 110'-307'. DRLG. DRLG F/ 307'-2020' MW: 9.4 VIS:143 02/05/93 (3) TD: 3734' (1714) 02/06/93 ( 4) TD: 4115' ( 381) 02/07/93 (5) TD: 4115' ( 0) 02/08/93 (6) TD: 4775' ( 660) 02/09/93 (7) TD: 7096' (2321) 02/10/93 (8) TD: 7956' ( 860) 02/11/93 ( 9) TD: 8843' ( 887) POOH. MW: 9.4 VIS:il0 DRLG TO 2145' CBU. WIPER TRIP. DRLG TO 3640' CIRC. DROP SINGLE SHOT SURVEY. DRLG TO 3734'. DROP SINGLE SHOT SURVEY. CIRC. POOH FOR MWD FAILURE. CIRC. MW: 9.4 VIS:ll5 POOH. CHANGE MWD. RIH. DRLG TO 4115'. CBU. SHORT TRIP 10 STDS. CIRC. POOH. RIH W/ 13-3/8" CSG. CIRC. RIH. MW: 9.5 VIS: 55 LAND CSG. CIRC. R/U HOWCO. PUMP 90 BBLS WATER, 1200 SX LITE CMT, 400 SX PREM CMT. BUMP PLUG W/ 2000 PSI. N/D RISWER, DIVERTER. 250 SX TOP JOB. N/U BOPE. TEST BOPE. RIH W/ BHA. DRLG. MW: 8.8 VIS: 35 RIH TO FC. CIRC. TEST CSG. DRLG FLOAT EQUIP, CMT, 10' NEW HOLE. CBU. LOT (12.9 PPG EMW). DRLG 2 STDS. CBU. POOH. CHANGE MWD. RIH. DRLG TO 4667' CIRC. POOH. CHANGE MWD. RIH. WASH 100' TO BTM. DRLG TO 4775' SHORT TRIP. MW: 9.4 VIS: 40 DRLG TO 5709'. CBU. SHORT TRIP TO SHOE. DRLG TO 6924' CIRC. DRLG TO 7096'. CIRC. POOH TO SHOE & WORK ON TOP DRIVE. DRLG. MW: 9.4 VIS: 40 RIH. DRLG TO 7635'. CBU. DROP SURVEY. POOH. CHANGE BIT. RIH. WASH 230' TO BTM. DRLG TO 7956' DRLG. MW: 9.7 VIS: 42 DRLG TO 8490'. POOH WET TO FIND WASHOUT. FOUND. RIH. DRLG TO 8843'. WELL- ~ : AGI-6 OPE~ATION: RIG : AUDI 2 PAGE: 2 02/12/93 (10) TD: 9550' ( 707) POOH. MW: 9.8 VIS: 43 DRLG TO 9550' CBU. SURVEY. POOH. CHANGE MTR, BIT. 02/13/93 (11) TD:10590' (1040) 02/14/93 (12) TD:10590' ( 0) 02/15/93 (13) TD:10590' ( 0) SHORT TRIP. MW: 9.9 VIS: 42 RIH. REAM 75' TO BTM. DRLG TO 10590'. TD 12-1/4" HOLE. CBU. 15 STDS SHORT TRIP. CMT 9-5/8" CSG. MW: 9.9 VIS: 44 CIRC SWEEP. POOH. R/U WOTCO. RIH W/ 9-5/8" CSG. WASH TO TD. CIRC. RIG RELEASED. MW: 9.9 VIS: 0 R/U HOWCO. PUMP 105 BBLS SLURRY. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. R/D CSG EQUIP. SET PACKOFF. TEST SAME. OK. RIH TO 2000'. DISP W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. OK. RIG RELEASED @ 19:00 HRS, 2/14/93. SIGNATURE: (drilling superintendent) DATE: R£CEIVED Alaska Oil & Sas Cons. Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279.1433 TELECOPY: (907) 276-7542 January 25, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 ARCO Alaska 99519-6612 Re: Prudhoe Bay Unit AGI-6 ARCO Alaska, Inc. Permit No. 93-09 Sur. Loc 2173'NSL, 2495'WEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 1868'SNL, 582'WEL, Sec. 31, T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. i .. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~?~ prir, ted on recycled paper b y f3',FI_. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CCtv, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill 171 'Redrilll-Illb. Type of well. Exploratoryl-1 Stratigraphic Test r-1 Developrhent Oi, l-I Re-Entry [] DeepenI-]I Service [] Development Gas [] Single Zone [] M.ultiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE ,- 491eet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 34628 4. Location of well at surf-ace 7. Unit or property Name 11. TYp® Bond(see 20 ^^c 25.o~s) 2173' NSL, 2495' WEL, SEC. 36, T12N, R14E Prudhoe Bay Un~ At top of productive interval 8. Well number Number 1910' SNL, 820' WEL, SEC. 31, T12N, R15E AGI-6 U-630610 At total depth 9. Approximate spud date Amount 1868' SNL, 582' WEL, SEC. 31, T12N, R15E 11'~/93 $200,000.00 12. Distance to nearest 13. Distance to '~earest well 14. Number of acres in Property15. Proposed depth (MD and mVD) property line ,- . ADL 28301-4696 tee[ AGI-5-120'@ Surface feet 2560 11280' MD/8486' TVDleet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 Mc 25.035 (e)(2)) Kickoff depth 6~3feet Maximum hole angle 46 o Maximum surface 3330pslg At total depth (TVD) ~{)O'/4~90pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole" Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ,,, 30" 20" 91.51t H-40 Weld 76' 30' 30' 106' 106' 11 yds Arcticset 16" 13-3/8" 68tt L-80 B TC 4074' 29' 29' 4103 3500 1163 sx PF "E"/400 sx "G"/250 sx PF"C" , 12-1/4" 9-5/8" 4711 L-80 NSCC 10648' 28' 28' 10676' 8066' 500 sx Class "G" 8-1/2" 7" 2611 L-80 NSCC 800' 10480' 7980' 11280' 8486' Uncemented 19. To be completed fOr Redrill, Re-entry, and Deepen OperatiOns. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production,JAN 1 1993 Liner Perforation depth: measured Alaska 0il & Gas Cons. true vertical Anchorage. 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Div~rter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction ~analysis [] Seabed reportE] 20 AAC 25.050 requirementsl-1 21. I hereby certify t,hat the fol~going is true and correct to~ t, be be.st of my knowledge Signed ~,,-~ Commissionit~leDrillingEngineerSuperviS°ruse Only Date ~ '" f~ '" c~'~ Permit Number IAPI number JApproval date ' ISee cover letter ?...:~ - O ,?' 15 0- O .z ? - ~ .7__ ~ .~ ~' I / -c~-.~---" ~ ~'. If°r other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Ye~' ~ No Hydrogen sulfide measures [] Yes J~ No Direction~,~ survey required ,~ Yes [] No Required working pressure for BOPE []2M; r"13M; J~5M; I'-I10M; I-I15M; ' ~'~ned By by order of Other: ~IT.~ Origirla~ Approved by David W, Johnston Commissioner tne commission_.Date/-'~"~---~. . ,,.. ,. Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: APEX GAS INJECTOR #6 (AGI #6) LOCATION: Surface: Target: T.D.: 2173' FSL, 2495' FEL, Sec. 36, T12N, R14E 1910' FNL, 820' FEL, Sec. 31, T12N, R15E 1868' FNL, 582 FEL, Sec. 31, T12N, R15E ESTIMATED START: 1 6JAN93 OPR. DAYS TO COMPLETE: 20 (1 6 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 46.0°/N79.65°W/613'/2° per 100' MD/6894' Estimated Ground level elevation is 13' AI~SL. KB to ground level elevation is 36'. Item TVD(BKB) MD(_BKB) Mud Wt. 20" CONDUCTOR 1 06 106 8.5 13-3/8" SHOE 3500 4103 9.0 9-5/8" SHOE 8066 10676 9.2-10.0 TOP SADLEROCHIT 8071 10683 9.2-10.0 7" SHOE 8486 11280 9.2-10.0 TARGET 8254 10946 9.2-10.0 TOTAL DEPTH 8486 11280 9.2-10.0 CASING PROGRAM: Hole C.~g Wl; Grade Conn Length Top Btm 30" 20" 91.5# H-40 WELD 76 30 106 1 6" 13-3/8" 68# L-80 BTC 4074 29 41 03 12-1/4" 9-5/8" 47# L-80 NSCC 10648 28 10676 8-1/2" 7" 26# L-80 NSCC 800 10480 11280 COMPLETION: Tubing: 7" GLMs: None Packer: LOGGING PROGRAM: Open Hole Cased Hole 26# L-80 NSCC 10403 27 10430 9-5/8" x 5-1/2" PERMANENT PACKER set at 1 0430 MD or +/- 50' above Top of liner 12-1/4" hole: 8-1/2" hole GR/RESISTIVITY WHILE DRILLING TO PICK CASING POINT. GR/RESISTIVITY WHILE DRILLING ACROSS SADLEROCHIT run to 13-3/8"~: SBT IN 9-5/8" before running tubing (GR to be ~E~ E iVE D Alaska Oil & Gas Cons. Commissi0~ Anchorage PEX GAS INJECTOR #6 (AGI #6) DRILLING DISCUSSION AGI #6 is the sixth of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the additional gas injection requirements associated with the GHX-2 project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the Ivishak sand injection interval (target interval) comprised of Zones 1, 2, 3, and partially truncated Zone 4. Ivishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2" tailpipe will be the completion assembly. This assembly will be run with a completion rig after the drilling has moved off the well. ANNULAR INJECTION The 13-3/8" x 9-5/8" annulus of AGI #2, AGI #3, AGI #4, and AGI #5 may be available for injection purposes. Ensure any annulus has been properly permitted before commencing injection. The 13-3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. ADEC has informed Prudhoe Bay Drilling that only associated fluids from drilling operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. SHUTDOWN OF WELL OPERATIONS Shutdown of well operations once 9-5/8" casing has been set and cemented is planned for wells AGI #3 thru AGI #9. Wells AGI #3- AGI #9 will be drilled to 12-1/4" hole TD, 9-5/8" casing run and cemented. At this time operations will be shutdown and the rig will move to the next well and repeat the process. AGI #10 will be drilled to 8-1/2" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/2" hole, running 7" liner and completing all the wells in which operations were shutdown. As per conversation with AOGCC (B. Wondzell) on 30DEC92 shutdown and resumption of well operations approval will be included as part of the permit approval-as long as the process is outlined in the PROPOSED DRILLING AND COMPLETION PROGRAM associated with this package-and therefore no application for sundry approval will be necessary for shutdown/resumption of operations. The decision to drill AGI #3- AGI #10 as described above is based solely on economics and therefore dictated by prudence alone. There are no known hydrocarbon bearing sands between surface and 9-5/8" casing point in any of the AGI wells. All 9-5/8" casing points are estimated to be above the top of the Sadlerochit sands. Operations on AGI #6 are expected to resume on or about 3APR93. All ten wells are estimated to be drilled and completed by 1 MAY93. If there are any questions or if further information is required please contact J. E. Robertson at 564- 5510. FREEZE PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES WELLNAME SLOT DISTANCE DEPTH (' TVD) AGI #1 AGI #1 598' 850 TVD AGI #2 AGI #2 480 SURFACE AGI #3 AGI #3 358' 500' TVD AGI #4 AGI #4 238' SURFACE AGI #5 AGI #5 120' SURFACE LGI #06 LGI #06 949' 8450' TVD LGI #08 LGI #08 509' 7350' TVD LGI #010 LGI #10 308' 5550' TVD RB EiVED Alaska Oil & 6a~ ,~,,~. Anchorage PROPOSED DRILLING AND COMPLETION PROGRAM AGI #6 Procedure · MIRU drilling rig. Notify AOGCC of upcoming diverter function test. N/U diverter and function test same. . . Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 2500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. . . Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. seawater. Bump cementing plug with . RIH to 2000' MD and displace to diesel. ND BOPE. NU dryhole tree and test to 5000 psi. SHUTDOWN OPERATIONS. Release rig. Move off. . RESUME OPERATIONS. MIRU. Notify AOGCC of upcoming BOPE TEST. ND dryhole tree and NU BOPE. Test BOPE. . 10. 11. RIH. Displace diesel cap w/seawater. Drill to 9-5/8" shoe. Displace wellbore w/"drill in" mud. Continue drill/LOG 8-1/2" hole through reservoir to TD. MU 7" liner on 5" DP. RIH to TD. Displace wellbore w/completion fluid. Set liner hanger and liner top packer. POOH. Run 7", L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. 12. NU tree and test to 5000 psi. Release drilling rig. o Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: 3850 psi @ 8800' TVD SS 2970 psi 8.6 PPG SEAWATER Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. No potential productive zones are anticipated above 9-5/8" casing shoe. d. No potential hazardous levels of HZS are anticipated in this well. RECEIVED JAN 1 t99 ~0jl & Gas Cons. MUD PROGRAM: Well AGI #6 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing Doint: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 <1 O0 YP lbs/100ft2 40- 60 20- 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 60 - 80 20 - 30 pH - 9.0 - 10 9.0 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS-INTERMEDIATE HOLE Surface casing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 min 6-8 pH - 8.5 - 10.0 Hardness mg/I <200 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point lbs/10Oft2 20- 30 10 sec Gel lbs/100ft2 18 - 22 10 min Gel lbs/100ft2 20 - 24 APl Fluid loss mi/30 min 6.0- 8.0 pH - 9.5 - 10.0 Hardness mg/I <200 The mud salinity should be compatible with the Reservoir logging program. The mud will be run at +40,000 ppm chlorides. RUN LOW SHEAR RATE VISCOSITY AT 40,000+ Centipoise on mud system. RECEIVED JAN 1 t99; Alaska Oil & Gas Cons. CommJss|on Anchorag~ AGI #6 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) 1069000 1556000 TJYS (#) 1300000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SI PRESSURE 14 3500 2198 Burst S.F. 1.57 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S,F, 1,31 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4103 PBYS Tension S.F. 4.48 Mud Wt. 9.5 ppg TJYS 5.45 String Wt. (#) 238493 JAN 3 ~Jaska 0ii .& Gas Cons. ~c~0.rag~ AGI #6 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 385O Burst S.F. 1.78 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/fi) Collapse press 10.2 8066 0.1 3472 Collapse S.F. 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (#Iff) MD (FT) 47 10676 PBYS Tension S.F. 2.56 Mud Wt. String Wt. (#) 10.2 423546 TJYS 2.74 Anchorage AGI #6 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3942 3850 Burst S.F. 1.84 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 10.2 8486 0.1 3652 Collapse S.F. 1.48 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 800 Mud Wt. String Wt. (#) 10.2 17557 Tension S.F. PBYS TJYS 34.40 37.99 RECEIVED ,.IAN 1 3 ~,993 AJaska Oil & Gas Cons, Anchorag~ CEM _,e T PROGRAM - HALLIBURTON SERVICES 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 1163 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx APPROX #SACKS: 250 PUMP TIME: 2:30 hfs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F ~.' 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. From top of tail to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. CASING SIZE: 9 5/8", 47# ~ 135°F 5/8" INTERMEDIATE CASING JAN 1 ~ ]~ ,':tlasL(a 0d & Gas Cons..Com~ssiot' Anchorage, TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps FW APPROX #SACKS: 500 PUMP TIME: 4 hfs Mix water temp: 70-80 F ~ Pump 20 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg, .OTHER CONSIDERATIONS: Continuously mix tail slurry, Displace at 12-1 5 bpm. CEMENT VOLUME 1, Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show, 2, Tail Slurry to 1000' MD above shoe w/30% excess, Prudhoe Bay AGI-06 HI'-IRIZlqNTAL SCALE 1 000 REFERENCE', VIEW ?4;, / WELL Drillina DIVISIF'IN13°'lGdeo'EastDeclln°tl°n I HEAD 500 500 1500 2500 3500 4500 5500 6500 I00 000 I IS dITHI lOC) 2000-- 2673 3000-- 350O 4000-- 0T 0.00'@ 0 ND R,K.~. ELEVAT[BN 49' 613 4.00' ~ 813 HD lO00 8,00' ~ 1013 ND 12.00' @ 1213 MD t 16.00' @ 1413 MD 20.00' @ 1613 MD 24.00' @ 1813 MD ~ 28.00' @ 2013 MD ~$, 3~.00' ~ 2213 MD %,, 36.00' ~ 2413 MD ~ 40,00' ~ 2613 HD 875 ~,,~46.00' ~ 2913 HD END DF BUfLD O0 ~ 4103 MD 13-3/8' CSG PT 1731 5000-- 6000-- 7000-- 0.00' @ 613 MD START OF BUILD BUILD RATE, 2.00 DEG/IO0 FT 8000-- eo~6 8071 8254 8436 .-. 8486 " 9000 0 6459 6464 6654 6848 6894 3000 4000 5000 I I I000 2000 VERTICAL VIEW SCALE 1000 ?-t:, / DIVISION REFERENCE: WELL HEAD HD ~.c AZl Tv~ No~*~ R.K.B. 49 0.oo 0.o0 START OF BUILD 6130.00 0.00 613 0 END OF BUILD 2913 46.0079.&$ 2673 1~7 8~1 13-3/6° C$O PT 4103 46.007~.65 3500 311 1702 9-5/8' CS6 PT 10676 46.0079.65 8066 1160 6354 10S 1068346. O0 79.658071 1161 6359 TARGET 1094646.0079.658~54 1195 6545 KAVIK 1120846. oo 79.658436 1229 6731 TOT^L DEPTH llaSO 46,0079.658486 1238 6788 8HL DATA TVD 8486,0~ MD l1280.1q North 1238.2~ ~Eos~ 67BI.G~ RECEIVED SURFACE LOCATION 2173' FSLj 2495' FEL SEC. 36s TI2NI RI4E ASP: ¥ = 5979811.65 X = 688781.84 TARGET LOCATION 1910' FNL~ 820" FEL SEC. 3lJ TI2NJ R15[ ASP: Y = 5981174.04 X · 695294.22 BOTTOMHOLE LOCATION ASP, Y= 5981823.34 x = 6~5529.34 JAN 1 ~ 1993 .0il .& Gas Cons. Commission ~ohorago '~'~ 46.00' @ 10676 MD 9-5/8' CSG PT P'X 46.00' ~ 10683 MD TBS ~.~ 46,00' @ 10946 MD TARGET 46.00' @ 11208 MD KAVIK 46.00' ~ I1280 ND IflTAL DEPTH I I 6000 7000 VERTICAL SECTIE]N PLANE: 79,65 ° mith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 0.00 deg. 'vey Reference: ~ELLHEAD ~erence 14or[d Coordinates: Lat. 70.20.58.48 N - Long. 148.28.02.06 14 ~erence GRID System: Alaska State PI@ne Zone: Ataska 4 erence GRID Coordinates: (feet): 5979811.65 N 688781.84 E 'tica[ Section Reference: WELLHEAD ~sure Reference: tJELLHEAD 'th Aligned To: TRUE NORTH ~hoe Bay Drifting -06 Page 1 Date: 1/5/93 14el[path ID: AGI-OG~P Last Revision: 1/5/93 ,asured Incl Drift TVD Subsea T 0 T A L Geographic Coordinates Depth Dir. Depth Rectangutar Offsets Latitude / Longitude (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Ctosure Dist. Dir. (ft) deg. Vertica[ DLS Section (ft) (dg/lOOft) IN 0,00 0.00 0.00 0,00 -49,00 0,00 N 0,00 E 70.20,58,4821 N 148,28.02,0601 14 RT OF BUILD 612.74 0.00 0.00 612,74 563,74 0,00 N 0.00 E 70.20.58.4821 N 148.28.02.0601 14 712,74 2,00 79.65 712.72 663,72 0.31 N 1,72 E 70,20,58.4852 N 148.28.02.0099 U 5979811,65 688781,84 5979811,65 688781,84 5979812,01 688783,55 0.00 @ 0.00 0.00 @ 0.00 1,75 @ 79.65 0.00 0.00 0.00 0.00 0.31 2.00 812,74 4,00 79,65 812.57 763,57 1,25 N 6,86 E 70,20,58,4944 N 148.28.01,8595 14 912.74 6.00 79,65 912,19- 863.19 2,82 N 15,44 E 70,20.58.5098 N 148,28.01.6089 14 1012,74 8.00 79,65 1011,44 962,44 5,01 N 27,43 E 70,20.58.5314 N 148,28,01.2586 14 1112,74 10,00 79.65 1110,20 1061,20 7.82 N 42.81 E 70.20.58.5590 N 148.28.00,8089 14 1212,74 12.00 79,65 1208.36 1159,36 11,24 N 61,58 E · 70.20,58,5927 N 148.28.00.2603 W 1312.74 14.00 79.65 1305,79 1256,79 15,28 N 83,71 E- 70,20,58.6324 N 148.27.59.6136 14 1412.74 16.00 79.65 1402,38 1353,38 19,93 N 109,17'E 70.20,58.6781 N 148.27,58.8696 ~ 1512.74 18.00 79.65 1498,01 1449,01 25,18 N 137,93 E 70,20,58.7298 N 148,27,58.0291 14 1612.74 20,00 79.65 1592,55 1543,55 31,03 N 169.96 E 70,20,58.7873 N 148.27.57.0931 14 1712.74 22.00 79.65 1685.91 1636.91 37.47 N 205.21 E 70,20,58.8506 N 148,27.56.0629 14 1812.74 24,00 79.65 1777,95 1728.95 44,49 N 243.65 E 70,20,58.9196 N 148.27,54.9396 14 1912.74 26,00 79,65 1868.58 1819.58 52.08 N 285,22 E 70,20,58,9943 N 148.27.53.7247 14 5979813,08 688788.67 5979814,86 688797,20 5979817,35 688809,13 6,98 @ 79,65 1.25 2.00 15,69 @ 79.65 2.82 2.00 27,88 @ 79,65 5,01 2.00 5979820,54 688824,44 43,52 @ 79,65 7.82 2.00 5979824,44 68884.3,12 62,60 @ 79,65 11.24 2.00 5979829,04 688865,14 85,10 @ 79.65 15.28 2.00 5979834,33 688890.47 5979840,30 688919,09 5979846,95 688950,96 5979854,28 688986,04 5979862,26 689024,28 5979870,90 689065,65 110.98 a 79.65 19.93 2.00 140,21 @ 79,65 25.18 2.00 172,77 @ 79.65 31,03 2.00 208,60 @ 79,65 37.47 2.00 247,67 @ 79,65 44.49 2.00 289,93 @ 79,65 52,08 2,00 2012.74 28,00 79,65 1957,67 1908,67 60.23 N 329.88 E . 70.20,59.0745 N 148.27.52,4196 14 2112.74 30.00 79,65 2045.13 1996,13 68.94 N 377.57 E 70,20.59.1601 N 148.27.51,0258 14 2212,74 32,00 79,65 2130,84 2081,84 78,19 N 428,23 E 70.20.59,2511 N 148,27.49,5452 14 5979880,18 689110,09 5979890,09 689157,54 5979900,61 689207.95 335,33 @ 79.65 60,23 2.00 383,81 @ 79,65 68,94 2.00 435,31 @ 79,65 78.19 2,00 2312,74 34.00 79,65 2214,71 2165,71 87,97 N 481,81 E' 70.20,59.3473 N 148.27.47.9795 14 2412.74 36.00 79,65 2296.62 2247,62 98.27 N 538.23 E 70,20.59,4486 N 148.27,46.3305 g 7512.74 38,00 79,65 2376.48 2327,48 109.08 N 597.43 E 70,20.59,5549 N 148,27,44.6004 14 5979911,74 689261.26 5979923,47 689317,40 5979935,77 689376,31 489,779 79.65 87.97 2,00 547,13 @ 79,65 98.27 2.00 607,30 @ 79,65 109,08 2.00 7612.74 40,00 79.65 2454,19 2405,19 120,38 N 659,33 E 70,20.59.6661 N 148,27.42.7912 14 7712,74 42,00 79,65 2529,65 2480.65 132.17 N 723,87 E 70,20,59.7820 N 148.27.40,9052 14 7812,74 44,00 79,65 2602,79 2553,79 144,42 N 790.96 E 70,20.59.9025 N 148,27.38.9446 14 5979948,63 689437,91 670,23 @ 79,65 5979962,04 689502,12 735,84 @ 79,65 5979975,98 689568.88 804,03 @ 79,65 120,38 2.00 132,17 2.00 144,42 2,00 OF BUILD 7912.74 46,00 79,65 2673,49 2624.49 157,12 N 860,51E 5/8" CSG PT ~102,54 46,00 79,65 3500,00 3451.00 310,84 N 1702.47 E ~8" CSG PT )675.55 46.00 79.65 8066.00 8017.00 1160.11N 6353.80 E 70,21,00.0274 N 148,27.36.9117 14 70,21,01.5393 N 148.27.12,3053 W 70.21.09.8919 N 148.24.56.3S88 U 5979990,44 689638,09 874,74 @ 79,65 5980165.47 690475.85 1730.61 @ 79.65 ~0~11~4.09 695105.68 ~&~R.~4 ~ 70.~ 157,12 2.00 310.84 ~0,00 11AQ.11 n nn ;mith International, Inc. Proposal Report Page Z Date: 1/5/93 ~ettpath ID: AG[-O6gP easured [nc[ Drift TVD Depth Dir. (ft) (deg.) (deg,) (ft). S 10682.75 46.00 79.65 8071.00 RGET 10946.19 46.00 79.65 8254.00 11046.19 46.00 79.65 8323.4? 11146.19 46.00 79.65 8392.93 11208.19 46.00 79.65 8436.00 11246.19 46.00 79.65 8462.40 rAL DEPTH 11280.17 46.00 79.65 8486.00 Subsea T 0 T A L Depth Rectangular Offsets (ft) (ft) (ft) 8022.00 1161.04 N 6358;90 E 8205.00 1195.08 N 6545.32 E 8274.47 1208.00 N 6616.08 E 8343.93 1220.92 N 6686.84 E 8387.00 1228.93 N 6730.72 E 8413.40 1233.84 N 6757.61E 8437,00 1238.23 N 6781.65 E Geographic Coordinates Latitude / Longitude 70,21,09.9011 N 148.24.56.2099 70.21,10.2358 N 148.24.50.7610 70.21.10.3629 N 148.24.48.6926 70.21.10.4900 N 148.24.46.6243 70.21.10.5688 N 148.24.45.3419 70.21.10.6171 N 148.24.44.5559 70.21.10.6602 N 148.24.43.8531 GRID Coordinates Ctosure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5981135.16 695108.75 6464.02 g 79.65 5981174.04 695294.22 6653.52 @ 79.65 5981188,80 695364.62 6725.46 @ 79.65 5981203.56 695435.02 6797.39 @ 79.65 5981212,71 695478.67 6841.99 @ 79.65 5981218.32 695505.42 6869.32 @ 79.65 5981223,34 695529.34 6893.77 @ 79.65 Verticat DLS Section (ft) (dg/lOOft) 1161.04 0.00 1195.08 0.00 1208.00 0.00 1220.92 0.00 1228.93 0.00 1233.84 0.00 1238.23 0.00 P~udhoe AGT-06 Bay DP/ling DO, 16 deg. Eos9 , Ii .1 RECEIVED HI3RIZFINTAL SCALE 500 REFERENCE' VIFW 6±, / DIVISION WELL HEAD Alaska 0il & Gas Co~m, Commissio~ ^~mhorage /D 333 L"D,~A'~] SIDq ~ELLS Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page Date: 1/5/~ Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling AGI-06 TVD, N/S and E/W are measured from the WELLHEAD Wellpath Slot Distance Direction LGI-02 LGI-02 3273.63 200.43 LGI-04 LG~-04 3583.00 166.19 LGI-06 LG[-06 949.03 108.80 LG[-08 LG[-08 509.58 268.87 LG[-IO LG[-IO 308.76 99.62 LG[-12 LG[-12 2106.57 219.79 Closest Points Ref MD Ref TVD 6117.92 4900.00 100,00 100.00 11228.34 8450.00 9644.83 7350.00 7053.63 5550.00 6981.65. 5500.00 RECEIVED Alaska,Oi! .& Gas Col]s, Commis$[Ol~ ~ncho,.rag~ P udhoe T~ovet/in9 Cfinde~ - Leas± ReCe~ence ~el/- AGI-O6WP TV]3: 0- 8486 £~c, Al/. ]3~ec~ions Ret ~o T~ue 500 330° Dis~cence 50 £~, No~ ~ch JO': 450 400 900 270° 240° 120° % 2~0o 150° Wetlpoth Slot LG]-O~ LG]-O~ LG]-04 LG]-04 LG]-06 LG]-06 LG]-08 LG]-O8 LG]- 10 L Gl- 10 LG]-12 LGI-12 CLOSES7 POINTS Dstonce N/A N/A ~0876 N/A Dir'~ction N/A N/A 268.87 99.(:,8 N/A R'e¢ MD N/A N/A N/A g~44.83 7053.63 N/A Re£ TVD N/A N/A N/A 7350.00 5550.0O N/A RE(EIVED JAN 1,3 t993 ..... '-,. ga_c. Jto_rag.~ Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page Date: 1/5/~ Least Distance Method REFERENCE WELL: Prudhoe Bay Drifting AGI-06 TVD, N/S and E/W are measured from the WELLHEAD Closest Points Wettpath Stot Distance Direction Eel MD Eel TVD NPBst-01 NPBst-01 12147.33 324.59 0.00 0.00 npbst02 NPBst-02 8260.70 316.62 600.00 600.00 NP-O3WP NPBst-03 3330.55- 342.51 0.00 0.00 wbeach01 WBCH01 2602~13' '' 308.63 9500.88 7250.00 wbeachla WBCH01 2671.58 319.26 8205.28 6350.00 wbeach02 WBCH02 3338.57 342.02 0.00 0.00 wbch03 ~BCH03 3270.53 345.85 850.27 850.00 wbchO3a ~BCH03 3270.53 345.85 850.27 850.00 wbchO3b ~BCH03 3269.29 345.84 850.27 850.00 WB-O4MUD WBCH04 3321.21 343.01 300.00 300.00 Px~udhoe ]Bay ]3mill n9 T~ave~in9 Cx~inde~ - LeasCo ]}istance Re£epence ~e~/- AGI-O6WP TV]}: 0- 8486 A~/ ]3ip ec±i on s I~et ~co T~ ue Nop ~ctn IS : THF -- E70~ 240° 33O° 21Do J600 550 500 450 400 350 300 ]5O° l~r--~OO CLOSES'[ PAINTS D s~once N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A ~ectlon N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Re£ ND N/A N/A N/A N/A N/A N/A N/A Re~' TVD N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A RECeIVeD 0il .& G~s Cons. Commissio~ Smith International, Inc. Travelling Cylinder Report Computed by the Sfi Win-CADDS System Least Distance Method Page Date: 1/5/9 REFERENCE WELL: Prudhoe Bay Orit[ing AGI-06 TVD, N/S and E/W are measured from the WELLHEAD We[tpath Stot Distance [101 L1-01 5281.61 t102 L1-02 5257.84 t109 L1-09 5041.g8 [110 L1-10 5018.61 1114 L1-14 4659.50 1115 L1-15 4862.50 1121 L1-21 4683.18 1127 L1-27 4410.45 [128 L1-28 3621.97 [130 L1-30 3000.33 Closest Points Direction Ref MD Ref TVD 183.61 50.00 50.00 181.69 100.00 100.00 . 183.55 300.00 300.00 181.54 200.00 200.00 178.86 4966.27 4100.00 183.48 0.00 0.00 183.43 0.00 0.00 225.98 4750.34 3950.00 153,14 11228.34 8450.00 182,28 11156.37 8400.00 RECEIVED Pmudhoe A61-06 Boy Dmitting lpeve~in9 Cy~indep - Leos~ Dis±ante Re~eeence ~/e(~- AGI-O6WP TV]l: 0- 8486 A~ Dieec+~ions I~et ~o TPue NoP~h SHTTH 600 550 500 450 40O 350 3O0 270° 240° 150° CL ELSESI PC]]NTS Weilpo th Slot D ston ce [101 L1-01 N/A [ I 0~ L 1-0~ N/A t109 L1-09 N/A I1 I0 L1-10 N/A ~114 LI-14 Il 15 LI-15 N/A 1127 L 1-27 N/A tlL:~ L1-L~ N/A Il30 LI-30 N/A [lipectio~ N?~ Re£ MD N/A N/~ N/~ N/A N/A N/~ N/A Ref TVD N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 180° RECEIVED A~chorag~ Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page Date: 1/5/: Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling AG1-06 TVD, N/S and E/W are measured from the WELLHEAD Closest Points WeLtpath Slot Distance Direction wgil WG[-01 8682.74 207.35 wgi2 WG]-02 8776.06 206.85 wgi3 WG]-03 8417;01 221.56 wgi4 WGI-04 8231.08 204.76 wgi5 WGI-05 9347.21 204.08 wgi6 WGI-06 9059.34 205.42 wgi7 WGI-07 9155.06 204.96 wgi8 WGI-08 9251.33 204.52 Ref MD Ref TVD 0.00 0.00 0.00 0.00 3814.63 3300.00 2950.89 2700.00 100.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 PPudhoe A61-06 Say DPi/~in9 l~eve~in9 Cy~inole~ - LeasCo Distance lee?epence ~e~l- AGI-O6WP TVD: 0 - 8486 A~I DiPec{ions I~e~ ~co TPue No~ch I© 270° 240° 33Co 2~0o I&o0 55O 5O0 45O 400 300 150o 1L:~OO CLOSEST F:'O]NTS Di~ectic~ N/A Re£ MD N/A N/A N/A N/A N/A N/A N/A N/A Ref TV]] N/A N/A N/A N/A N/A N/A N/A 180° RECEIVED JAN 1 ~ 1595 Alaska Oil &". uao Co~s. Commission Auchoraga Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Date: Page 1151~ Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling AG[-06 TVD, N/S and E/W are measured from the WELLHEAD Wetlpath Stol Distance ngil NG[-01 8530.95 ngi2 NG[-02 8420.58 ngi3 NGI-03 8311.00 ngi4 NGI-04 6776.13 ngi5 NGI-05 7842.56 ngi6 NGI-06 7983.08 ngi7 NGI-07 7874.25 ngi8 NGI-08 7766.18 ngi9 NGI-09 7657.55 ngilO NGI-IO 6922.23 ngi11 NGI-11 7095.94 ngi12 NGI-12 7335.83 ngi13 NGI-13 7229.33 ngi14 NGI-14 6549.39 Closest Points Direction Ref MD Ref TVD 191.07 50.00 50.00 191.38 200.00 200.00 191.72 50.00 50.00 191.05 8205.28 6350.00 197.34 4462.43 3750.00 192.76 0.00 0.00 193.12 0.00 0.00 193.50 600.00 600.00 193.88 50.00 50.00 214.55 3670.67 3200.00 220.37 2607.27 2450.00 195.11 300.00 300.00 195.55 50.00 50.00 204.95 4174.52 3550.00 PPudhoe AOI-06 t}o,y D~itting l~evetting Cytindep - Lees~ Distance Re~e~ence ~ett- AGI-O6WP YVD: 0- 8486 ?~, In~cePve~, 50 £~c, All Dinec{iens Ret -~o lnue Non'ch 3~ 600 550 500 ~50 400 350 300 270° 240° 120° 210° CLDSES7 POINTS Slot Dstonce Directim Re£ MD Ref TVD NG]-OJ N/A N/A N/A N/A NG]-C)~ NVA N/A N/A N/A NG]-03 N/A N/A N/A N/A NG]-04 I~&/A N/A N/A N/A N6]-C~ N/A N/A N/A N/A NG]-~ N/A N/A N/A NVA NG]-O? N/A N/A N/A N/A NG]-OB N/A N/A N/A NG]-Og N/A N/A N/A N/A NG]-IO N/A N/A N/A N/A NG]-II N/A N/A N/A N/A NG]-12 N/A N/A N/A N/A NG]-~3 N/A N/A N/A N/A NG]-]4 N/A N/A N/A N/A 180° 150° Alaska 0i~ & G&s Cons. Com~llS~'L~-~ Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page Date: 1/5/9 Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling AG[-06 TVD, N/S and E/W are measured from the WELLHEAD We[lpath Slot Distance Direction Closest Points Ref MD Ref TVD AGIO1MWD AGI-01 598.03 171.07 850.27 850.00 AGI-O2MWD AG[-02 480.01 169.95 0.00 0.00 AGI-O3MWl) AG[-03 358.83 169.88 500.00 500.00 AGI-O4WP AGI-04 238.38 172.07 0.00 0.00 AGI-O5WP AG[-05 120.00 169.94 0.00 0.00 gnchora~a Ppudhoe AGT-06 9ay n9 lpevellin9 Cx/indep - LeasCo I~e£e~ence R/el/- AGI-O6WP TVD: 0- 8486 +~±, Inte~ve/~ ALL DiPec±ions I~el ~co TPue 600 550 500 450 aO0 350 300 870° 210o CLOSES'[ ~/ellls~th Slot Ds¢once D;-ec±;on Ref MD Ref TVD ~]01 ~D AQ-OI 5~.03 J 7 ] .07 8~.87 ~.~ ~]-~VD ~]-~ 4~.01 169.~ 0.~ 0.~ ~]-O~D AG]-03 ~.83 ~ 6g.~ 5~.~ ~.~ ~]-~P ~]-~ 8~.~ J 78.07 0.~ 0.~ ~]-~ A6]-~ ] ~.~ ] 69.94 0.~ 0.~ Dis~cance 50 £~, ISHITN ~ _RECEIVED 120° JAN 1 ~ I~.9~ .Alaska.Oil .& Gas Cons, Cornmissio~ iAnchorag~ KOP: 613 MD MAX. ANGLE: 46.0° TD Departure · 6894' WELLHEAD. FMC JER JAN93 20" Conductor 13-3/8", 68~, L-80, BTC 3-3/8" Shoe 9-5/8", 47#, L-80, NSCC MD BKB 106' mD 4103'MD 7" Baker Hngr and Liner ~To-p Packer .... 9- 5/8" Shoe ~ 7", 26~, L-80, NSCC Liner PB TD 10526'MD 10676'MD .... Shoe '~~"~"-'8--1/2" hole TD _+11200'MD 11280'MD 11280'MD SUt-... C[ ~"OLE DIVE~TE.:I SYSTEM-:'..:? 10' Full Opening Valves Two lines venling 90 deg. apart in direclions that ensure sale down wind venling, and lending to a point at least 100' Irom any potential source o[ ignilion. Dresser SJeeve 35' or as required .o 10' Diverter Line 1. All pipe connections 150¢ ANSI Flanges or welded connections and secured to prevent movemenL 2_ Manual 10' lull opening valves mechanically connecfled to ensure that one valve is/ail-sale open at all times. 3. Ail tums are g0 deg. and targeted. 10' Full opening ball valve wi Hyd~ulic Actuator Cellar 20" Diverl. er Spool wi I0' Side Outlet MEM 1/3/'9o ....... o~l <~... b~,.s Cons. Commission Anchorage "[',kid r. ~J ~0 T~a c 3 r-triO tXJt~/'~ . ro /IuD __cC) ro ~'~r 1 - Bca~dt Dual TaJ~de~n Sl~a].e Shaker 1- ~~ 6-12" Cone Shale ~sander 1- l~l,~ 41611 w/16 ~nes 4811 w/16 ~nes (L~s/lter) 1 - t'~:il~ Abmspherlc Hud ~asser 1 - 200 gpm Operahlng Capacity. Centrifuge 15 - Brandh I-IK5 Hud Nix AgJ. tabors 1- 150 bbl. Trip TaDk 1 - Bacording dLrilling ~luid pit level indicator with both visual and audio ¥~arnlng devices at driller's console , 11.3 50 t~t~L I ~'~;'~ I r~o,, ~_jr,-,,~ j 7O 1.-Dr~llJJn9 fluid flc~..; sP.n. sor witl~ readout at drill~'~.',s console AUDI #2 5/8" 5,000 psi Stack m2.00 ~k 4.12 12.72 ~r,. 4.50 3.01 3.01 1.83 3.01 ..~ I 2.52 1.5 F / RKB1 [ I DRIP PAN HYDRIL R G FLOOR PIPE RAM BLIND RAM MUD CROSS 17.88 .. 22.38 25.3 PiPE RAM GROUND LEVEL MUD CROSS ~ASE FLG/ 30.23 34.25 35.75 · AGI-6CMT.×LS State: Well: Field: State Permit AG/#~ Pn,,dhoe Bay $$429 En~neef~ Work S heet~ Date: M. 1/15/'33 Ca~ing Type Casing Size -inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks 111 Cement-Yield 111 Cement- Cubic ft111 Cement- Cubic tt Cement- Sacks 112 ~ment - YWW ~2 Cement - Cu~c ~t~2 Cem~ - Cub~ ~{ ~2 Cement-Sacks Cement- Yield ~3 Cement - C~ic f{ Cement - Cubic f{ ~3 Ce~t- Cubic ft / Vd Cement- Fill Factor Condudo~ 20.000 7G. O00 30.000 0.00O 0.000 0.000 297.000 0.000 0.000 0.000 0.000 297.000 1.433 Surface 13.375 1G. O00 1,1G3.O00 2.170 2,523.710 2,523.710 400.000 1.160 464.000 464.000 0.00O 0.000 0.000 0.000 2,987.710 1.855 Liner 0.000 0.000 0.000 0.0O0 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 11DIV/O! Casing Type Casing Size Casir,:j Depth Hole Diameter Cement- Sacks Cement- Yield Cement- Cubic ti Cement-Cubic fi Cement- S~ks Cement- Yield Cement- Cubic It Cement- Cubic tt Cement- Sacks -Inches - Feet -Inches 111 111 111 111 112 112 112 112 113 Cement- Yield 113 Cement- Cubic fl 113 Cement- Cubic tt 113 Cement- Cubic tt / Vol Cemenl- Interval fl Top of Cement- Feet IntermedwIe 111 0.000 0.0O0 0.000 0.O0 0.00 0.00 0.00 0.00 0.00 0.0O 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/O! IIDIV/O! Intermediate 112 0.000 0.0O0 0.00O 0.O0 0.0O 0.00 0.00 0.00 0.00 0.0O 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/~ I~DIV/O! Production 12. 250 50O. O0 1.05 525.00 525.00 0.00 0.00 0.0O 0.00 0.00 0.00 0.00 0.00 525.00 1,734.80 7,680.2 Measul ed Dep-th Stale: Alaska Borough: Well: AGI #6 Field: Prudhoe Bay St. Perm ;93-09 Dale 1/15/93 Engr: M. Minder AGI-B.XLS Casing Interval Interval Size BO~o~ Top Le~V-. Lbs lA 13.375 29 68 ?_A 13,375 3500 120 3954 68 3A 9.625 8066 28 4A 7 8486 7980 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Descriptionescriptionescription Tension Grade Thread Lbs K-55 BTC 0 L-80 BTC 268872 10648 47 L-80 NSCC 0 800 26 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ff psi/ff 1B 9.5 0.494 0.394 2B 9.5 0.494 0.394 3B 10.2 0.530 0.430 4B 10,2 0.530 0.430 5B 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 8B 0.0 0.000 -0.100 9B O. 0 0.000 -0.100 1 OB 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3330 3450 1.0 3330 4930 1,5 3330 6870 3330 7240 22 0 0 #DIV/O! 0 0 #DIV/O.I 0 0 #DIVIO! 0 0 #DIV/OI. 0 0 #DIViO! 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 1C 277,032 1069 2C 268,872 1556 3C 500,456 1086 4C 20,8 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 3,86 5,79 2,17 604 29.04 0 8DIV/0! 0 8DIV/0! 0 8DIV/0! 0 8DIVI0! 0 8DIV/0! 0 8DIV/O! Collapse Collapse Pr-Bot-Psi Resist, CDF 59 1950 32.776 1379 2260 1.639 3472 4750 1.368 3652 5410 1.481 0 0 8888888 0 0 8DIV/0! · 0 0 8DIVIO! 0 0 8DIV/O! 0 0 8DIV/0! 0 0 8DIV/0! ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D T 1] 2 thru 3. 4. ru :F3] [10 & 133 (4) Casg ~_~/.~. /-/~-¢,~ [14 thru 22] [23 thru 28] 0 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company?CCf¢_~¢2 YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. ~_ Is well located proper distance from property line ................... L Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. ,L .... Is well to be deviated & is well bore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ AP Does operator have a bond in force ................................... Is a conservation order needed ....................................... , Is administrative approval needed ..................... .............. Is lease ntrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ ~ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic $ list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to~psig ..... Does choke manifold comply w/API RP-53 (blay 84) ...................... Is presence of H2S gas probable ...................................... Lease & Well ~ ,,,'~" ..~'~'.,~.~/, ,~..~'-~ NO REMARKS (6) Other ~/¢(.~ //~3/¢~ [29 thrO-3~1]-~ (7) Contact¢;;?¢_~ {/~ [32] ( 8 ) Ad d 1 ~/'~o,l~¢~/; /-J~¢'- ?~3' geo 1 ogy: eng i nee r i nq' DWJ MTM_~_ RADo-) ~ -7~ 1 RP~___~,_ BE~t!~u~ JDI-I~ rev 12/92 jo/6.0!1 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL 'UNIT 'ON/OFF POOL CLASS STATUS AREA ~ SHORE Add it ional remarks' UM MERIDIAn' SM Exp/Dev Inj ~ TYPE.: Redrill' Rev 0 --I ~0 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 VERIFICATION USTING FOR: ARCO ALASKA, INC. AGI-6 PRUDHOE BAY ¥~ ' °o%,. % IC OFILMED ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA INC. AGI-6 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Gamma Ray Borehole Corrected (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB mmho/m mmho/m MWD-API MWD-API deg deg mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 7 OCT 93 3:23p ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 I AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, 1 =ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0--OFF, 1 =ON 3 COMMENTS = I , ! Decode LIS Comment records: 0=OFF, 1 =ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO,1 =YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1 =tape units 6 LISTFREQ -- 50, ! Listing Frequency: Every n units 7 ESTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, 1 =ON 9 FORCETYP = 0 , !(I=BIT,2=LIS ... thru 35=ArrayAccoustic) (see table) 10 WRITEASCll -- 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP -- 1 , ~ Write Tape-Image File: 0=NO,1 =YES 12 SPLITES = I , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subfile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0, AUTOFILE = 0 , -- COMMENTS = I , INFORECS = 1 , MSTMETHOD = 0 , _ LISTFREQ = 50, LISTMAX = 0 , STATS = 0, FORCETYP = 0 , " WRITEASCll = O, WRITETAP = 1 , SPLITMS = 1 , -- SUBFILES = /0/, INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ! ._ !-- CONSTANT PARAMETERS ..........................................! AUTOCURV= O.O00000E+O0 AUTOFILE: O.O00000E+O0 COMMENTS: 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 LISTFREQ= 50.0000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPMTLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC-- O.O00000E+O0 WRITETAP= 1.00000 dpcoef-- 1.00000 dpcte = 1.00000 drlength = O.O00000E + O0 Iistwave = O.O00000E + O0 maxrecln = O.O00000E + O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 ffendep = O.O00000E+O0 tflevsp = O.O00000E+O0 tfstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcrlevsp= O.O00000E +00 wcrtop = O.O00000E +00 !-- ARRAY PARAMETERS ........................................... SUBFILES(1) = O.O00000E +00 SUBFILES(2) = -9999.00 ._ SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) = -9999.00 SUBFILES(10) = -9999.00 -- SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 -. SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 .- SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27): -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 " SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(36) = -9999.00 -. SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) = -9999.00 " SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50): -9999.00 --- SUBFILES(51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999.00 ._ SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) - -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 " SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 -- SUBFILES(71) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) = -9999.00 -. SUBFILES(77) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) -- -9999.00 SUBFILES(83) = -9999.00 SUBFILES(84) = -9999.00 -" SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 -- SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) ---9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) -- -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) SUBFILES(106) SUBFILES(108) SUBFILES(110) SUBFILES(112) SUBFILES(114) SUBFILES(116) SUBFILES(118) SUBFILES(120) SUBFILES(122) SUBFILES(124) SUBFILES(126) SUBFILES(128) = -9999.00 = -9999.00 = -9999.00 -- -9999.00 = -9999.00 = -9999.00 = -9999.00 -- -9999.00 -- -9999.00 -- -9999.00 = -9999.00 = -9999.00 = -9999.00 !-- STRING PARAMETERS INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1181\1181.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. -- Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) _. Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) --.. (Specify AUTOFILE = 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... -' (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD 93/10/7 1181 01 **** TAPE HEADER **** MWD 93/10/7 1181 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN1 JOB NUMBER: 1181 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD AGI-6 50-029-22333 Arco Alaska inc. BAKER HUGHES INTEQ 07 OCT 93 BIT RUN2 BIT RUN3 1181 R. GEHRES K. JOHNSTON S. WALLS S. WALLS 36.00 13.00 36 12N 14E 2173 2495 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 110.0 2ND STRING 16.000 13.375 4104.0 3RD STRING 12.250 PRODUCTION STRING REMARKS: $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8936.0 10590.0 $ BASELINE CURVE FOR SHIFTS: GRC CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH CADE CPDE DCCM GRAM _. 8900.0 8910.0 8910.0 8910.0 8910.0 8910.0 10094.5 10104.5 10104.5 10104.5 10104.5 10104.5 10140.5 10143.7 10143.7 10143.7 10143.7 10143.7 10205.5 10216.2 10216.2 10216.2 10216.2 10216.2 ._ 10265.5 10268.0 10268.0 10268.0 10268.0 10268.0 10308.0 10311.2 10311.2 10311.2 10311.2 10311.2 10367.2 10373.2 10373.2 10373.2 10373.2 10373.2 .- 10395.2 10400.0 10400.0 10400.0 10400.0 10400.0 10416.7 10422.0 10422.0 10422.0 10422.0 10422.0 10417.0 10422.5 10422.5 10422.5 10422.5 10422.5 10418.2 10423.7 10423.7 10423.7 10423.7 10423.7 10418.7 10424.0 10424.0 10424.0 10424.0 10424.0 10420.0 10425.2 10425.2 10425.2 10425.2 10425.2 10420.5 10425.5 10425.5 10425.5 10425.5 10425.5 " 10422.0 10427.0 10427.0 10427.0 10427.0 10427.0 10422.2 10427.5 10427.5 10427.5 10427.5 10427.5 10423.2 10428.5 10428.5 10428.5 10428.5 10428.5 .- 10427.5 10433.0 10433.0 10433.0 10433.0 10433.0 10428.0 10433.5 10433.5 10433.5 10433.5 10433.5 10428.5 10433.7 10433.7 10433.7 10433.7 10433.7 10428.7 10434.0 10434.0 10434.0 10434.0 10434.0 10429.2 10434.7 10434.7 10434.7 10434.7 10434.7 10429.7 10435.2 10435.2 10435.2 10435.2 10435.2 10430.0 10435.7 10435.7 10435.7 10435.7 10435.7 -- 10431.2 10437.0 10437.0 10437.0 10437.0 10437.0 10438.2 10444.2 10444.2 10444.2 10444.2 10444.2 10452.0 10460.2 10460.2 10460.2 10460.2 10460.2 __. 10455.7 10464.5 10464.5 10464.5 10464.5 10464.5 10470.0 10477.7 10477.7 10477.7 10477.7 10477.7 10489.2 10496.0 10496.0 10496.0 10496.0 10496.0 10489.5 10496.2 10496.2 10496.2 10496.2 10496.2 --' 10489.7 10496.7 10496.7 10496.7 10496.7 10496.7 10490.0 10497.0 10497.0 10497.0 10497.0 10497.0 10493.5 10501.0 10501.0 10501.0 10501.0 10501.0 -- 10494.0 10501.5 10501.5 10501.5 10501.5 10501.5 10494.2 10502.0 10502.0 10502.0 10502.0 10502.0 10494.5 10502.2 10502.2 10502.2 10502.2 10502.2 10494.7 10502.7 10502.7 10502.7 10502.7 10502.7 10499.0 10507.2 10507.2 10507.2 10507.2 10507.2 10504.0 10512.0 10512.0 10512.0 10512.0 10512.0 10504.2 10512.5 10512.5 10512.5 10512.5 10512.5 -- 10504.7 10512.7 10512.7 10512.7 10512.7 10512.7 10506.2 10514.2 10514.2 10514.2 10514.2 10514.2 10506.5 10514.7 10514.7 10514.7 10514.7 10514.7 -- 10512.5 10520.7 10520.7 10520.7 10520.7 10520.7 GRCM 10600.0 10600.0 10600.0 10600.0 10600.0 10600.0 $ BASELINE DEPTH PDEM RACM RADE ROPA 8900.0 8910.0 8910.0 8910.0 8910.0 8910.0 10094.5 10104.5 10104.5 10104.5 10104.5 10104.5 .. 10140.5 10143.7 10143.7 10143.7 10143.7 10143.7 10205.5 10216.2 10216.2 10216.2 10216.2 10216.2 10265.5 10268.0 10268.0 10268.0 10268.0 10268.0 10308.0 10311.2 10311.2 10311.2 10311.2 10311.2 10367.2 10373.2 10373.2 10373.2 10373.2 10373.2 10395.2 10400.0 10400.0 10400.0 10400.0 10400.0 10416.7 10422.0 10422.0 10422.0 10422.0 10422.0 -.- 10417.0 10422.5 10422.5 10422.5 10422.5 10422.5 10418.2 10423.7 10423.7 10423.7 10423.7 10423.7 10418.7 10424.0 10424.0 10424.0 10424.0 10424.0 .. 10420.0 10425.2 10425.2 10425.2 10425.2 10425.2 10420.5 10425.5 10425.5 10425.5 10425.5 10425.5 10422.0 10427.0 10427.0 10427.0 10427.0 10427.0 10422.2 10427.5 10427.5 10427.5 10427.5 10427.5 "' 10423.2 10428.5 10428.5 10428.5 10428.5 10428.5 10427.5 10433.0 10433.0 10433.0 10433.0 10433.0 10428.0 10433.5 10433.5 10433.5 10433.5 10433.5 .-- 10428.5 10433.7 10433.7 10433.7 10433.7 10433.7 10428.7 10434.0 10434.0 10434.0 10434.0 10434.0 10429.2 10434.7 10434.7 10434.7 10434.7 10434.7 10429.7 10435.2 10435.2 10435.2 10435.2 10435.2 10430.0 10435.7 10435.7 10435.7 10435.7 10435.7 10431.2 10437.0 10437.0 10437.0 10437.0 10437.0 10438.2 10444.2 10444.2 10444.2 10444.2 10444.2 -" 10452.0 10460.2 10460.2 10460.2 10460.2 10460.2 10455.7 10464.5 10464.5 10464.5 10464.5 10464.5 10470.0 10477.7 10477.7 10477.7 10477.7 10477.7 ._ 10489.2 10496.0 10496.0 10496.0 10496.0 10496.0 10489.5 10496.2 10496.2 10496.2 10496.2 10496.2 10489.7 10496.7 10496.7 10496.7 10496.7 10496.7 10490.0 10497.0 10497.0 10497.0 10497.0 10497.0 ._ 10493.5 10501.0 10501.0 10501.0 10501.0 10501.0 10494.0 10501.5 10501.5 10501.5 10501.5 10501.5 10494.2 10502.0 10502.0 10502.0 10502.0 10502.0 -- 10494.5 10502.2 10502.2 10502.2 10502.2 10502.2 10494.7 10502.7 10502.7 10502.7 10502.7 10502.7 10499.0 10507.2 10507.2 10507.2 10507.2 10507.2 .. 10504.0 10512.0 10512.0 10512.0 10512.0 10512.0 10504.2 10512.5 10512.5 10512.5 10512.5 10512.5 10504.7 10512.7 10512.7 10512.7 10512.7 10512.7 10506.2 10514.2 10514.2 10514.2 10514.2 10514.2 -' 10506.5 10514.7 10514.7 10514.7 10514.7 10514.7 10512.5 10520.7 10520.7 10520.7 10520.7 10520.7 10600.0 10600.0 10600.0 10600.0 10600.0 10600.0 -- $ BASELINE DEPTH RPCM 8900.0 8910.0 10094.5 10104.5 10140.5 10143.7 10205.5 10216.2 10265.5 10268.0 10308.0 10311.2 10367.2 10373.2 10395.2 10400.0 10416.7 10422.0 RPDE TCDM 8910.0 8910.0 10104.5 10104.5 10143.7 10143.7 10216.2 10216.2 10268.0 10268.0 10311.2 10311.2 10373.2 10373.2 10400.0 10400.0 10422.0 10422.0 ROPS 10417.0 10422.5 10422.5 10422.5 10418.2 10423.7 10423.7 10423.7 10418.7 10424.0 10424.0 10424.0 10420.0 10425.2 10425.2 10425.2 10420.5 10425.5 10425.5 10425.5 10422.0 10427.0 10427.0 10427.0 10422.2 10427.5 10427.5 10427.5 10423.2 10428.5 10428.5 10428.5 10427.5 10433.0 10433.0 10433.0 10428.0 10433.5 10433.5 10433.5 10428.5 10433.7 10433.7 10433.7 10428.7 10434.0 10434.0 10434.0 10429.2 10434.7 10434.7 10434.7 10429.7 10435.2 10435.2 10435.2 10430.0 10435.7 10435.7 10435.7 10431.2 10437.0 10437.0 10437.0 10438.2 10444.2 10444.2 10444.2 10452.0 10460.2 10460.2 10460.2 10455.7 10464.5 10464.5 10464.5 10470.0 10477.7 10477.7 10477.7 10489.2 10496.0 10496.0 10496.0 10489.5 10496.2 10496.2 10496.2 10489.7 10496.7 10496.7 10496.7 10490.0 10497.0 10497.0 10497.0 10493.5 10501.0 10501.0 10501.0 10494.0 10501.5 10501.5 10501.5 10494.2 10502.0 10502.0 10502.0 10494.5 10502.2 10502.2 10502.2 10494.7 10502.7 10502.7 10502.7 10499.0 10507.2 10507.2 10507.2 10504.0 10512.0 10512.0 10512.0 10504.2 10512.5 10512.5 10512.5 10504.7 10512.7 10512.7 10512.7 10506.2 10514.2 10514.2 10514.2 10506.5 10514.7 10514.7 10514.7 10512.5 10520.7 10520.7 10520.7 10600.0 10600.0 10600.0 10600.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 6 8936.0 9492.0 MWD 7 9492.0 10540.0 $ REMARKS: DATA HAS BEEN DEPTH SHIFTED TO ATLAS WlRELINE CASED HOLE GAMMA RAY DATA. $ CN · Arco Alaska inc. WN · AGI-6 FN · Prudhoe Bay COUN · North Slope STAT 'Alaska US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213141516 000 I 0000000 1 000 1 Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a [F ] 1.00000000 '- ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I GR MWD 68 I GAPI 4 4 98 660 71 6 2 RA MWD 68 I OHMM 4 4 98660 71 6 3 ROP MWD 68 1 FPHR 4 4 98 660 71 6 4 RP MWD 68 I OHMM 4 4 98 660 71 6 16 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 67 -- Tape File Start Depth = 8936.000000 Tape File End Depth = 10590.000000 Tape File Level Spacing = 0.500000 ,_ Tape File Depth Units = Feet **** FILE TRAILER **** -' LIS representation code decoding summary: Rep Code: 68 3718 datums Tape Subtile: 2 280 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subtile 3 is type: LIS **** FILE HEADER **** MWD .OO2 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8928.0 9492.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOIl'OM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11 FEB 93 M1.33 M1.33 MEMORY 0.0 8928.0 9492.0 0 43.3 46.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): DISPERSED 9.80 43.0 9.9 1200 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.977 MUD FILTRATE AT MT: 0.923 132.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN : Arco Alaska Inc. WN : AGI-6 FN : Prudhoe Bay COUN : North Slope STAT : Alaska 0.0 132.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 6. * FORMAT RECORD (TYPE# 64) -' Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) _, Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units I ATCM MWD 68 I -dB 2 ATDC MWD 68 I -dB 3 CADE MWD 68 I MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 I GAPI 7 PDCM MWD 68 I DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 I MINS 10 RACM MWD 68 1 OHMM 11 RADEMWD 68 I OHMM 12 ROPAMWD 68 1 FPHR 13 ROPS MWD 68 I FPHR 14 RPCM MWD 68 I OHMM 15 RPDE MWD 68 I OHMM 16 TCDM MWD 68 I DEGF APl APl APl APl Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 49866O 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 162 -" Tape File Start Depth = 8928.000000 Tape File End Depth = 9492.000000 Tape File Level Spacing = 0.250000 _. Tape File Depth Units = Feet **** FILE TRAILER **** '- LIS representation code decoding summary: Rep Code: 68 5058 datums Tape Subtile: 3 226 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9492.0 10590.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT)' BOTrOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13 FEB93 M1.33 M1.33 MEMORY 0.0 9492.0 10590.0 0 45.2 46.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1867-41 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT)' 12.250 0,0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 42.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.949 MUD FILTRATE AT MT: 0.870 136.0 MUD CAKE AT MT: 0.000 0.0 0.0 136.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 9492' TO 9548' MD (7284 TO 7323' TVD) WAS LOGGED 11 HOURS AFTER BEING DRILLED. INTERVAL FROM 10540' TO 10590' MD (8010 TO 8044' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET ON LOGGING SUITE. $ CN :Arco Alaska Inc. WN : AGI-6 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 -' ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod I ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 I -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 I 4 6 GRAM MWD 68 I GAPI 4 7 PDCM MWD ~ 68 I DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 1 MINS 4 10 RACMMWD 68 I OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPAMWD 68 I FPHR 4 13 ROPSMWD 68 I FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 RPDE MWD 68 1 OHMM 4 16 TCDM MWD 68 I DEGF 4 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 9866O 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 314 Tape File Start Depth = 9492.000000 Tape File End Depth = 10590.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13520 datums Tape Subtile: 4 382 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS **** TAPE TRAILER **** MWD 93/10/7 1181 01 **** REEL TRAILER **** MWD 93/10/7 1181 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 7 OCT 93 3:24p Elapsed execution time = 39.76 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR RA ROP RP 8936.0000 -999.2500 -999.2500 -999.2500 -999.2500 8936.5000 99.0654 -999.2500 -999.2500 -999.2500 8950.0000 76.2070 8.6253 -999.2500 6.4863 9000.0000 90.8673 9.3596 67.7000 6.9557 9050.0000 85.5332 9.2044 44.2625 6.8171 9100.0000 95.9057 9.9206 64.2475 7.1650 9150.0000 80.6654 8.5099 63.2836 6.6653 9200.0000 101.3308 20.1039 68.0962 11.0301 9250.0000 82.4851 20.3268 93.1842 12.263 1 9300.0000 83.3495 15.5810 49.0578 9.9263 9350.0000 83.4860 12.6591 55.4428 8.1344 9400.0000 86.2884 15.5738 66.8657 10.4783 9450.0000 89.8096 9.9750 24.7440 7.2185 9500.0000 85.6172 11.4814 81.5633 -999.2500 9550.0000 83.4313 7.5771 168.7564 7.0637 9600.0000 107.2551 3.5276 82.4159 3.6437 9650.0000 99.1201 3.5542 72.3242 3.5497 9700.0000 111.9036 4.1933 91.4807 4.2274 9750.0000 93.3094 7.3554 107.6243 6.6787 9800.0000 119.8725 4.8444 90.8688 4.4094 9850.0000 97.5153 8.4308 93.2601 8.1939 9900.0000 109.9114 4.5429 61.051 7 4.8536 9950.0000 120.3706 5.7820 42.6627 5.3972 10000.0000 132.2133 5.9084 56.3401 5.8987 10050.0000 1 64.6977 4.3537 81.3802 4.3629 10100.0000 130.6638 4.8720 44.8593 4.9297 10150.0000 146.4058 16.6772 140.7273 12.2227 10200.0000 133.2491 9.0393 87.5272 7.7063 10250.0000 125.1070 9.5048 98.6079 6.5451 10300.0000 95.7997 8.1672 110.1794 7.0958 10350.0000 148.3656 3.5851 94.5363 3.2034 10400.0000 1 40.0439 6.6688 122.6752 5.91 46 10450.0000 185.4008 7.0342 107.4514 5.6183 10500.0000 189.6836 8.1879 82.0738 7.8533 10550.0000 -999.2500 -999.2500 129.9237 -999.2500 10590.0000 -999.2500 -999.2500 130.1821 -999.2500 Tape File Start Depth = 8936.000000 Tape File End Depth = 10590.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8928.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 99.7726 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8928.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 91.7202 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8950.0000 0.3714 0.4366 106.1400 144.1232 90.2566 98.4988 8.4590 8.2060 -999.2500 11.1545 9.4215 -999.2500 -999.2500 6.6452 6.9385 -999.2500 9000.0000 0.3451 0.4100 99.5289 134.2134 87.3656 96.1218 8.0693 7.8207 62.7961 12.0009 10.0473 57.4964 55.3732 7.1297 7.4508 132.3500 9050.0000 0.3610 0.4268 103.6896 143.9310 90.2029 96.9520 8.4518 8.1986 66.2417 11.4762 9.6442 49.8364 49.2206 6.6538 6.9478 134.7125 9100.0000 0.3315 0.3974 96.4458 135.1504 87.6420 92.4027 8.1065 7.8577 52.3389 12.4893 10.3685 61.6117 63.1398 7.0812 7.3992 135.3875 9150.0000 0.3322 0.3979 96.5649 134.1579 87.3487 90.9469 8.0670 7.8186 56.7745 12.4821 10.3557 64.2841 64.0735 7.1327 7.4539 137.1313 9200.0000 0.1214 0.1903 47.5068 81.8363 69.8951 91.8112 5.7521 5.5351 92.1947 31.6762 21.0496 58.1166 58.1287 11.6159 12.2192 137.3000 9250.0000 0.1810 0.2468 61.0071 96.3031 75.3068 88.1718 6.4455 6.2162 118.7075 22.1647 16.3915 28.5373 27.3292 9.8553 10.3839 135.7761 9300.0000 0.2598 0.3280 79.6545 123.5359 83.8911 85.7151 7.6339 7.3913 92.6862 15.8192 12.5542 38.1554 32.5127 7.7857 8.0948 131.0000 DEPTH ATCM ATDC CADE CPDE DCCM G RAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9350.0000 0.3345 0.4031 97.8506 149.3187 91.7270 91.9932 8.6578 8.4032 63.1011 12.3769 10.2197 66.1427 65.8781 6.4175 6.6971 134.2625 9400.0000 0.3739 0.4405 107.1107 152.0523 92.5012 88.5812 8.7624 8.5057 86.3227 11.0790 9.3361 71.6636 73.7708 6.3023 6.5767 137.4125 9450.0000 0.2709 0.3369 81.7823 116.8731 82.0404 90.6284 7.3550 7.1150 71.6983 15.1977 12.2276 38.3242 32.1909 8.1727 8.5563 132.3500 9492.0000 0.2631 0.3321 -999.2500 124.3395 85.3304 98.1240 7.6708 7.4241 53.7251 15.5647 -999.2500 85.1499 84.3782 7.5034 8.0425 136.6250 Tape File Start Depth = 8928.000000 Tape File End Depth = 9492.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 4 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9492.0000 0.2631 0.3321 -999.2500 124.3395 85.3304 98.1240 7.6708 7.4241 53.7251 15.5647 -999.2500 85.1499 64.3782 7.5034 8.0425 136.6250 9492.2500 0.3151 0.3811 92.4512 127.1380 86.2226 95.4677 7.7876 7.5379 226.2568 15.4719 10.8165 65.1499 84.8927 7.3361 7.8655 136.6250 9500.0000 0.4033 0.4624 112.5990 122.5728 83.8306 86.9177 7.5947 7.3517 744.9388 10.2703 8.8811 74.3746 74.7369 7.7979 8.1584 137.1875 9550.0000 0.5830 0.6404 159.0495 160.7051 94.8725 85.4512 9.0838 8.8248 45.6377 6.9906 6.2874 15.3256 15.8786 5.9681 6.2226 126.8656 9600.0000 0.8907 0.9485 247.5267 254.4981 117.3657 93.9320 12.1553 11.8728 41.2225 4.3629 4.0400 79.7382 78.7530 3.7902 3.9293 122.0000 9650.0000 0.9904 1.0466 277.8613 269.2518 120.4944 92.9774 12.5845 12.2994 50.0550 3.8559 3.5989 63.3383 61.1014 3.5848 3.7140 125.0375 9700.0000 0.7941 0.8484 217.6219 194.7581 103.6565 108.1267 10.2790 10.0096 31.2982 4.9740 4.5951 86.1108 91.5527 4.9365 5.1346 127.1375 9750.0000 0.5258 0.5838 143.9012 148.9865 91.6336 107.9191 8.6452 8.3907 50.3454 7.8027 6.9492 110.9308 111.1863 6.4316 6.7120 129.8750 9800.0000 0.6369 0.6972 174.5571 195.4863 103.6346 105.1522 10.3033 10.0339 45.6773 6.3536 5.7288 94.2248 98.8980 4.9164 5.1154 130.7750 9850.0000 0.5163 0.5760 141.8437 156.5115 93.7404 113.8405 8.9303 8.6712 48.9787 7.9554 7.0500 98.5077 91.8731 6.1243 6.3893 133.2500 DEPTH DCCM RACM RPDE ATCM GRAM RADE TCDM ATDC PDCM ROPA CADE PDDC ROPS CPDE PDEM RPCM 9900.0000 95.4147 7.2832 6.1463 9950.0000 130.9618 3.7245 3.1089 0.5611 101.5274 6.5153 135.1625 1.0200 173.4968 3.4679 136.5125 0.6198 9.1572 58.9890 1.0797 14.0221 61.2530 153.4840 8.8976 62.0696 288.3585 13.7294 60.0346 162.6996 62.0388 5.8954 321.6527 42.5003 3.0069 10000.0000 91.6758 5.1814 6.7088 10050.0000 118.1459 4.5129 3.8741 0.7658 133.4861 4.8114 138.4250 0.8649 175.8210 4.1663 138.6500 0.8148 8.6483 96.8325 0.9238 12.2621 69,5518 207.8378 8.3937 98.9759 240.0186 11.9790 70.4252 149.0576 56.4491 6.4252 258.1248 54,3311 3.7374 10100.0000 106.2236 5.3688 4.8706 10150.0000 68.6036 16.9155 12.7482 0.7419 133.6521 4.9170 140.5625 0.2421 130.6638 13.7110 141.1250 0.7993 10.6293 60.4165 0.2997 5.5829 104.5587 203.3752 10.3573 55.5932 72.9343 5.3687 105.0093 205.3147 61.9659 4.6854 78.4426 36.7710 12.1058 10200.0000 80.4210 12.1889 8.9427 10250.0000 89.8248 10.9179 7.0124 0.3397 118.2123 10.3005 143.0375 0,3794 128.0905 9.2644 143.4312 0.4000 7.1389 86.9966 0.4439 8.4002 109.9436 97.0825 6.9016 90.8688 107.9398 8.1481 118.1325 111.8231 37.7937 8.5356 142.6046 26.3475 6.7144 10300.0000 83.3786 9.1706 8.2593 10350.0000 97.5274 5.9893 5.8603 0.4503 68.3236 8.0752 144.2750 0.6722 157.7249 5.4643 144.5750 0.5067 7.5338 85.6155 0.7276 9.4440 110.6048 123.8360 7.2904 85.1653 183.0071 9.1818 114.1886 121.0749 34.8125 7.8901 170.6395 24.9710 5.6246 10400.0000 85.0920 9.1888 7.8976 0.4495 178.1453 8.0704 145.6250 0.5070 7.7634 130.3285 123.9095 7.5173 140.0124 126.6205 99,9264 7.5491 DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10450.0000 0.4247 0.4832 117.8534 125.2860 84.6795 189.4346 7.7081 7.4631 31.3500 9.7382 8.4851 104.2760 110.8856 7.6291 7.9817 143.3000 10500.0000 0.4761 0.5340 130.8704 135.3170 87.6966 222.4724 8.1135 7.8646 68.4564 8.6567 7.6411 92.8860 90.7949 7.0716 7.3901 145.2125 10550.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 149.1201 154.0819 -999.2500 -999.2500 144.9500 10590.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 132.2973 132.2973 -999.2500 -999.2500 145.9625 Tape File Sta~ Depth = 9492.000000 Tape File End Depth = 10590.000000 Tape File Level Spacing = 0.250000 Tape File Depth UnEs = Feet Tape Subtile 5 is type: LIS Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LoGs WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION sTRING REMARKS: RUN1 5915.01 B. ESARY SEE REMARKS AGI-6 500292233300 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 14-MAY-93 RUN2 36 12N 14E 2173 2495 49.00 13.00 RUN3 RECEIVED AUG ;5 1 199 Alaska Oil & Gas Cons, OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 10582.0 8.500 11200.0 DLL/MLL/AC/GR. LOGS WITNESSED BY: J. GAFFNEY / K. MARTIN. CIRCULATION STOPPED @ 20:15 24-APR-93. LOG ORIGINALY TIED TO SBT DATED 24-MAR-93. IT WAS LATER DISCOVERED THAT THE SBT WAS OFF DEPTH. THERE- FOR THE OPEN HOLE LOGS WERE REVISED. THE MARKED LINE USED FOR OPEN HOLE LOGGING WAS USED AS DEPTH CONTROL. THE REPEAT PASS GOT APPROXIMATELY 12' DEEPER THAN THE MAIN PASS. THAT EXTRA DATA FROM THE REPEAT IS SPLICED ONTO THE END OF THE MAIN PASS DATA IN THE MERGED FILE. THE GAMMA RAY WAS LOGGED ABOVE THE CASING POINT TO TIE INTO THE SBT LOG. CYCLE SKIPS ARE AT: 10680 - 10706 10719 - 10752 11909 - 11909 11133 - 11152 IC OFIL 9 DUE TO CONCERNS OVER THE WELL TAKING FLUID, THE COMPANY REPRESENTATIVE FELT ADDITIONAL PASSES WERE NOT WARRANTED TO CORRECT THE CYCLE SKIPS. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth shifted and clipped curves; (including cased hole). DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GR DLL BCS $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH STOP DEPTH 10579.0 11154.0 10579.0 11196.0 10579.0 11173.0 BASELINE DEPTH 10559.0 10578.5 10582.5 10594.5 10609.0 10625.5 10629.0 10640.0 10640.5 10662.0 10667.5 10673.0 10688.5 10702.0 10713.5 10749.0 10753.5 10792.5 10793.0 10806.5 10807.0 10818.0 10818.5 10840.0 10866.0 10872.5 10873.0 10878.5 10880.0 10901.5 10904.0 10906.0 10908.0 10908.5 10930.0 10930.5 10934.0 10948.0 10951.0 10959.5 OPEN HOLE GR (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH MLL DT 10559.0 10559.0 10702.0 10712.5 10754.5 10791.5 10806.0 10818.5 10839.5 10872.5 10906.0 10908.0 10930.5 10934.5 LLD 10559.0 10578.5 10629.0 10639.0 10702.0 10713.5 10753.5 10583.5 10594.5 10609.0 10626.0 10641.5 10661.5 10667.5 10672.5 10687.5 10701.5 10712.5 10749.5 10794.0 10806.5 10819.0 10839.5 10840.0 10865.5 10878.0 10900.5 10872.5 10879.5 10905.0 10908.0 10909.5 10930.0 10932.5 10949.0 10960.0 10934.0 10951.5 all runs merged 10984.5 11005.5 11008.0 11009.5 11012.5 11026.0 11037.5 11038.0 11040.5 11048.0 11061.5 11072.5 11080.5 11092.0 11094.0 11109.5 11118.0 11118.5 11132.5 11134.5 11140.5 11219.0 $ MERGED DATA SOURCE LDWG TOOL CODE GR GR DLL DLL BCS BCS $ REMARKS: CN WN FN COUN STAT 10984.0 11006.5 11009.5 11026.5 11037.0 11037.5 11005.5 11009.0 11012.0 11025.5 11035.5 11039.5 11048.5 11060.5 11061.0 11071.5 11080.5 11078.5 11079.0 11091.0 11118.0 11109.5 11134.0 11095.5 11119.0 11131.0 11132.5 11140.0 11219.0 11219.0 11219.0 RUN NO. PASS NO. MERGE TOP 1 6 10579.0 1 7 11129.0 1 6 10579.0 1 7 11131.0 1 6 10579.0 1 7 11139.0 MERGE BASE 11129.0 11154.0 11131.0 11196.0 11139.0 11173.0 OPEN HOLE SECTION OF MAIN PASS. MTEM, CALl, TEND, & TENS WERE SHIFTED WITH MLL. LL3 & SP SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : AGI-6 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR BCS 68 2 DT BCS 68 3 TEND BCS 68 1 GAPI 1 US/F 1 LB 4 67 465 06 6 4 85 618 83 5 4 56 053 87 1 4 TENS BCS 68 1 LB 4 5 MLL DLL 68 1 OHMM 4 6 CALl DLL 68 1 IN 4 7 LL3 DLL 68 1 OHMM 4 8 LLD DLL 68 1 OHMM 4 9 SP DLL 68 1 MV 4 10 MTEM DLL 68 1 DEGF 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 55 4 56 053 87 4 39 859 45 4 08 564 98 4 42 480 89 4 39 859 45 4 23 415 80 4 84 503 82 40 Tape File Start Depth = 11210.000000 Tape File End Depth = 10579.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13894 datums Tape Subfile: 2 219 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10069.0 10579.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PASS. $ : ARCO ALASKA INCORPORATED : AGI-6 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH DLL 68 1 GAPI 4 2 MTEM DLL 68 1 DEGF 4 3 TEND DLL 68 1 LB 4 4 TENS DLL 68 1 LB 4 4 57 515 01 6 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 10579.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5796 datums Tape Subfile: 3 49 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 6 0.2500 VENDOR TOOL CODE START DEPTH GR 10067.0 MLL 10573.0 DLL AC $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 10573.0 10574.0 STOP DEPTH 11153.0 11196.0 11142.0 11173.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR AC MIS KNJT KNJT MLL $ CABLE HEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUALLATEROLOG GAMMARAY BHC ACOUSTILOG MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICRO LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : 25-APR- 93 FSYS REV. J001 VER 1.1 2015 24-APR-93 427 25-APR-93 11200.0 11200.0 10069.0 11196.0 1200.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 1609EA/1603MA 3967XA 3921NA 3921NA 1233XA 8.500 10582.0 10579.0 PRO FLO 9.10 55.0 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI-6 : PRUDHOE BAY : NORTH SLOPE : ALASKA 143.9 0.116 69.0 0.058 143.9 0.103 69.0 0.000 0.0 0.134 69.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 4 2 AC AC 68 1 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 RMLL MLL 68 1 OHMM 4 7 CAL MLL 68 1 IN 4 8 RD DLL 68 1 OHMM 4 9 RS DLL 68 1 OHMM 4 10 SP DLL 68 1 MV 4 11 SPD DLL 68 1 F/MN 4 12 TEMP DLL 68 1 DEGF 4 GAPI 4 06 969 49 US/F 4 48 852 89 4 81 285 47 4 95 558 30 4 95 558 30 4 71 857 46 4 90 132 02 4 39 859 45 4 40 514 81 4 23 415 80 4 11 639 82 4 84 503 82 6 1 0 1 1 1 1 0 0 5 1 1 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 255 Tape File Start Depth Tape File End Depth = 11210.000000 = 10000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 76828 datums Tape Subfile: 4 336 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 7 0.2500 VENDOR TOOL CODE START DEPTH GR 10573.0 MLL 10573.0 DLL 10573.0 AC 10573.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLE HEAD TENSION TEMP TEMPERATURE PCM PULSE CODE MODULATOR MIS MASS ISOLATION SUB DLL DUAL LATEROLOG GR GAMMARAY AC BHC ACOUSTILOG MIS MASS ISOLATION SUB KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT MLL MICRO LATEROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): STOP DEPTH 11173.0 11216.0 11162.0 11193.0 25-APR-93 FSYS REV. J001 VER 1.1 2015 24-APR-93 524 25-APR-93 11200.0 11200.0 10069.0 11196.0 1200.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 1609EA/1603MA 3967XA 3921NA 3921XA 1233XA 8.500 10582.0 10579.0 PRO FLO 9.10 55.0 9.8 6.2 143.9 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI-6 : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.116 69.0 0.058 143.9 0.103 69.0 O.00O 0.0 0.134 69.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 RMLL MLL 68 1 OHMM 7 CAL MLL 68 1 IN 8 RD DLL 68 1 OHMM 9 RS DLL 68 1 OHMM 10 SP DLL 68 1 MV 11 SPD DLL 68 1 F/MN 12 TEMP DLL 68 1 DEGF 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 71 857 46 1 4 4 90 132 02 1 4 4 39 859 45 0 4 4 40 514 81 0 4 4 23 415 80 5 4 4 11 639 82 1 4 4 84 503 82 1 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 141 Tape File Start Depth = 11220.000000 Tape File End Depth = 10555.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40390 datums Tape Subfile: 5 220 records... Minimum record length: 58 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS 01 **** REEL TRAILER **** 93/ 6/ 8 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 8 JUN 93 5:18p Elapsed execution time = 15.76 seconds. SYSTEM RETURN CODE = 0