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188-033
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: OPERABLE: Injector W-35 (PTD #1880330) RWO complete Date:Monday, September 29, 2025 10:21:11 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 28, 2025 7:24 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector W-35 (PTD #1880330) RWO complete Mr. Wallace, Injector W-35 (PTD #1880330) passed MIT-T & MIT-IA post rig on 09/19. The well is now classified as OPERABLE. An online MIT-IA will be performed once post rig intervention work is complete and the well is on stable injection. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, August 2, 2025 10:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector W-35 (PTD #1880330) tubing cut for sidetrack Mr. Wallace, Injector W-35 (PTD #1880330) had the tubing cut on 07/18 in preparation for the upcoming sidetrack. The well will now be 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 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 State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 21 Township: 11N Range: 12E Meridian: Umiat Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10620 ft MD Lease No.: ADL 028263 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 119 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2662 Feet Csg Cut@ Feet Intermediate: 9-5/8" O.D. Shoe@ 9864 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 10620 Feet Csg Cut@ Feet Tubing: 4-1/2" O.D. Tail@ 9585 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 10577 ft 9064 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2750 2641 2608 IA 92 93 93 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Nicholes Draper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Plug back for redrill. A slick line tag was done with a 2-inch bailer. The returns were thick like putty that was cement colored. June 29, 2025 Bob Noble Well Bore Plug & Abandonment PBU W-35 Hilcorp North Slope LLC PTD 1880330; Sundry 325-303 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0629_Plug_Verification_PBU_W-35_bn 9 9 9 9 9 999 9 9 9 9 9 9 9 9 9 999 99 99 9 9Plug back for redrill James B. Regg Digitally signed by James B. Regg Date: 2025.08.27 14:03:19 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-35 PRUDHOE BAY UNIT W-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/26/2025 W-35 50-029-21799-00-00 188-033-0 N SPT 8339 1880330 2500 540 2750 2652 2608 0 0 0 0 OTHER P Bob Noble 7/17/2025 MIT-TxIA, to 2500 psi as per sundry 325-303 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 W-35 Inspection Date: Tubing OA Packer Depth 540 2750 2652 2610IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250718163055 BBL Pumped:3.2 BBL Returned:2.5 Tuesday, August 26, 2025 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector W-35 (PTD #1880330) tubing cut for sidetrack Date:Monday, August 4, 2025 9:45:31 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, August 2, 2025 10:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector W-35 (PTD #1880330) tubing cut for sidetrack Mr. Wallace, Injector W-35 (PTD #1880330) had the tubing cut on 07/18 in preparation for the upcoming sidetrack. The well will now be 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Tyson Shriver Subject:FW: PBU W-35 (PTD# 188-033) Pre-Rig P&A Update Date:Tuesday, July 1, 2025 12:00:21 PM Thank you Tyson for verifying hydrostatic overbalance to the reservoir. You have approval to move forward with your plan below. Jack From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Tuesday, July 1, 2025 11:46 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: PBU W-35 (PTD# 188-033) Pre-Rig P&A Update Jack, As a follow-up I have written out the current fluid profiles in the wellbore and associated hydrostatic pressures: TBG: Diesel – surface to 2,500’ MD/TVD x 6.8 ppg = 884 psi 9.8 ppg brine – 2,500’ TVD to St #3 (7,409’ TVD) x 9.8 ppg = 2502 psi Diesel – St #3 (7,409’ TVD) to 8,735’ MD (7,784’ TVD) x 6.8 ppg = 133 psi Fresh Water – 8,735’ MD (7,784’ TVD) to TOC 9,064’ MD (8,021’ TVD) x 8.33 ppg = 103 psi Total tubing hydrostatic above reservoir cement plug = 3,622 psi IA: Deisel – surface to 2,500’ MD/TVD x 6.8 ppg = 884 psi 9.8 ppg brine – 2,500’ TVD to St #3 (7,409’ TVD) x 9.8 ppg = 2,502 psi 9.6 ppg brine – St #3 (7,409’ TVD) to Prod Packer (8,340’ TVD) x 9.8 ppg = 465 psi Total IA hydrostatic above production packer = 3,851 psi Thanks, Tyson Shriver Hilcorp Alaska PBU GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Tyson Shriver Sent: Monday, June 30, 2025 10:54 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: PBU W-35 (PTD# 188-033) Pre-Rig P&A Update Jack, The reservoir abandonment plug for W-35 was pumped 6/27. A successful pressure test of the reservoir plug was performed and witnessed by AOGCC 6/29 to 2,608 psi. SL subsequently tagged TOC at 9,064’ MD (planned TOC of ~9,400 ‘ MD). St #1 and #2 are now inaccessible so SL is actively working to pull St #3 for the upcoming wellbore circ out to 9.8 ppg brine. Circulating out through St #3 will still leave fluid with “sufficient density” between the plugs. Please let me know if you have any issues with this minor change to the approved sundry (attached). Thanks, Tyson Shriver Hilcorp Alaska PBU GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 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. By Grace Christianson at 2:00 pm, May 14, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.14 13:45:30 - 08'00' Torin Roschinger (4662) 325-303 X DSR-6/3/25A.Dewhurst 02JUN25 10-407 JJL 6/4/25 X AOGCC witness tag TOC and MIT of both reservoir cements plugs. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.05 15:00:40 -08'00'06/05/25 RBDMS JSB 061025 Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Well Name:W-35 API Number:50-029-21799-00 Current Status:Operable – WAG Injector Permit to Drill #:188-033 Estimated Start Date:6/9/2024 Rig:SL, EL, FB Reg.Approval Req’std?10-403 Estimated Duration:Two weeks Regulatory Contact:Abbie Barker Date Reg. Approval Rec’vd: First Call Engineer:Tyson Shriver (907) 564-4542 (O) (406) 690-6385 (M) Second Call Engineer:Hunter Gates (215) 498-7274 (M) AFE: Current Bottom Hole Pressure:3,602 psi @ 8,800’ TVD (2010 SBHPS) Max. Anticipated Surface Pressure:2,722 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:200 psi (Taken on 1/6/2022) Min ID:3.813” X-Nipple 1,983’ MD Max Angle:44 Deg @ 8,800’ MD Brief Well Summary: W-35 is an Ivishak WAG injector. The well was drilled and completed in 1988 as a producer and later converted to injection in 2002. W-35 does not directly support any offset production and is only used to maintain reservoir pressure in the Ivishak. Ivishak reservoir pressure is very healthy in the area so W-35 is injecting <1000 bwpd. This voidage rate can be made up in one of the 6 remaining active Ivishak injectors. The plan forward is to P&A the current wellbore and do a shallow kickoff in the 13-3/8” casing for a recomplete to the Schrader Bluff formation. The proposed sidetrack will be a two string design with a 9-5/8” intermediate casing string and a regulated injection liner. Objective: Place an Ivishak reservoir and confining layer cement plug. Plug to be confirmed via tag and pressure test. A second cement plug placed in the tubing and IA will cover the Schrader Bluff interval and again confirmed via tag and pressure test. The 4-1/2” tubing will then be cut prior to rig arrival to setup for a decomplete. Annular Cement: 7” Liner: Cemented with 280 sx 15.4 Class ‘G’ cement. Full returns were noted throughout the job. A subsequent CBL showed cement up to the 9-5/8” casing shoe with minimal / poor cement from the 9-5/8” casing shoe to the top of 7” liner. 9-5/8” Casing: Cemented with lead of 805 sx (261 bbls) 13.5 ppg Class ‘G’ w/ 8% bentonite and tail 500 sx (102 bbls) 15.8 ppg Class ‘G’. Total 363 bbls. No losses were reported. Assuming 30% hole washout and accounting for shoe-track volume, TOC is estimated to be at 5,020’ MD. Top of Sag River formation – 9,905’ MD (8,646’ TVD). Top of Schrader formation – 5,066’ MD (4,822’ TVD). Base of Schrader formation – 5,684’ MD (5,314’ TVD). Recent Integrity: 04/21/2025 -> PPPOT-T & IC PASSED pre-rig screening 01/18/2024 -> AOGCC MIT-IA PASSED to 3,125 psi 01/08/2022 -> Offline AOGCC MIT-IA PASSED to 2,724 psi Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 WBL Steps: 1 F MIT-IA TO 2,500 PSI AND OA INJECTIVITY TEST 2 S DRIFT TO TOP OF FISH 3 F INJECTIVITY TEST AND PUMP RESERVOIR ABANDONMENT PLUG OVER IVISHAK 4 F MIT-T TO 2,500 PSI (AOGCC WITNESSED) 5 S TAG TOC (AOGCC WITNESSED). PULL ST #1 DGLV. CIRC WELL TO 9.8 PPG BRINE. INSTALL ST #1 DMY. PULL ST #6 DMY AND LEAVE OPEN POCKET. 6 F PUMP TXIA CEMENT PLUG OVER SCHRADER 7 F CMIT-TXIA TO 2,500 PSI (AOGCC WITNESSED) 8 S TAG TOC (AOGCC WITNESSED), DRIFT FOR JET CUTTER 9 E JET CUT TUBING 10 F CMIT-TXIA TO 2,500 PSI Procedural Steps: Fullbore – Pressure test and OA injectivity 1. Perform MIT-IA to 2,500 psi. Max applied 2,750 psi. Can be done with well online. 2. Attempt to pump into OA with diesel. Max OA pressure of 1,200 psi. If able to obtain injectivity, perform 5-minute injectivity test at <1,200 psi. Slickline – Drift wellbore 1. Drift to top of fish at 10,308’ ELM. Fullbore – Injectivity test & reservoir abandonment plug 1. Pump Ivishak reservoir cement plug. Planned TOC in the tubing is ~9,400’ MD (8,268’ TVD). Max tubing pressure 3,000 psi. a) 275 bbls FW, SW, or 1% KCl (1.5x wellbore volume). b) 40 bbls 15.8 ppg Class ‘G’ cement c) 2 bbls water to clear lines d) Two 7” Foam-Balls e) 5 bbls water behind balls f) 136 bbls heated 70 deg F diesel. 2. Pump initial displacement at 5-7 bpm to kill and fluid pack well. Confirm injectivity prior to mixing and pumping cement. 3. 40 bbls of cement is enough volume to fill 7” liner from bottom perf, exposed 9-5/8” casing, and tubing up to ~9,400’ MD. 4. Displace cement at ~5 bpm. With 130 bbls diesel away, drop rate to ~1 bpm and pump final 6 bbls of displacement. 5. Deepest allowable TOC is 9,575’ MD (8,396’ TVD, 250’ TVD above top of pool). Pipe Volumes: x 4-1/2” tubing: 9,556’ x 0.0152 bpf = 145.3 bbls x 9-5/8” casing: (9,653’ – 9,556’) x 0.0732 bpf = 7.1 bbls x 7” Liner (to bottom perf): (10,437’ – 9,653’) x 0.0383 bpf = 30 bbls x Total volume of wellbore to bottom perf = 182.4 bbls Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Cement Volume: x 4-1/2” tubing: (9,556’ – 9,400’) x 0.0152 bpf = 2.4 bbls x 9-5/8” casing: (9,653’ – 9,556’) x 0.0732 bpf = 7.1 bbls x 7” Liner (to bottom perf): (10,437’ – 9,653’) x 0.0383 bpf = 30 bbls x Total volume of cement with TOC @ 9,400’ = 39.5 bbls Cement Design: Cement Type: Class ‘G’ Density: 15.8 ppg Thickening Time: 5-hrs minimum API Fluid Loss: 80-120 cc/30 min BHST: 190 deg F BHCT: 170 deg F Pump Time: 40 minutes at assumed rate of 5 bpm Fullbore – Pressure test reservoir cement plug and circ out 1. MIT-T to 2,500 psi target pressure, max applied 2,750 psi (AOGCC witnessed). 2. Circulate well to 9.8 ppg brine and diesel freeze protect. Pump down IA taking returns to production. Jumper TBG x IA and allow diesel FP to U-tube. x Tubing Volume to St #1 = 142 bbls x IA Volume to St #1 = 499 bbls x Diesel FP Volume TxIA to 2500’ MD = 172 bbls Slickline – Tag cement plug and pull GLV 1. Tag TOC (AOGCC witnessed). 2. Pull DGLV from St #1. If valve cannot be pulled, move up hole and pull the DGLV from St #2. 3. Re-install DGLV in St #1. 4. Pull DGLV from St #6 and leave pocket open. Fullbore – TxIA cement plug 1. Pump Schrader Bluff (Polaris Oil Pool) cement plug down the tubing taking returns from IA. Planned TOC in the TBG and IA 4,300’ MD (4,202’ TVD). Max tubing pressure is 3,000 psi. a) 160.5 bbls diesel. b) 69.6 bbls fresh water c) 164 bbls 15.8 ppg Class ‘G’ cement d) 2 bbls FW to clear lines e) Two 7” Foam-Balls f) 18 bbls FW spacer behind balls g) 45.6 bbls diesel. 2. This schedule will leave the IA FP’d down to 3,000’ MD. 3. 164 bbls of cement is enough volume to fill TBG and IA from 6,691’ to 4,300’ MD. Pipe Volumes: x 4-1/2” tubing: 6,691’ x 0.0152 bpf = 101.7 bbls x 4-1/2” x 9-5/8” annulus: 6,691’ x 0.0535 bpf = 358 bbls x Total volume of wellbore to St #6 = 459.7 bbls Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Cement Volume: x 4-1/2” tubing: (6,691’ – 4,300’) x 0.0152 bpf = 36.3 bbls x 4-1/2” x 9-5/8” annulus: (6,691’ – 4,300’) x 0.0535 bpf = 127.9 bbls x Total volume of cement with TOC @ 4,300’ = 164.2 bbls Cement Design: Cement Type: Class ‘G’ Density: 15.8 ppg Thickening Time: 5-hrs minimum API Fluid Loss: 80-120 cc/30 min BHST: 110 deg F BHCT: 90 deg F Pump Time: 50 minutes at assumed rate of 5 bpm Fullbore – Pressure test TxIA cement plug 1. CMIT-TxIA to 2,500 psi target pressure, max applied 2,750 psi (AOGCC witnessed). Slickline – Tag cement plug and drift 1. Tag TOC (AOGCC witnessed). 2. Drift for jet cutter. E-Line – Jet cut tubing 1. MU Jet Cutter for 4-1/2” 12.6# tubing. 2. RIH and jet cut tubing 1’ above nearest collar at 4,000’. Fullbore – CMIT-TxIA and OA injectivity test 1. CMIT-TxIA to 2,500 psi target pressure, max applied 2,750 psi. Attachments: Wellbore Schematic Proposed Schematic Tubing Tally Sundry Change Form Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Current Wellbore Schematic Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Proposed Wellbore Schematic Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Tubing Tally Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Reservoir Abandonment & Pre-Rig PBU W-35 PTD: 188-033 Sundry Change Form 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 Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Plug for Redrill against P&A" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 188-033 325-303 PBU W-35 A.Dewhurst 02JUN25 A.Dewhurst 02JUN25 1 Christianson, Grace K (OGC) From:Tyson Shriver <tyson.shriver@hilcorp.com> Sent:Wednesday, June 4, 2025 8:48 AM To:Lau, Jack J (OGC) Subject:RE: [EXTERNAL] PBU W-35 (PTD: 188-033) Res P&A Jack, Apologies for the delay in response. After cement plug #1 is in place (Ivishak plug), the lowest most accessible dummy gas lift valve will be pulled and the well circulated to 9.8 ppg brine and only a diesel freeze protect. The DGLV will be pulled from St #6 and cement plug #2 (Schrader plug) will be pumped into the Tubing and IA. There should be 9.8 ppg brine trapped between the two cement plugs from the lowest most accessible GLM to St #6. Above cement plug #2 diesel will be left in the hole until the rig shows up. Prior to pulling the upper completion, the rig will circulate the tubing and IA to 9.8 ppg brine through the tubing cut at ~4,000’ MD. This can also be done pre- rig. If you would prefer to have this step included in the pre-rig P&A sundry it can be added for completeness. Estimated Schrader BluƯ reservoir pressure is ~2,000 psi. Thank you, Tyson Shriver Hilcorp Alaska PBU GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, May 30, 2025 2:11 PM To: Tyson Shriver <tyson.shriver@hilcorp.com> Subject: [EXTERNAL] PBU W-35 (PTD: 188-033) Res P&A Good afternoon Tyson – A question regarding your sundry application. x I see you have diesel between the cement plugs. Please provide the reservoir pressure for the Schrader and demonstrate that diesel meets the following requirement: 20 AAC 25.112. Well plugging requirements. 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. 2 (f) Each of the respective intervals of a wellbore between the various plugs must be Ʊlled with Ʋuid of suƯicient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-35 PRUDHOE BAY UNIT W-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/04/2024 W-35 50-029-21799-00-00 188-033-0 W SPT 8339 1880330 3000 1182 1183 1183 1183 6 6 6 7 REQVAR P Kam StJohn 1/18/2024 AOGCC2 Year MIT-IA per AIO AA 3C.002 Max anticipated pressure 3000 psi 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 W-35 Inspection Date: Tubing OA Packer Depth 118 3207 3147 3125IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240119130337 BBL Pumped:10 BBL Returned:9.2 Monday, March 4, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:Brooks, Phoebe L (OGC) Cc:Regg, James B (OGC); AOGCC Records (CED sponsored) Subject:FW: W-35 (PTD# 188033) AIO 3C.002 MIT-IA test date Date:Thursday, September 29, 2022 11:17:20 AM Attachments:image002.png From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, September 28, 2022 10:11 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: W-35 (PTD# 188033) AIO 3C.002 MIT-IA test date Chris, We have decided to keep AIO 3C.002 in place for W-35 (PTD# 188033) after removal of the patch on 12/6/2021 and passing AOGCC witnessed MIT-IA on 1/8/2022 per well work under sundry # 321-575. Due to the 24 month pressure test occurring 3 months earlier than the required AA anniversary date in April 2022, we are going to set the next required MIT-IA test date to be in January of 2024 such that we do not exceed the 24 month testing requirement. Let me know if you require us to take an alternative course of action. Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 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 permanentlydelete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. Noresponsibility 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: OPERABLE: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Date:Monday, March 14, 2022 3:02:02 PM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 11, 2022 7:32 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: OPERABLE: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) has been on MI for 29 days with no IA re-pressurization that would indicate TxIA communication on MI. The tubing patch will remain out and the well is now classified as OPERABLE. We plan to leave the AA AIO 20-010 in place for now and may request to cancel at some point in the future provided no annular communication is observed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Thursday, February 10, 2022 1:08 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: UPDATE UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) PWI has been shut in and the well is swapping to MI. The under evaluation clock is being reset to day 1 to allow for up to 30 days of monitoring for re-pressurization on MI per approved sundry #321-575. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 3, 2022 2:31 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) was put on PWI on 01/11/22 with the patch out of hole as outlined in the email below. There has not been any evidence of IA re-pressurization during the PWI period. The well is scheduled for a WAG swap in February and per the Sundry, it requires a 30-day monitoring period while on MI to ensure the IA re-pressurization has not worsened with the patch out of hole. The well is on day 23 of PWI and I wanted to get a plan in place before day 30. I am thinking the cleanest way to approach this is to continue monitoring the well Under Evaluation on PWI. I will notify you when the swap to MI has been completed and we will continue monitoring Under Evaluation for up to 30-days on MI. Please let me know if this plan is agreeable. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 11, 2022 9:50 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) currently operates under AA AIO 3C.002 for slow IA re-pressurization. A patch was pulled to facilitate downhole work outlined in approved Sundry #321-575. Past re-pressurization trends pre and post patch setting, along with doubt surrounding the accuracy of a previous LDL indicates the patch may not be affecting the IA re-pressurization. As part of the approved Sundry, on 01/08/22 DHD performed an AOGCC witnessed MIT-IA to 2,724 psi proving two competent barriers. The well can now be placed on Injection to monitor for increased IA re- pressurization with the patch out of hole. If the re-pressurization rate is observed to have increased, a patch will be re-installed. The well is now UNDER EVALUATON and will initially be on PWI. If IA re-pressurization does not increase, it will be swapped to MI for further monitoring. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 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: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Date:Wednesday, February 9, 2022 11:19:46 AM Attachments:image001.png W-35_NOVEMBER2021_10-403.pdf EXTERNAL 20220107 1628 APPROVAL REDUCED MIT-IA Test Pressure W-35 (PTD # 188033) Change to MIT-IA Test Pressure Under Sundry 321-575.msg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 3, 2022 2:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) was put on PWI on 01/11/22 with the patch out of hole as outlined in the email below. There has not been any evidence of IA re-pressurization during the PWI period. The well is scheduled for a WAG swap in February and per the Sundry, it requires a 30-day monitoring period while on MI to ensure the IA re-pressurization has not worsened with the patch out of hole. The well is on day 23 of PWI and I wanted to get a plan in place before day 30. I am thinking the cleanest way to approach this is to continue monitoring the well Under Evaluation on PWI. I will notify you when the swap to MI has been completed and we will continue monitoring Under Evaluation for up to 30-days on MI. Please let me know if this plan is agreeable. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 11, 2022 9:50 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W-35 (PTD # 1880330) currently operates under AA AIO 3C.002 for slow IA re-pressurization. A patch was pulled to facilitate downhole work outlined in approved Sundry #321-575. Past re-pressurization trends pre and post patch setting, along with doubt surrounding the accuracy of a previous LDL indicates the patch may not be affecting the IA re-pressurization. As part of the approved Sundry, on 01/08/22 DHD performed an AOGCC witnessed MIT-IA to 2,724 psi proving two competent barriers. The well can now be placed on Injection to monitor for increased IA re- pressurization with the patch out of hole. If the re-pressurization rate is observed to have increased, a patch will be re-installed. The well is now UNDER EVALUATON and will initially be on PWI. If IA re-pressurization does not increase, it will be swapped to MI for further monitoring. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 1 Carlisle, Samantha J (OGC) From:Wallace, Chris D (OGC) Sent:Tuesday, January 18, 2022 1:45 PM To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector W-35 (PTD #1880330) Monitor with Patch Out of Hole Attachments:W-35_NOVEMBER2021_10-403.pdf; [EXTERNAL] 20220107 1628 APPROVAL REDUCED MIT-IA Test Pressure W-35 (PTD # 188033) Change to MIT-IA Test Pressure Under Sundry 321-575 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 11, 2022 9:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector W‐35 (PTD #1880330) Monitor with Patch Out of Hole Mr. Wallace, WAG Injector W‐35 (PTD # 1880330) currently operates under AA AIO 3C.002 for slow IA re‐pressurization. A patch was pulled to facilitate downhole work outlined in approved Sundry #321‐575. Past re‐pressurization trends pre and post patch setting, along with doubt surrounding the accuracy of a previous LDL indicates the patch may not be affecting the IA re‐pressurization. As part of the approved Sundry, on 01/08/22 DHD performed an AOGCC witnessed MIT‐IA to 2,724 psi proving two competent barriers. The well can now be placed on Injection to monitor for increased IA re‐ pressurization with the patch out of hole. If the re‐pressurization rate is observed to have increased, a patch will be re‐ installed. The well is now UNDER EVALUATON and will initially be on PWI. If IA re‐pressurization does not increase, it will be swapped to MI for further monitoring. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. 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Supervisor 1 FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT W-35 Insp Num: mitSAM220108165619 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 11, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W-35 PRUDHOE BAY UNIT W-35 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21799-00-00 Inspector Name: Austin McLeod Permit Number: 188-033-0 Inspection Date: 1/8/2022 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-35 Type Inj N TVD 8339 Tubing 195 193 193 194 PTD 1880330 Type Test SPT -Test psi 2500 IA 1027 2753 2732 - 2724 BBL - Pumped: 42 BBL Returned: 4.6 OA 0 0 0 0 Interval OTR P/F P Notes: Sundry 321-575 to 3000psi. 2500psi test approved by Mel Rixse. No plug in tubing Tuesday, January 11, 2022 Page 1 of I 1 Carlisle, Samantha J (OGC) From:Rixse, Melvin G (OGC) Sent:Friday, January 7, 2022 5:15 PM To:Wyatt Rivard Cc:AOGCC Records (CED sponsored) Subject:[EXTERNAL] 20220107 1628 APPROVAL REDUCED MIT-IA Test Pressure W-35 (PTD # 188033) Change to MIT-IA Test Pressure Under Sundry 321-575 Attachments:Sundry_321-575_111221.pdf; AIO 3C.002 04-27-20.pdf Wyatt, Hilcorp is approved to perform MIT‐IA to 2500 psi on the attached Sundry 321‐575 on the witness MIT‐IA step 22. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907‐793‐1231 Office 907‐223‐3605 Cell 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 Mel Rixse at (907‐793‐1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, January 7, 2022 1:49 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: W‐35 (PTD # 188033) Change to MIT‐IA Test Pressure Under Sundry 321‐575 Hello Mel, We have successfully performed a tailpipe tubing cut and add perfs on Schrader Bluff WAG injector W‐35 (PTD#188‐033) per sundry 321‐575 (attached). We are currently preparing for step 22 of the procedure, completing an AOGCC witnessed MIT‐IA with well SI to determine if a tubing patch should be reset. I would like to make a change to the target MIT‐IA test pressure, targeting 2500 psi instead of originally proposed 3000 psi. Looking at current, post perforating, SI tubing pressures of ~200 psi, we will be at roughly 90% of our tubing collapse rating when factoring in a 3000 psi IA test pressure and derating the 4.5” 12.6 lb tubing for previously logged 55% penetrations. A 2500 psi test pressure will place us at ~75% collapse rating and we have analogs of testing at this differential including a 2500 psi shut‐in MIT‐IA on 7/31/15. The well’s IA was most recently tested to 3056 psi on 4/10/20 while on injection however a 2500 psi test pressure meets the max anticipated injection pressure requirement of the admin approval for this well (AIO 3C.002 attached for CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 reference). A TIO plot is included below for reference showing last two years of injection with both water (Injecting at ~1500‐1600 psi) and MI cycles (Injecting at ~2300‐2400psi). Please let me know if this change is acceptable. Thank You, Wyatt Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads) O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.com Hilcorp Alaska, LLC | Anchorage, AK 99503 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Wyatt Rivard Cc:AOGCC Records (CED sponsored) Subject:20220107 1628 APPROVAL REDUCED MIT-IA Test Pressure W-35 (PTD # 188033) Change to MIT-IA Test Pressure Under Sundry 321-575 Date:Friday, January 7, 2022 5:15:06 PM Attachments:image001.png Sundry_321-575_111221.pdf AIO 3C.002 04-27-20.pdf Wyatt, Hilcorp is approved to perform MIT-IA to 2500 psi on the attached Sundry 321-575 on the witness MIT-IA step 22. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, January 7, 2022 1:49 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: W-35 (PTD # 188033) Change to MIT-IA Test Pressure Under Sundry 321-575 Hello Mel, We have successfully performed a tailpipe tubing cut and add perfs on Schrader Bluff WAG injector W-35 (PTD#188-033) per sundry 321-575 (attached). We are currently preparing for step 22 of the procedure, completing an AOGCC witnessed MIT-IA with well SI to determine if a tubing patch should be reset. I would like to make a change to the target MIT-IA test pressure, targeting 2500 psi instead of originally proposed 3000 psi. Looking at current, post perforating, SI tubing pressures of ~200 psi, we will be at roughly 90% of our tubing collapse rating when factoring in a 3000 psi IA test pressure and derating the 4.5” 12.6 lb tubing for previously logged 55% penetrations. A 2500 psi test pressure will place us at ~75% collapse rating and we have analogs of testing at this differential including a 2500 psi shut-in MIT-IA on 7/31/15. The well’s IA was most recently tested to 3056 psi on 4/10/20 while on injection however a 2500 psi test pressure meets the max anticipated injection pressure requirement of the admin approval for this well (AIO 3C.002 attached for reference). A TIO plot is included below for reference showing last two years of injection with both water (Injecting at ~1500-1600 psi) and MI cycles (Injecting at ~2300-2400psi). Please let me know if this change is acceptable. Thank You, Wyatt Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 anintended 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 havereceived this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of thismessage 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 andother checks as it considers appropriate. 7. 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/Pool(s): 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU W-35 Pull Patch, Cut Tubing Tail Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 188-033 50-029-21799-00-00 341H ADL 0028262 10620 Conductor Surface Intermediate Production Liner 9216 80 2624 9863 967 10577 20" 13-3/8" 9-5/8" 7" 9182 41 - 121 40 - 2662 39 - 9901 9653 - 10620 2430 41 - 121 40 - 2662 39 - 8643 8454 - 9216 9575 2260 4760 5410 None 5020 6870 7240 10316 - 10380 4-1/2" 12.6# L-80 36 - 96238969 - 9021 Structural 4-1/2" TIW Packer No SSSV Installed 9498, 8340 No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, PRUDHOE OIL 11/22/2021 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 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:19 pm, Nov 09, 2021 321-575 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.09 14:32:03 -09'00' Stan Golis (880) DSR-11/10/21DLB 11/10/2021MGR10NOV21 10-404 State witness MIT-IA to 3000 psi. 24 hour notice. X dts 11/12/2021 11/12/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.12 08:29:09 -10'00' Well: W-35 PTD:1880330 Job: Add Perf Well Name:W-35 API Number:50-029-21799-00 Current Status:Online Injector Rig:SL/EL Estimated Start Date:11/20/2021 Estimated Duration:5days Reg.Approval Req’std?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:1880330 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:150 psi (Taken on 10/17/15) Min ID:2.313” X NIP @ 1981’ MD Max Angle:44 Deg @ 8800’ MD Brief Well Summary: W-35 is an active Ivishak WAG injector currently injecting in the 41P and 31P. All offsets are perf'd throughout zone 4, but injection in W-35 is only below the 41N. Strong MI responses have been observed in Z3 offsets, expect similar response with additional Zone 4 perfs. Since 2008, a WRP has been lodged in the tubing tail at ~9575’ CTMD despite extensive slickline and CTU fishing and milling attempts. In order to access the target perf interval, the tubing tail will be cut off immediately above WRP (below packer)to allow it to fall to bottom. W-35 currently operates under AIO 3C.002 for slow/intermittent IA pressurization while under gas injection. The well has a tubing patch across the SSSV profile after a previous acoustic LDL showed possible leak signature at SSSV. Acoustic tools were not run in tandem and it is unclear if signature was result of “road noise”/tool movement through profile. Well consistently passed MIT-IAs whether or not patch was installed and it is not clear if patch affected IA pressurization under MI. Patch will be pulled to facilitate downhole wellwork and left out of the well and well returned to MI injection under eval. If IA pressurization is observed to have increased, patch will be reset across the SSSV. Objective: Cut tubing tail to access perforations. Add perforations to 42P to provide MI sweep benefit to offset producers. Notes on Wellbore Condition: - Well had a passing MIT-IA to 3056 psi on 4/10/20 - Tubing is plastic coated. Schmoo and plastic debris observed on previous interventions - Well injects through tubing punches from 9556’-9561’ Procedure: Slickline 1. RU SL Unit and pressure test 2. RIH and pull 45KB tubing patch from 1939’-1974’ x Patch set 6/3/16 x Patch currently has MCX installed in X Nip at 1981’ 3. RIH and drift for Jet cutter to stuck WRP at ~9575’ MD CTMD. x Last tag on 8/9/15 with CTU at 9575’ CTMD after tagging up early on X-Nip at 9554’ CTMD -00 DLB Well: W-35 PTD:1880330 Job: Add Perf x Last Slickline tag at 9556’ SLM. 4. Bail schmoo/plastic as needed to reach WRP x Cutting tubing tail as deep/short as possible is critical to access future perf targets 5. RDMO Eline 6. RU EL unit and pressure test 7. MU largest OD Jet Cutter sized for 4.5” tubing cut 8. RIH and correlate to tubing tally dated 5/6/88 x Ensure tubing cut is well below 30ft tubing packer assembly at 9498’ MD x Space out to ensure tubing cut is not directly on collar x Contact OE Wyatt Rivard 1(509) 670-8001 or Brodie Wages at 1(713)380-9836 prior to Cutting for final approval of tie in. 9. Cut tubing as deep as possible. x A tubing cut at ~ 9570’ MD should free up roughly 50ft of tubing tail to fall to bottom. 10. Once cut, drop down just deep enough to verify WRP/tubing tail fallen. Use caution in area of tubing cut due to lack of WLEG 11. POOH Slickline 12. RU SL Unit and pressure test 13. MU Drift, RIH and confirm tubing cut. x Use caution in area of tubing cut due to lack of WLEG 14. RIH and attempt to tag top of fish/tubing stub. x Last tag during Eline 12/15/06 RPM log was at 10355’ MD. x Top of open perf at 10316’ MD. x New top of fish/tubing stub should be between 10,270’- 10305’ MD depending on level of fill in perfs. 15. MU 2-7/8” gun drift, RIH and drift to TD. Eline 16. RU EL unit and pressure test 17. MU GR/CCL and, 2-7/8”, 6spf, 60 deg phased gun with premium deep penetrating charges. 18. RIH and correlate to reference log SLB Composite IPROF/Sigma log dated 12-15-2006 x Use caution in area of tubing cut/tubing tail due to lack of WLEG x Perf intervals may be adjusted based on top of fish/how much liner is accessible x Contact OE Wyatt Rivard 1(509) 670-8001 or Brodie Wages at 1(713)380-9836 prior to perforating for final approval of tie in. Table 1: W-35 Proposed Ad-Perf Gun Runs 19. Perforate Gun Run # 1 per Table 1: W-35 Proposed Ad-Perf Gun Run. Gun Run #Perf Top Perf Bottom Perf Length 1 ±10293 ±10302 9 2 ±10248 ±10286 38 3 ±10230 ±10245 15 Total 62 Well: W-35 PTD:1880330 Job: Add Perf a. Note any tubing pressure change in WSR. b. POOH 20. Repeat steps 17-19 for gun runs 2 & 3. 21. RDMO DHD/Operations 22. MIT-IA to 3000 psi to confirm IA integrity with patch removed x Notify AOGCC at least 24 hours prior to performing MIT-IA . x If passing, return well to injection and monitor IA pressurization under 30 day Eval x If shut-in MIT fails or if post injection pressurization is worse with patch removed, proceed with contingent Eline patch set. Eline ***Contingency only, if pre injection MIT fails or IA pressurization under MI injection increased after patch pulled*** 23. MU one run 4.5” tubing patch to cover 1939’-1974’. 24. MIT-IA to 3000 psi only if previous MIT-IA failed x Notify AOGCC at least 24 hours prior to performing MIT-IA . 25. RD Eline. 26. RTI well. Attachments: -Current Wellbore Schematic -Proposed Wellbore Schematic -Tie In Log Well: W-35 PTD:1880330 Job: Add Perf Current Wellbore Schematic -00 DLB Well: W-35 PTD:1880330 Job: Add Perf Proposed Wellbore Schematic Well: W-35 PTD:1880330 Job: Add Perf W-35 Tie-In Log Well: W-35 PTD:1880330 Job: Add Perf Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 8, 2021Subject: Changes to Approved Sundry Procedure for Well W-35Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 3C.002 Mr. Oliver Sternicki Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: AIO-20-010 Request for administrative approval to allow well W-35 (PTD 1880330) to be online in water alternating gas (WAG) injection service with a known inner annulus repressurization Prudhoe Bay Unit (PBU) W-35 (PTD 1880330) Prudhoe Bay Field Prudhoe Oil Pool Dear Mr. Sternicki: By letter dated April 16, 2020 BP Exploration (Alaska), Inc. (BPXA) requested administrative approval to continue WAG injection in the subject well. In accordance with Rule 10 of Area Injection Order (AIO) 3C.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BPXA’s request for administrative approval to continue WAG injection in the subject well. BPXA reported an anomalous inner annulus (IA) repressurization to AOGCC in April 2020 and initiated additional diagnostics and monitoring. BPXA completed a passing state waived witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) on April 10, 2020 which indicates that W-35 exhibits at least two competent barriers to the release of well pressure. The well has an IA build up rate of approximately 8 psi/day and AOGCC finds that BPXA is able to manage the IA pressure with periodic pressure bleeds. BPXA has installed wireless gauges on W- Pad that allow for real time monitoring of the IA and outer annuli. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 3C.002 April 27, 2020 Page 2 of 2 AOGCC’s approval to continue WAG injection in PBU W-35 is conditioned upon the following: 1.BPXA shall record wellhead pressures and injection rate daily; 2.BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3.BPXA shall perform a mechanical integrity test of the inner annulus (MITIA) every 2 years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 1500 psi; 4.BPXA shall limit the well’s IA operating pressure to 2000 psi; 5.BPXA shall continue to maintain wireless pressure gauges and real time electronic monitoring of the well annuli; 6.BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7.After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8.The MIT anniversary date is April 10, 2020. DONE at Anchorage, Alaska and dated April 27, 2020. Jeremy M. Price Daniel T. Seamount, Jr. Jessie L. Chmielowski Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector W-35 (PTD #1880330) needs MIT-IA with patch out of hole Date:Monday, December 13, 2021 1:34:58 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, December 11, 2021 2:07 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector W-35 (PTD #1880330) needs MIT-IA with patch out of hole Mr. Wallace, Injector W-35 (PTD #1880330) is being prepared for E-line Ad-Perfs. The tubing patch was recently pulled as part of this prep work. While it is not clear if the patch is needed after further inspection of the past LDL, the well work Sundry (#321-575) requires a passing MIT-IA with the patch out of hole before the well can placed back on Injection. The well will now be classified as NOT OPERABLE for tracking purposes until the MIT-IA is completed. Plan Forward: 1. If the MIT-IA passes, the well will be monitored Under Eval for 30-days on MI 2. If the MIT-IA fails, the patch will be re-installed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. 7. 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/Pool(s): 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU W-35 Pull Patch, Cut Tubing Tail Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 188-033 50-029-21799-00-00 341H ADL 0028262 10620 Conductor Surface Intermediate Production Liner 9216 80 2624 9863 967 10577 20" 13-3/8" 9-5/8" 7" 9182 41 - 121 40 - 2662 39 - 9901 9653 - 10620 2430 41 - 121 40 - 2662 39 - 8643 8454 - 9216 9575 2260 4760 5410 None 5020 6870 7240 10316 - 10380 4-1/2" 12.6#L-80 36 - 96238969 - 9021 Structural 4-1/2" TIW Packer No SSSV Installed 9498, 8340 No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, PRUDHOE OIL 11/22/2021 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 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:19 pm, Nov 09, 2021 321-575 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.09 14:32:03 -09'00' Stan Golis (880) DSR-11/10/21DLB 11/10/2021MGR10NOV21 10-404 State witness MIT-IA to 3000 psi. 24 hour notice. X dts 11/12/2021 11/12/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.12 08:29:09 -10'00' RBDMS HEW 11/15/2021 Well: W-35 PTD:1880330 Job: Add Perf Well Name:W-35 API Number:50-029-21799-00 Current Status:Online Injector Rig:SL/EL Estimated Start Date:11/20/2021 Estimated Duration:5days Reg.Approval Req’std?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:1880330 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:150 psi (Taken on 10/17/15) Min ID:2.313” X NIP @ 1981’ MD Max Angle:44 Deg @ 8800’ MD Brief Well Summary: W-35 is an active Ivishak WAG injector currently injecting in the 41P and 31P. All offsets are perf'd throughout zone 4, but injection in W-35 is only below the 41N. Strong MI responses have been observed in Z3 offsets, expect similar response with additional Zone 4 perfs. Since 2008, a WRP has been lodged in the tubing tail at ~9575’ CTMD despite extensive slickline and CTU fishing and milling attempts. In order to access the target perf interval, the tubing tail will be cut off immediately above WRP (below packer)to allow it to fall to bottom. W-35 currently operates under AIO 3C.002 for slow/intermittent IA pressurization while under gas injection. The well has a tubing patch across the SSSV profile after a previous acoustic LDL showed possible leak signature at SSSV. Acoustic tools were not run in tandem and it is unclear if signature was result of “road noise”/tool movement through profile. Well consistently passed MIT-IAs whether or not patch was installed and it is not clear if patch affected IA pressurization under MI. Patch will be pulled to facilitate downhole wellwork and left out of the well and well returned to MI injection under eval. If IA pressurization is observed to have increased, patch will be reset across the SSSV. Objective: Cut tubing tail to access perforations. Add perforations to 42P to provide MI sweep benefit to offset producers. Notes on Wellbore Condition: - Well had a passing MIT-IA to 3056 psi on 4/10/20 - Tubing is plastic coated. Schmoo and plastic debris observed on previous interventions - Well injects through tubing punches from 9556’-9561’ Procedure: Slickline 1. RU SL Unit and pressure test 2. RIH and pull 45KB tubing patch from 1939’-1974’ x Patch set 6/3/16 x Patch currently has MCX installed in X Nip at 1981’ 3. RIH and drift for Jet cutter to stuck WRP at ~9575’ MD CTMD. x Last tag on 8/9/15 with CTU at 9575’ CTMD after tagging up early on X-Nip at 9554’ CTMD -00 DLB Well: W-35 PTD:1880330 Job: Add Perf x Last Slickline tag at 9556’ SLM. 4. Bail schmoo/plastic as needed to reach WRP x Cutting tubing tail as deep/short as possible is critical to access future perf targets 5. RDMO Eline 6. RU EL unit and pressure test 7. MU largest OD Jet Cutter sized for 4.5” tubing cut 8. RIH and correlate to tubing tally dated 5/6/88 x Ensure tubing cut is well below 30ft tubing packer assembly at 9498’ MD x Space out to ensure tubing cut is not directly on collar x Contact OE Wyatt Rivard 1(509) 670-8001 or Brodie Wages at 1(713)380-9836 prior to Cutting for final approval of tie in. 9. Cut tubing as deep as possible. x A tubing cut at ~ 9570’ MD should free up roughly 50ft of tubing tail to fall to bottom. 10. Once cut, drop down just deep enough to verify WRP/tubing tail fallen. Use caution in area of tubing cut due to lack of WLEG 11. POOH Slickline 12. RU SL Unit and pressure test 13. MU Drift, RIH and confirm tubing cut. x Use caution in area of tubing cut due to lack of WLEG 14. RIH and attempt to tag top of fish/tubing stub. x Last tag during Eline 12/15/06 RPM log was at 10355’ MD. x Top of open perf at 10316’ MD. x New top of fish/tubing stub should be between 10,270’- 10305’ MD depending on level of fill in perfs. 15. MU 2-7/8” gun drift, RIH and drift to TD. Eline 16. RU EL unit and pressure test 17. MU GR/CCL and, 2-7/8”, 6spf, 60 deg phased gun with premium deep penetrating charges. 18. RIH and correlate to reference log SLB Composite IPROF/Sigma log dated 12-15-2006 x Use caution in area of tubing cut/tubing tail due to lack of WLEG x Perf intervals may be adjusted based on top of fish/how much liner is accessible x Contact OE Wyatt Rivard 1(509) 670-8001 or Brodie Wages at 1(713)380-9836 prior to perforating for final approval of tie in. Table 1: W-35 Proposed Ad-Perf Gun Runs 19. Perforate Gun Run # 1 per Table 1: W-35 Proposed Ad-Perf Gun Run. Gun Run #Perf Top Perf Bottom Perf Length 1 ±10293 ±10302 9 2 ±10248 ±10286 38 3 ±10230 ±10245 15 Total 62 Well: W-35 PTD:1880330 Job: Add Perf a. Note any tubing pressure change in WSR. b. POOH 20. Repeat steps 17-19 for gun runs 2 & 3. 21. RDMO DHD/Operations 22. MIT-IA to 3000 psi to confirm IA integrity with patch removed x Notify AOGCC at least 24 hours prior to performing MIT-IA . x If passing, return well to injection and monitor IA pressurization under 30 day Eval x If shut-in MIT fails or if post injection pressurization is worse with patch removed, proceed with contingent Eline patch set. Eline ***Contingency only, if pre injection MIT fails or IA pressurization under MI injection increased after patch pulled*** 23. MU one run 4.5” tubing patch to cover 1939’-1974’. 24. MIT-IA to 3000 psi only if previous MIT-IA failed x Notify AOGCC at least 24 hours prior to performing MIT-IA . 25. RD Eline. 26. RTI well. Attachments: -Current Wellbore Schematic -Proposed Wellbore Schematic -Tie In Log Well: W-35 PTD:1880330 Job: Add Perf Current Wellbore Schematic -00 DLB Well: W-35 PTD:1880330 Job: Add Perf Proposed Wellbore Schematic Well: W-35 PTD:1880330 Job: Add Perf W-35 Tie-In Log Well: W-35 PTD:1880330 Job: Add Perf Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 8, 2021Subject: Changes to Approved Sundry Procedure for Well W-35Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date P&A UJ - 35 i 3, Reqq, James B (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Monday, May 4, 2020 1:00 PM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (CED); Wallace, Chris D (CED) �P�c 11 Cc: Cc: AK, GWO DHD Well Integrity; Sternicki, Oliver R ,\ I Subject: BPXA April 2020 MIT Forms Attachments: BPXA APR 2020 MIT FORMS.zip my Attached are the completed AOGCC MIT forms for tests performed by BP in April 2020. Well: PTD: Notes: 03-07B 2191820 Initial MIT post CTD 03-36B 2191520 Initial MIT post CTD 04-10 1760420 2 year test required by A10 4E.036 04-15 1780370 4 year test 04-17 1860200 4 year test 16-28 1920620 Producer. MIT -T to test reservoir P&A cement plug. GC -1E 1890680 2 year test. Class II disposal well. L -119A 2191550 Initial MIT post CTD M -13A 2011650 MIT -T and MIT -IA. CO 736 post IA cement job. P1-122 2141850 In anticipation of possible AA request P-30 2141160 4 year test R -22A 2141640 2 year test required by AIO 4G.008. Sets anniversary date. S-112 2021350 2 year test required by AIO 22D.001 S -201A 2190920 Initial MIT post rotary sidetrack S-210 2190570 Initial MIT. New well. j W-35 1880330 2 year test required by A10 3C.002. Sets anniversary date. Thanks, Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.re0a(rDalaska.0ow AOGCC.Inspectors(c0alaska.00v phoebe. brooks(Malaska.00v OPERATOR: BP Exploration (Alaska). Inc FIELD / UNIT / PAD: Prudhoe Bav / PBU / W Pad DATE: 04/10/20 OPERATOR REP: Ryan Holt AOGCC REP: chds. wallaceo ala s ka.0ov � 5 (L /�►� Well W-35 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. S = Slurry PTD 1880330 Type Inj G Tubing 2349 2359 - 2365 _ 2367- Form 10-426 (Revised 01/2017) Type Test P Packer TVD 8340 BBI -Pump 8.1 IA 346 3091 3062. 3056 - Interval V Test psi 2085 BBL Return 8.7 - OA 22 22 22 22 Result P Notes: 2 year test per AIO 3C.002. This test establishes anniversary dale. Declined to witness by AOGCC Jeff Jones. ✓ Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA I Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BEL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well j Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT PBU W-35 04-10-20 Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, April 28, 2020 7:19 AM To: AK, GWO SUPT Well Integrity; Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek; Stechauner, Bernhard; Glasheen, Brian P; Huber, Kenneth J; Peru, Cale Cc: Regg, James B (CED); AK, GWO DHD Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C Subject: OPERABLE: Injector W-35 (PTD #1880330) Administrative Approval granted for continued WAG injection Attachments: AIO 3C.002 04-27-20.pdf All, Injector W-35 (PTD # 1880330) has slow IA repressurization while on MI injection. It passed an MIT -IA to 3056 psi on 04/10/20, demonstrating competent well barriers. On 04/27/20 the AOGCC granted Administrative Approval to continue water alternating gas (WAG) injection, subject to conditions specified in AIO 3C.002. The well is now classified as OPERABLE. AIO 3C.002 is attached. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com> Sent: Wednesday, April 8, 2020 4:10 PM To: 'ch ris.waIlace@alaska.gov' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2 Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWell Pad LV@ bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek <Derek.Nottingham @bp.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com> Cc: 'Begg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Injector W-35 (PTD #1880330) Slow TxIA Communication while on MI All, Injector W-35 (PTD # 1880330) is suspected to have slow TxIA communication while on MI injection. On 04/07/20 the IA was bled from 850 psi to 200 psi with gas / liquid returns. The IAP increased 140 psi overnight. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. Fullbore: AOGCC MIT -IA to 3100 psi 2. Well Integrity: Further monitoring / corrective action as required. Consider AA application for continued gas injection. Please respond if in conflict. Ryan Holt Well Integrity BP Global Wells Organization -Alaska Office: 907-659-5102 WAM11: W-315 2.500 2.000 1.500 1.000 Soo 01.='0P'.Ci <'20 l '2 . 2 0 02 'D 1., 02,'1'9_-2,0 O?. 7 Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, April 8, 2020 4:10 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek; Stechauner, Bernhard; Glasheen, Brian P Cc: Regg, James B (CED); AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Injector W-35 (PTD #1880330) Slow TxIA Communication while on MI All, Injector W-35 (PTD # 1880330) is suspected to have slow TxIA communication while on MI injection. On 04/07/20 the IA was bled from 850 psi to 200 psi with gas / liquid returns. The IAP increased 140 psi overnight. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. Fullbore: AOGCC MIT -IA to 3100 psi 2. Well Integrity: Further monitoring / corrective action as required. Consider AA application for continued gas injection. Please respond if in conflict. Ryan Holt Well Integrity BP Global Wells Organization - Alaska Office: 907-659-5102 4.000 3.500 3, 00o 2.500 2.000 1.500 1.000 500 01 i Opl'20 02.19'20 1 Wcil: W-35 0--k,'0-A-,'20 02.1 '20 0_'.;'01;120 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, November 26, 2019 1:56 PM To: AK, GWO Well Integrity Engineer; AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD W; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Peru, Cale; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector W-35 (PTD #1880330) TxIA communication on MI mitigated with tubing patch All, Injector W-35 (PTD #1880330) was made under evaluation on 10/30/2019 in order to monitor for TAA communication during the first MI injection cycle post patch set. The well was WAG'd to MI on 10/31/2019 and has shown a stable IA pressure during the 28 day UE period. The stable annuli pressure indicates the TxIA has been mitigated. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 4,000 3.500 'x.000 2.500 2,000 1.5,20 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, October 30, 2019 7:42 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD W, Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Peru, Cale; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras 1; Regg, James B (CED) Subject: Injector W-35 (PTD #1880330) Monitor for inner annulus pressurization on MI injection post patch set Ma Injector W-35 (PTD #1880330) has known TxIA communication to MI that has historically been mitigated with a tubing patch. In 2015 the tubing patch was pulled to facilitate down hole well work. The patch was reset in 2016 and the well has been on water injection since. The well is now ready to be swapped to MI and is hereby reclassified as Under Evaluation to monitor for TxIA communication. Plan Forward: 1. Operations —Put well on MI injection 2. DHD—Monitor]A pressure 3. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO <AKDCWe Il l ntegrityCoordi nator@ bp.com> Sent: Sunday, September 25, 2016 9:0 To: AK, GWO SUPT Well Integrity <AKDCWelllntegrity inator@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Field O&M TL <AKOP eIdOMTIl@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WelipadLead@bp.com>; AK, OPS Prod Controllers <AKOPSPro rollers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West We Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOp @bp.com>: AK. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1ILII 31 073 DATE: Wednesday,January 03,2018 P.I. 7 � PSupervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. W-35 FROM: Chuck Scheve PRUDHOE BAY UNIT W-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-35 API Well Number 50-029-21799-00-00 Inspector Name: Chuck Scheve Permit Number: 188-033-0 Inspection Date: 12/7/2017 Insp Num: mitCS171208071036 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-35 Type Inj W TVD 8339 - Tubing 1190 1182 - 1175 - 1179 - PTD 1880330 Type Test SPT Test psi 2085 IA 127 2297 • 2271 - 2261 - BBL Pumped: 6.5 - BBL Returned: 4,5 - OA 8 11 - 12 • 11 - Interval 4YRTST P/F P Notes: Wednesday,January 03,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, September 25, 2016 9:08 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD W; Peru, Cale; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'jim.regg@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: OPERABLE:Injector W-35 (PTD #1880330) No Signs of Anomalous Inner Annular Pressure Post-Patch Attachments: Injector W-35 (PTD#1880330) TIO and Injection Plots.docx All, VOWED JAN 1 '1 Injector W-35 (PTD#1880330) was classified as Not Operable on 07/28/2015, after a tubing patch set across the SSSV nipple was pulled from the well. The patch repaired slow IA repressurization that had previously been observed when the well was on MI injection. A passing non-witnessed MIT-IA to 2500 psi was performed on 07/31/2015, after the patch was pulled. A new patch was set on 06/03/16. In lieu of performing an MIT-IA,the well was put on water injection as Under Evaluation on 09/03/2016 to verify the new patch had repaired slow IA repressurization. This well is now reclassified as Operable, however another Under Evaluation period will be required when the well is swapped back to MI. Please find injector plot data attached. The well is reclassified as Operable. Please contact Well Integrity Superintendent prior to swapping to MI injection. Please contact us with any questions or concerns. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 907.659.5102 C: 907.943.0296 H: x2376 From: AK, GWO-SUPT_Well Integrity Sent: Friday, September02;-2016 7:38 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field-O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt En�K, RES GPB East Wells Opt Engr; AK, OPS WELL PAD W; Peru, Cale; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'jim.regg@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; 1 • • Injector W-35(PTD# 1880330) TIO Plot September 25th, 2016 wet w(100 000 The -M- 04 04 DX- 0625'16 0iM 16 C-4916 0:616 v".7316 3'3c!6 WOE 16 61316 666666 3ST'1€ IgG3-6 C.4`C16 f6-1, 0919'16 Injection Plot September 25th,2016 Well 6I-35 2,400• -5.000 2210• -4 50 2 COO -4000 1.600^ 1 600 -3.500 • 3000 I —WHIP 1.400^ —A4 -PW 1.200 -1.500 1000^ q -GI -2000$ Other 800 -1.500 600• -1 000 400 2N -500 0625116 07102,16 07,13'16 07116,16 0712016 07.12016 08.+06'16 CR'„' '..1 X362716 0910316 03110116 0917616 092'416 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, September 02, 2016 7:38 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD W; Peru, Cale; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; jim.regg@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J Subject: UNDER EVALUATION:Injector W-35 (PTD#1880330) Patch Re-Set All, Injector W-35 (PTD#1880330)was classified as Not Operable on 07/28/2015,after a tubing patch set across the SSSV nipple was pulled from the well.The patch repaired slow IA repressurization that had previously been observed when the well was on MI injection.A passing non-witnessed MIT-IA to 2500 psi was performed on 07/31/2015,after the patch was pulled.A new patch was set on 06/03/16. The AOGCC has granted permission to bring the well online Under Evaluation, on water injection,to verify that the new patch has repaired the slow IA repressurization, in lieu of performing an MIT-IA.Another Under Evaluation period will be required when the well is swapped back to MI. The well is reclassified as Under Evaluation. Plan Forward: 1. Operations: Bring well online Under Evaluation UNWED JAN 2 7 2C17 2. DHD: Monitor for IA Repressurization Please be aware of the fluid-packed IA when bringing the well online. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D: - Integrity Coordinator Sent: Tuesday, July 28, :32 PM To: AK, OPS GC2 OSM; AK, OPS d O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slick i -, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, STATE OF ALASKA • eLASKA OIL AND GAS CONSERVATION COMMISal REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well m Re-enter Susp Well 0 Other:Set Patch m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 188-033 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service Ed 6. API Number: 50-029-21799-00-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU W-35 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10620 feet Plugs measured feet true vertical 9216 feet Junk measured See Attachment feet J U L 14 2016 Effective Depth: measured 10577 feet Packer measured 9497 feet ,�y sip true vertical 9182 feet Packer true vertical 8339 feet e.�4 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 41 -121 41-121 Surface 2624 13-3/8"68#L-80 40-2664 40-2664 5020 2260 Intermediate 9863 9-5/8"47#L-80 39-9901 39-8643 6870 4760 Production Liner 967 7"26#L-80 9653-10620 8454-9216 7240 5410 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36-9622 36-8431 Packers and SSSV(type,measured and 4-1/2"TIW Packer 9497 8339 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 7 n SCANNED JA 2 2r.,17 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3705 640 1023 Subsequent to operation: Shut-In 200 2040 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 13 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-253 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature iV/mac. Phone +1 907 564 4424 Date 7/11/16 Form 10-404 Revised 5/_20_15 s V7-L � // Art,9/1//L Ae / /D RBDMS W jU L 1 8 2016 Submit Original Only • • Junk Attachment PBU W-35 SW Name MD Date Comments W-35 9575 08/08/2015 Milled WRP W-35 10303 11/17/1996 Packer Rubber Element W-35 10355 12/13/2006 4-1/2"TEL Finger • co) co m � N is- NI- CO � O ON- ti N O O N- N OO CO 1s- OD Cn Cn a) v- CO co cocy) co co co I- 0 CO OD 00 O) O) co O N Cn CO p O) O) O) O) O) 0 0 0 0 0 0 p OD CO CO 00 OD O) a) CD CD O) 0. 0 I- a) N- Tr CONrcoa) N. N O a) N- N OD CO CO N N N- CL cn O) C4 c N- co CO N p m CO CO CO OD O) a) oO MCD W 0 a) a) O) a) a) a) 00000 > 0 tlD Oo 00 C)D aD oD O) a) O) a) a) 0 cc w o Z Li' 55Y °o U O O O w Y Y g CO N CO CO CO N CD in co D N- U U W W • y- C`7 co d' Cn CO is- OO N 07 J J J Q Q w N w }f Cl co co co co Cr) CO C) CO co < < < W O_ d Z 00 0 0 0 0 0 0 0 0 0 0 0 0 J J J D D d ¢ ¢ Q = o o a w a 2 U U 0 W = = = < < r Z Z t W w a I- I- Q Q OLt! 2 2 2 0 co v) co co co CO CI as � SFLN CO N OD CO CO N Cn LC) O O p M ) CO CO N- O Cr) O M N co co co co M cO co 00 0 0 0 0 0 0 0 0 0 0 0 0 coag 0 2 a 2 O Cl) Cn co co co d CL U 0• N LL LL N LL LL LL LC_ LL N N a. 0 t Cif a 0 CnInV) CnfnCnCnCDCnrnrn o 0) rn 0) 00) 0) 0) 0) CT) c ° 0) 0) 0) w 0) 0) CT) rn a) z u ¢ w m CO CO CO CO Co Co cc) co cc) CD 0 w w J p w of CO CO COCOCnCotococo � � z O m o w J J < 0 w w ¢ ¢ a cool u_ acc E co z CD Cn Cn Cn to to Lr) in CD Cn CD N Cr) Cr) CO Cr) CO CO CO CO CO CO CO LL0_ fn O LL N Q: LI- 3: L � � � � � � � � � � � < < m CO � � c) C,) m . • 0 2 Lu 2 q o - w 2 @ o 0 L Lu co 2 •/ O k o 2 0 O W o I 0CL La co 0 - k (1). 0 ri $ _ m ® £ 4 a _ 0 ¥ <R % w « « = q < Lit 2 _ 03 L 0 0_ § _1 o W U) / 0_ I— L � Y a" o ¥ 1 q 0 1- w CL = / co cts / / E � oIII� � < / k § \ 0 I0. ƒ -I 6Ga- z ° � (/) >,I- 0 _ � � k k � 2 : 0 / _ k - � � f - — , / @f b kq@ LI % � eo % > = m . 4- D ! w o : c 0 7 a e 0 m0 2S - < 22 \ o < b E < ce = o o di a 2 0 u0I < _ ¥ — I a)re 2 Co q E / = 2 1 1 m 'co_ k / k ƒ q ƒ / 9 < a) c > a E Z w@ < R 2 ! 0 o a D = o O c e 7 L 6 n a) - k 7cpcv -i < 2W0 / -3W � kZi \ A L _ z y # m / / S � � m0 .. / � 2ke 0 k m / � 2 ƒ & ,-�2b0 \ nE % _ \ � = Io2I % / a - > 22 �� 2 -1 u « U 2c[ 00 < w ® oz _w73 _ ik = k % ; R m < 0 L 5 ! w � = L m _ O LU < 0 o CO / a- a Ir0 I- CN 5 Cr) Cu COCr) @ CO a 0 « TREE= 4-1/16"aW • VVELL}EAD WCEVOY SADY NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C W"3 5 WHENON MI.WELL REQUIRES A SSSV WHEN ON ML KB.BEV= 90.88' BF.ELEV= 5433' 1(C7(31-LO iz KOp= 3200' 45 KB BKR FLO-GAURD PATCH w/2-7/8" Max Angle= 44'Q 8800' 2.02.01 X N6P,PKR D=2.45"(06/03/16) Datum M)= 10218' Datum TV D= 8800'SS H 2-7/8"X NP N PA TCH TA tLP ID=2.313" 4993- *2-7/8"MULESHOE,D=2.43" 1983' -14-112"OTIS HXO SSSV NP,D=3.813" 13-3/8"CSG,68#,L-80,D=12.415" H 2662' , GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 8 2924 2833 5 OTIS DMY RA 0 08/25/02 7 5715 5248 37 OTIS DMY RA 0 08/25/02 6 6691 6045 35 OTIS DMY RA 0 Minimum ID =2.313" @ 1981' 5 7233 6494 34 OTIS DMY RA 0 2-718" HES X NIP IN PATCH 4 7696 6877 34 OTIS DMY RA 0 3 8357 7409 40 OTIS DMY RA 0 2 9179 8014 43 OTIS DMY RA 0 1 9327 8123 43 OTIS DM' RA 0 II 1 943T —_-4:1/2-this SLD SLV,D=? 1-9498' —4-1/T TBG SEAL ASSY 9498' —9-518"x 4-1/7 TIW HBBP-R PKR,D=-4:0"1 TUBNG PUNCH(08/15/08) —� 9556'-9561' 9558' 4-1/2"OTIS X NP,D=3.813" - 9575'CTM WRP Ml_LED&PUSH@(08/08/15) 4-1/7 TBG-PC,12.6#,L-80, H 9623' 9591' —4-1/7 OTIS XN NP,D=3/25" .0152 bpf,0=3.958" \ 9623' H4-1/2"TBG TAI.,D=3.958" TOP OF 7"LNR H 9653' r 9628' H BMD TT LOGGED 08/07/94 9 518"CSG,47#,L-80,D=8.681" --j 9901' 1091r -MARKER JONT 1 PERFORATION SUMMARY REF LOG:BRCS ON 05/01/88 ? —i FISH-4-1/2'TEL FNGER(12/13/06) ANGLE AT TOP PERF:34°©10513' Note:Refer to Abduction DB for historical perf data 10303' —I FISH-PKR RUBBER SIZE SPF INTERVAL Opn/Sqz DATE , 5" 5 10312-10348 S 04/29/95 3-3/8" 6 10316-10338 O 06/08/95 3-3/8" 6 10338-10346 S 0429/95 1113-3/8" 6 10346-10352 0 05/05/95 3-3/8" 6 10364-10380 0 05/05/95 1 3-3/8" 4 10400-10420 S 0429195 3-3/8" 4 10430-10437 S 04/29/95 [ PBTD H 10577' .....A'A�A�.( * 7"LW,26#,L-80,0.0383 bpf,D=6.276' —i 10620' ! ******1 DATE REV BY OOMfu6JT5 DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/05/88 GRV ORIGINAL COMPLETION 08/17/08 RRIYSV TUBING PUNCH(08/15/08) WELL W-35 09/08/01 RN ITP CORRECTIONS 10/27/15 RCT/11H PATCH PULLED(07/27/15) PERMIT No:'1880330 05/31/09 SWC/TLH FISH(04/06/09) 10/27/15 SW/TLH FISWFLUG MLLE)(08/08/15) AR No: 50-029-21799-00 09/30/09 KJB/SV SET PATCH(07/16/09) 06/09/16 DS/JM) SET PATCH w/X NP&MILESHOE SEC 21,T11 N,R12E 1251'SNL&1451'WEL 02/16/11 14/f3/JM) ADDED SSSV SAFETY NOTE 01/20/12 TMYJM)ADDED Ii2S SAFETY NOTE BP Exploration(Alaska) • • • Or r4, THE STATE Alaska Oil and Gas of • Conservation Commission Sf�= 333 West Seventh Avenue +'�"�''& Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g UMain: 907.279.1433 a.w8�' Fax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton Pad Engineer Sale BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-35 Permit to Drill Number: 188-033 Sundry Number: 316-253 Dear Ms. Burton: 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, Cathy P oerster Chair DATED this day of May, 2016. RBDMS .--- MAY 1 0 2016 AlEcEIVEV STATE OF ALASKA MAY 0 2 2016 •ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 5/�j k//�4, 20 AAC 25.280 ¢7ts iG 4.�F, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well p - Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ElPerforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Set Patch TLr/ii k.2I I 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 188-033 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic ❑ Service p. 6. API Number 50-029-21799-00-00 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No II PBU W-35 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028262 - PRUDHOE BAY,PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10620 - 9216 - 10577 9182 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 41 -121 42-122 Surface 2623 13-3/8"68#L-80 41 -2664 41 -2664 5020 2260 Intermediate 9863 9-5/8"47#L-80 39-9901 39-8643 6870 4760 Production • Liner 967 7"26#L-80 9653-10620 8454-9216 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 37-9623 Packers and SSSV Type: 4-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 9498, 8339.77 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program p BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ❑ Service ) 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG p - GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature (-1 ('/V7,---- Phone +1 907 564 5554 Date o yi 18/Zb 1 b �L COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: -3kLe_ - 253 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test .13 Location Clearance ❑ Other: I jZ�f F Ca n�rf,�v1 i ccc;+,'UY, y3 ,hdi 1-cd . �lT� ltl' GGvC Nfx �' Z'�"! ZU/� �r � / Post Initial Injection MIT Req'd? Yes L No 1E' Spacing Exception Required? Yes❑ No 0 Subsequent Form Required: /G i1 0 447/0 T�(/ APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 5,6 _ /6 ORIGINAL RBDMS MAY 1 0 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate iv 3/6/Loft _ - 5 3 'c_:; 1 • • • Junk Attachment PBU W-35 SW Name MD Date Comments W-35 9575 08/08/2015 Milled WRP W-35 10303 11/17/1996 Packer Rubber Element W-35 10355 12/13/2006 4-1/2" TEL Finger • • m N CO _ CO 6) ti N- N t O 0 I- N CO CO r CO 0 0 O 0 M 4 00 (D O M I� C) CO CO CO 0) 0) O N CC) CO O O) O) O) D) 0) co 0 0 0 0 0 CO CO CO CO CO O) CA 0) C)) 0) I- O I- CA - N N- CD cr CO 0) I- t I- OCA I- N CO 0 CD N CV 5- 0 0-) c c)CO CO 00 CO00) 0 0 0 v M 0 0 0) 0) C)) CA 0) CA O O O O O CO CO CO CO CO CO CA 0) CD a) C)) 0 w � w 0 0 U Z W W 0 W 0 J 0 LLI °' ggY 00 o CIS CO N 00 CD CO N 0 0 O O I� O O J U U Wix w fl N- Cr) CO V V 0 CO I- CO N CO J -i J d d U Z CO CO Cr) CO CO Cr) CO CO CO a a a W D 0 0 0 0 0 0 0 0 0 0 0 _U _U U J W W J CD . . . . . . Z Z Z O J J J D J m a a a = 0 0 d 2 w w w w & LI- < 01_ 0 z 0 z H a J a 2 2 2 O cn cn cn cn cn Q• , 5 • t N 0 N CO CO CO t 0 CO O O MM p Cr) CO) "ct CO CD N- O CO E.O W 0 C) 0 0 0 0 0 0 0 0 0 0 - Cna) L m 2 2 O cn cn cn cn cn d a 0 0 U O• N LL IL N u_ LL u_ u_ LL N N o 0- 0- C� 0_ 0_ a a a 0 0 C: 0 t N 0 m F- CI 0 0 0 CO 0 0 0 LO 0 LU 0 0 CA (A 0) O 0) 0) 0) 0) c CA a) O) a) 6) O O) C) a) ci) Z WLLI 0 . . . . . . ¢ LL TO 0 CO OO -Co l() 0 0 0 0 U LU ID CO CO CO CO L[) L j U) 0 N N z a J Ow W LL W 2 V < 0 J I- J J -I 0 CC 0- 0 C0 0 D W J JaO a a 0_ N LL LL Li Ud LU N E ca LO LO LO LO 10 L.0 LO LO LO LOz N CO CO CO Cr) CO CO CO CO CO CO Cr) i 1 1 1 1 1 1 1 1 1 1 LL O_ U) 0 LL N !Y LL 0 m0OCDwCCQaLn- • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: W-35 Well Type: WAG Injection Well API Number: 50-029-21799-00 Well Activity Conventional 4 Classification: Activity Description: Set Patch Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Required? No Primary Secondary Engineer: Kaity Burton Contact numbers: (907) 564-5554 (907)360-6002 Well Intervention Engineer: WIC Contact numbers: No Data No Data Lead Engineer: Dan Robertson Contact numbers: (907)564-5546 (907)529-5818 Date Created: April 20, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 4/19/2016 0 0 532 Current Status: Not Operable Shut In Inclination >70°at Depth (ft) NA Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppmDepth) 44° 8,800' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) NA Reservoir pressure(date, 10/10/2010 3,602psi Minimum ID and Depth psig) P 3.750" 9,591' MD Reservoir Temp,F 190° F Shut-in Wellhead Pressure 500 psi Known mech. integrity Patch over SSSV @ 1937' pulled 07/27/2015,WRP stuck in tubing tail problems(specifics) Last downhole operation (date, 8/9/2015 CT attempt to fish stuck WRP operation) Most recent TD tag (date,depth, toolstring OD) 8/9/2015 9,576' MD Tag WRP, attempt to remove to no avail Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. • • Comments,well history, It is a pattern injector in the main fault block below the gas cap and injects into the 31-41 P. It has had background information, two bulbs of MI and is currently on produced water. In 2008 the well needed a tree change and in etc: process of securing the well for the tree change it would not pass an MIT-T. It did pass an MIT-IA multiple times. The tree change out was completed and when slickline tried to retrieve the WRP from 9543' MD it would not come loose. Fishing attempts were made with Slickline and braided line until the fishing neck came off the WRP and all fishing ended. At this point in time,the tubing tail was punched so the well could be put back on injection and it was lined back up to MI.The well passed multiple MITIAs but experienced slow BUR in the IA when on injection so temporarily had an AA for PWI only. In 2009 an acoustic LDL was run which saw,a small signature over the SSSV caa-g69ish-w4.-- evcr - the SSSV 07/16/2009. Another MIT-IA passed 07/31/09 so the well was placed back on injection. The well has been online injecting through the tubing tail punch since the plug was stuck in 2009. In 2015 in attempt to access to the perfs, understand conformance,and gain ability to addperf this injector in the future one last fishing attempt was attempted. It was unsuccessful although Weatherford felt they had a tool we could modify to get it out. Unfortunately,this added to the already high costs of fishing attempts and it was felt that the current value in getting the plug out would not pay for further fishing, until a change in perfs was needed. In this fishing attempt,the patch was pulled and not reset(due to desire to possibly trial an Xray tool for better understanding of fish which never happened.) The well then went Non-operable until the patch is reset or an AA is obtained. This procedure aims to reset the patch to restore operability to the injector. WIC(Whitney Pettus)confirmed with the state 04/05/2016 they would allow the patch to be set with no pressure testing and Under Eval th well. The well will also need to be placed under Eval when swap to MI to confirm no communication.Well passes MITIA to 2500psi and 4000psi without the patch in place therefor does not need to be retested unless it shows signs of communication. Well Intervention Details Suspected Well Problem: IA repressurization when on MI Specific Intervention or Well Objectives: 1 Set new patch over leaking SSSV 2 3 Key risks,critical issues: Mitigation plan: 1 Failing MIT-IA post patch removal MIT-IA passed 07/31/2015 2 3 Summary Step# Service Line Activity 1 F Warm well pre-patch set by pumping 290bbIs of 180 degree 1% KCL down the tubing followed by 32 bbls 180 degree diesel. Set Baker 4-1/2"one trip KB patch with 90-80-90 element arrangement over the SSSV at 1940'-1975' 2 E MD. Please use the Halliburton eline unit to take advantage of larger crane. Patch specs: 35 foot E-E Baker KB Single Trip Straddle. ID of 2.44". Patch rated 3500 psi.Tailpipe with 2.313" ID X nipple and WLEG will be hung off bottom of patch. Tie-in to collars on TecWel WLW log run 04/07/09. 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 • • Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Well can be P01 Under Eval. Has loaded IA and will need to be watched and bled. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Pelf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • II • 0) Line Speed SN nn} 100 0 WLD-A 500000 4700 Co_ 400 0 WL13•13 500000 20 ..-.._... Taroppralure(dogF? 0 0 WLD.0 _-...._... 6C0000 0 Temperature(dagF) 20 Di?a cmparahrQ d F 1 t 9 ` '.1 —4- ----J.. ' :if- ). ..... r .._..m.__ _--_—__,. 4 --:, r I i I_ 1 r . �. ... t 2000 -... _._ . 1,1t.,r-r hal tarop,r at u-,--.... 1 J , r I " 4 _, 7. _ • • tip Baker Thru-Tubing ��� 045 WL "KB"Single Trip Straddle OPTION ##1 - Single Set Baker Oilluols Well: W-35 Date XXXX Co. Man XXX 1�' OD ID Length 9CR•45"KS"Upper Straddle Packer -All ACC 4"GS Fishing Neck Up 3.70" 2.45'" 5.51' 3 112"STL Pin Down 30K Shear Release �: 14819634511 (8)'."-20 Shear Pins 011.3204"s(3"Shear) u IT 1 3 1 111 a } AfitE Alt 13 CR-3 1/2"STL Full Joint 3.50" 2.972" 30 24' 3 III it Air 9CR-45"KB"Lower Straddle Packer all • 3`,"Box Up 3.70" 2.45" 5.40' all WLEG Down ear Shear Release 1111 H819834511 (5)'."-20 0 T075ers(1 Shear) (2)5116"-18 0 4,7561e's(2^"Shear) NOTE:Setting tool WLAK Dressed with II (1).410"Dia Sear Stud 018-21K1(4"'Shear) 2.31""X"Nipple 3.50" 2.310" -2.00' PPWLEG 3.50" 2 972" -0.50' TREE= 4-1/16°CM • 1t4ELL)EAD= MCEVOY S Y NOTES: H2S READINGS AVERAGE 125 ppm ACTllATOR= BAKERC W-35 WHEN ON MI.WELL REQUIRES A SSSV WHEN ON ' KB.ELEV= 90.88' ML BF.ELEV= 54.33' KOP= 3200' Max Angle= 44"G@ 8800' 1983' H4-1/2"OTIS HXO SSSV NP,D=3.813" [tum MD= 10218' Q [tum TVD= 8800'SS !'1. t( GAS LFT MANDRELS y0.1 0 'S ST MD TVD DEV TYPE VLV LATCH FORT DATE e8 2924 2833 5 OTIS DMI' RA 0 08(25/02 13-3/8"CSG,68#,—L---80,D=12.415" --L 2662' 7 5715 5248 37 OTIS DMY RA 0 08/25/02 ----- 6 6691 6045 35 OTIS DMY RA 0 5 7233 6494 34 OTIS DMY RA 0 4 7696 6877 34 OTIS OW RA 0 3 8357 7409 40 OTIS DMY RA 0 _._-------.._ 2 9179 8014 43 OTIS DMY RA 0 Minimum ID = 3.725" @ 9591 1 9327 8123 43 OTE DMY RA 0 OTIS XN NIPPLE II 9437' _14-1/2"OTIS SLD SLV,D=1 --I 9498' H4-1/2"TBG SEAL ASSY 9498' H9-5/8"x 4-1/2"TM/H 8BP-R PKR,D=4.0" TUBNG PUNCH(08/15/08) —I 9556'-9561' ❑ ' 9558' H4-1/2"OTIS X NP,D=3.813' 9575'CTM —IVVRP MLL®&PUSHED(08/08/15) 4-1/2'TBG-PC,12.6#,L-80, — 9623' � ' 9591' —{4 1/2"OTIS XN tom,n=3.725" .0152 bpf,D=3.958" / ---I 9623' —14-1/r TBG TA L,D=3.958" 9628' --I arvo TT LOGGED 08/07/94 TOP OF 7"LNR —I 9653' 9-5/8"CSG,47#,L-80,D=8.681" --f 9901' jJ L 1001T —I.MARKER Jaw PERFORATION SUMMARY 11111 ? --IFISH-4-1!2"TU RINGER(12/13/06) REF LOG:BHCS ON 05/01/88 ANGLE AT TOP PERF:34°©10513' 1114 {-10303' --I FISH-PKR RUBBER Note:Refer to Ftoduction DB for historical perf data SIZE SPF NITHRVAL Opn/Sqz DATE I 5" 5 10312- 10348 S 04/29/95 3-3/8' 6 10316-10338 O 06/08/95 3-3/8" 6 10338-10346 S 04/29/95 3-3/8" 6 10346-10352 O 05/05/95 ' 3-3/8" 6 10364-10380 0 05/05/95 1 3-3/8" 4 10400-10420 S 04/29/95 3-3/8" 4 10430-10437 S 04/29/95 L PBTD]—I 10577' } 11111111111111111 ►!�•!�!�!�!�!�!�! 7"LW,26#,L-80,0.0383 bpf,D=6276" --I 10620' DATE REV BY COMIue'ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05105/88 GRI/ ORIGINAL COMPLETION 08/17/08 RRD/SV TUBNG PUNCH(08/15/08) VVE-L W-35 09/08/01 RNYTP CORRECTIONS 10/27/15 RCT/TLH PATCH PULLED(07/27/15) PERMIT ND:9880330 05/31/09 SVVC/TLH FISH(04/06/09) 10/27/15, SW/TLH FISHIFLUG MILLED(08/08/15) API No: 50-029-21799-00 09/30/09 KJB/SV SET PATCH(07/16/09) SEC 21,T11 N,R12E, 1251'SNL&1451'VVEL 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE 01/20/12 TMWJMD ADDED 112S SAFETY NOTE BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, April 06, 2016 12:27 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Sternicki, Oliver R Subject: Permission to Monitor Injector W-35 (PTD #1880330) Under Evaluation Instead of MIT- IA Post Patch Set Attachments: W-35 AA Approval 3.027 05-13-09.pdf; W-35 AA Approval 3.027 Cancellation 01-03-11.pdf Chris, Per our conversation yesterday, Injector W-35 (PTD#1880330) is a WAG injector that previous operated under Administrative Approval Area Injection Order(AIO) 3.027 for continued water injection only.AA 3.027 was issued on May 13, 2009 and then cancelled January 03, 2011 after a patch was set to repair known tubing by inner annulus communication (TxIA comm)while on miscible injectant (MI). A passing MIT-IA was obtained prior to as well as after patch set in July of 2009. The patch was subsequently pulled in July of 2015 in order to perform wellwork.The injector remains lined up for produced water injection and the patch will be reset after wellwork is complete. Produced water injection will not commence until after the patch is reset. BP requests permission to reset the patch and then place the well Under Evaluation on produced water injection for up to a 28 day monitor period in lieu of performing another MIT-IA. This well has a history of passing MIT-lAs with and without the patch set downhole. The last passing AOGCC MIT-IA was performed on December 27, 2013 with the patch set downhole. The patch was pulled on July 27, 2015 and a subsequently passing non-witnessed MIT-IA was obtained shortly thereafter on July 31, 2015. A secondary Under Evaluation will be performed once the well is placed back on miscible injection to ensure the patch repair was successful. A copy of the approved AA and AA cancellation have been included for reference. MIT data can be provided upon request. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED APR 2 12016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull Patch I I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 188-033 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service I1 6. API Number: 50-029-21799-00-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU W-35 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10620 feet Plugs measured feet true vertical 9216 feet Junk measured See Attachment feet JAN 2 5 2016 Effective Depth: measured 10577 feet Packer measured 9498 feet true vertical 9182 feet Packer true vertical 8340 feet 1 OGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 39-119 39-119 Surface 2625 13-3/8"68#L-80 39-2664 39-2664 5020 2260 Intermediate 9865 9-5/8"47#L-80 37-9901 37-8643 6870 4760 Production Liner 967 7"26#L-80 9653-10620 8454-9216 7240 5410 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 35-9623 35-8432 Packers and SSSV(type,measured and 4-1/2"TIW Packer 9498 8340 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3662 580 1037 Subsequent to operation: Shut-In 160 150 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service Elf Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG WI GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature C Phone +1 907 564 4424 Date 1/21/16 Form 10-404 Revised 5/201 v-!-L. zit g �� ?i RBDMS 0- JAN 2 5 2016 Submit Original Only • • Junk Attachment PBU W-35 SW Name MD Date Comments W-35 9575 08/08/2015 Milled WRP W-35 10303 11/17/1996 Packer Rubber Element W-35 10355 12/13/2006 4-1/2"TEL Finger • • C) N CC! m N CO CO O) N- N- N O O) N N 00 CO N- CO Ln Lo d CO co Co 0) a) O '— N Co CO Cl 0) O) C)) O) 0) co 0 0 0 0 0 CO 00 CO CO CO 0) 01 0) 0) C7) 0. 0 o) — N N- v CO v CO 0) N L OO) N N 00 CO CD NCV N- o. 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O Ca ca C_ c' c 0 O � >0 CU a) a) O vi (`2 O NF- 0 � � � ° s r � u_15 0- -.9E70 0 � 0 a) E v d M - - N u ij c N j -TRE = 4-1/16'OW • W�LH \D= MCEVOY I� silkyNOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C IN—3 5 EN ON MI.WELL REQUIRES A SSSV WHEN ON KB.ELEV= 90.88' BF.ELEV= 5433' KOP= 3200' Max Angle= 44"Qa 8800' 1983' —14-1/2"OTIS HXO SSSV tom',D=3.813" I Datum MD= 10218' 0 Datum1VD= 8800'SS GAS LST MANDRELS ST MID ND DEV TYPE VLV LATCH PORT DATE 8 2924 2833 5 OTIS DMY RA 0 08/25/02 13-3l8'CSG,68#,L-80,D=12.415"-1--1 2662'..._._. 7 5715 5248 37 OTIS DMY RA 0 08/25/02... 6 6691 6045 35 OTIS DMI RA 0 5 7233 6494 34 OTIS DMI RA 0 1-1 4 7696 6877 34 OTIS DMI RA 0 3 8357 7409 40 OTIS DMY RA 0 2 9179 8014 43 OTIS DMI RA 0 Minimum ID = 3.725" @ 9591 1 9327 8123 43 0115 DMY RA 0 OTIS XN NIPPLE II 9437' _14-1/2"OTIS SLD SLV,D=? 9498' —14-1/2"TBG SEAL ASSY 9498" H9-518"x 4-1/2"11W HBBP-R PKR,D=4.0" TUBING PUNCH(08/15/08) --j 9556'-9561' 9568" —4-1/2"O11S X NP,D=3.813" • 9575'CTM --I WRP MLLES&PUSHED(08/08/15) 4-1/2"TBG-PC,12.6#,L-80, H 9623' 9691' --I4-1/2"OTIS XN NP,D=3.725" .0152 bpf,D=3.958" \ 9623' --{4-1/2"TBG TAL,D=3.958" 9628' --I ELMD TT LOGGED 08/07/94 TOP OF 7"LNR --{ 9653' 9-5/8'CSG,47#,L-80,D=8.681" —I 9901' I--A 10017' --{MARKER JOINT PERFORATIONSUMMARY vot( ? —{FISH-4-1/2"TEL FINGER(12/I3/06) REF LOG:BHCS ON 05/01/88 ANGLE AT TOP PERF:34°(10513' 414 1 10303' 1-i FISH-PKR RUBBER 1 Nate:Refer to Production DB for historical perf data ' SIZE SPF NTBRVAL Opn/Sqz DATE 5" 5 10312-10348 S 04/29/95 3-3/8" 6 10316-10338 0 06/08/95 3.3/8" 6 10338 10346 S 04/29/95 3-3/8" 6 10346-10352 O 05/05/95 I 3-3/8" 6 10364-10380 0 05/05/95 I 3-3/8' 4 10400 10420 S 04/29/95 3-3/8" 4 10430-10437 S 04/29/95 PBTD H 10577' J 7"LNR,26#,L-80,0.0383 bpf,D=6.276" H 10620' ►11..11....+!11 DATE REV BY COMENTS DATE REV BY COMMITS PRUDHOE BAY UNIT 05/05/88 GRN ORIGINAL COMPLETION 08/17/08 RRDSV TUBNG PUNCH(08/15/08) WELL: W-35 09/08/01 RIWTP CORRECTIONS 10/27/15 RCT/7LH PATCH PULLED(07/27/15) FERMI'Pb: 1880330 05/31/09 SWC/11_H FISH(04/06/09) 10/27/15 SW/TLH FISWFtUG MLLES(08/08/15) API Pb: 50-029-21799-00 09/30/09 KJB/SV SET PATCH(07116/09) SEC 21,T11 N,R12E, 1251'SNL&1451'WE_ 02/16/11 M3/A13 ADDED SSSV SAFETY NOTE 01/20/12 TMMJMD ADD@ H2S SAFETY NOTEBP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, July 28, 2015 1:32 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov' Subject: NOT OPERABLE:Injector W-35 (PTD #1880330) Patch Pulled All, Injector W-35 (PTD#1880330)a patch was set over the SSSV from 1937'-1983' MD to mitigate inner annulus repressurization. The patch was pulled in prep for pulling a down hole plug. The well is reclassified as not operable until well barriers can be restored and confirmed. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate. Whitney Pettus SCATHE© JUL 2 8 2015 BP Alaska-Well Integrity Coordinator l� C;ioba \,'Vele V V Organizaiior Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, January 12, 2011 11:47 AM To: AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Ops Lead; AK, OPS GC2 Operators Cc: AK, D&C Well Integrity Coordinator; Kirchner, Carolyn J; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Subject: W-35 (PTD #1880330) Cancellation of AA for TxIA comm, Permitted for WAG injection All, WAG Injector W-35 (PTD #1880330) passed an AOGCC MITIA on 09/12/09 after a tubing patch was set to mitigate the TxIA communication. In addition, the IA pressure has remained stable since POI in late October 2010. The Administrative Approval for PWI only has been cancelled and the well has been returned to WAG status. Please have the AOGCC email and the laminated copy of the AA removed from the wellhouse. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 1 • • r 4 c P r I R r [ F ( . r L. \ k I \ h Ir- u V' SEAN PARNELL, GOVERNOR Li ii-k\ u ii, ,, , ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 3.027 JAN 18 2011 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 z1 , BP Exploration (Alaska) Inc. \ o P.O. Box 196612 Anchorage, AK 99519 -6612 I RE: Cancellation of Administrative Approval AIO 3.027 (Well PBU W -35) Dear Mr. Cismoski: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated December 16, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 3.027, which allows continued water injection in Prudhoe Bay Unit ( "PBU ") well W -35. This WAG injection well exhibited inner annulus repressurization while injecting MI. BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Not long after the Administrative Approval was issued, BPXA set a tubing patch that has, based on the required monthly pressure monitoring, repaired the well. The well successfully passed an MIT -IA on September 12, 2009. Consequently, Administrative Approval AIO 3.027 no longer applies to operation of this well. Instead, injection into PBU W -35 will be governed by provisions of the underlying AIO No. 3. DONE at Anchorage, Alaska and dated January 3, 2011. _ — . -- t The Alaska Oil and Gas/ o servation Commission •,' , 2 ;° -''ti 0 Of 1 l ;f or Daniel T. Seamount, Jr. g" Norman. Cathy ' . Foerster Commissioner, Chair Co , • sioner Commissioner • . L-fvpf, DEC 2 7 2010 hh��,, F x � . (664ifn its by Expi+m ion (Alaska) kw. Anthorepe 11 410, Attn: well Integrity Coordinator, PRB -20 Post Office Box 198612 Anchorage, Alaska 99819.6612 December 18, 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7' Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well W -35 (PTD #1880330) Application for Cancellation of Al0 Administrative Approval 3.027 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 3.027 dated May 13, 2009. The administrative approval was for continued water injection into. Weft W-35 with slow tubing by inner annulus communication. A tubing patch was sot July 16, 2009 to mitigate the tubing by inner annulus communication for future miscible gas injection. To verify the tubing patch mitigated the communication, the commission agreed to leave the well on MI for one WAG cycle to monitor the 110 plot prior to cancelling the current AA for water injection only. The T10 plot verifies that the tubing by inner annulus communication was mitigated by setting the tubing patch. An AOGCC witnessed MITIA passed to 4000 psi on September 12, 2009. Therefore, it is requested to cancel Administrative Approval number 3.027 for water injection only and return the well to WAG service. A plot of wellhead pressures has been kuluded for refisronco. If you require any addition& information, please contact me at 564 -4303 or Gerald Murphy / Torin Roschinger at 659 -5102. Sincerely, Dotes A. Cismoski, P.E. BPXA Wells Intervention Manager • • Attachments: TIO Plot Wellbore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger Carolyn Kirchner Harry Engel 0 0 • W -35 (PTD #1880330) TIO Plot WA W -i 4,000 .....n+'.rwownonn . . 3,000 2,000 • —~ 00A Il +000 11 rwonwe omen On 1,000 - _ I 066/19/10 07/03 /10 07/17 /10 07/31/10 08/14/10 08/28/10 09/11/10 09/25/10 10/09/10 10/23/10 11/06/10 11/20/10 12/04/10 W -35 Injection Plot wawa r + 3,000 4.01.110.1,10•11011.•••• •20.000 -79 2,800 18.000 2.600 - - 17,000 2,400 - -16,000 -1 5,000 2.200 - -14,000 l i ff 2,000 - / ( ��""��(( - 13,000 } 4 - 12,000 £ "' -"WIMP n. 1.800 .11.000 _ M SW 1,6�- 41, ! .10,000 — 1.400 • 1 - 9.000 - _ 01 1200 • - 8 M On - 7,000 1.000' 8000 800 - 5.000 600- 4600 4 3.000 . 2.000 200 I I 1,000 t r 06/19/10 07/03/10 07 /17/10 07/31/10 08 /14/10 08/28/10 06/11/1 - 09/25/10 10/09/10 1023/10 11/06/10 11/20/10 12/04/10 • • 0 TVS. 4- v16'CW ACRATORa MOM • VV-35 - 611619J3/ . SS KOP= . . ■ . QM 44 . s;w.:.a 1 m- OT$ 11314V . ,D_ ,.. I II. I OASL6rT *yews Dm VO■ moo _ r i.1h...l a7rr :7.•a∎ . sax sip O•2.31' P7i114) i 1 6115 3246 9 MS ON RA 0 : e 6611 0046 36 OTS OAP RA 0 �' 01(1.80, CO. � 7 ' 111LYAIN 6 1233 6444 31 016 Ott M 0 4 1668 6611 X 018 CAW RA 0 3 5361 7406 43 078 MY RA 0 2 511! 6014 48 015 OM RA 0 II Minium 1 6321 6123 • 078 Air RA 0 0*241 "�1!'f�!' I III r gu - ' S'r46 ?cT' , q r , , - -4 s. .1.1. 1 � } T - . - r.'. (' r • • NW= ■ • -,t a -11111111 W`r,TV!".Y MIN I I4-yr ism 5C.12E5. L20. Q NILLI.' 4-1m - 0 manor ox 0116' WOW. 33W 11111 a1 —.Wri r .I L I E -' - i { '1631j" .... - 1 1 WSW Ca0 41$S L -40, 54 =$..661' 11 IFILIAll Jar P!ltl01(ATOR *!464131 NV LOO blot ORammo MAO 4-wrisi (S( (12I4L08) I All SAT TOP PEW. 34 0 10413 Nola : ROWS 6∎333544 136 Sr WAS* ° 4466 IRE r l 0413 1 -1 339' 6 10316 -10334 C 0406416 3314' 6 1086 -1034$ 3 062!!6 331- 6 10316 -10342 C 080598 ' 3341 6 10334 -10340 C 066061/6 334r 4 10400 -10420 3 063395 I 339' 4 10450 -1043T S 042636 7 f.• i ifi 4y1/f � "f a v,.,,..,4a I 7' LIeR, XL L-601, MU SC 0 ,Yt. inL.ai] 5 N`- ,4L:1 WI Ls'1.1iewrit+--.., r:' Pm-ma MY lNf 64.44.44.111144.446 , . ...r+:4. r :,4 1 .r - , i>rrn Mir NoP1H0330 i .,�: U .i2ul C `'■.T:t'. `«'. lE.',c. /i11TI T 7•7. _ .1111111111111 AFAR A 80.0232196 -00 iT.: 7 l I , t. • . -. ; , IMMO ...; +J ".t.:f ,a.::. SIC 111 , 1 4141 S— ittG.A10.4 11-Q 4..41.1 -1s. 2... ii 1 '"t ; /, ,i " 1 v..1' ,4, - JIM. � �� • • Regg, James B (DOA) Page 1 of 2 From Regg, James B (DOA)�� Sent: Wednesday, November 24, 2010 2:51 PM To: AK, D &C Well Integrity Coordinator Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: PBU W -35 Torin - I have reviewed the TIO plot for PBU W -35 (PTD 18 330), as well as those in our files provided monthly by BP in compliance with administrative approval AIO 3.027 (admin approval restricts the well to water injection only). The well appears to exhibit good mechanical integrity and thus it may remain on MI injection PBU W -35 has been on intermittent MI injection since September 2009 following a tubing patch to repair the TxIA communication. The well passed a Commission witnessed MIT to MI injection pressures on 9/12/2010. MI injection was allowed with monthly TIO pressure plot monitoring reports sent to the Commission to evaluate the uncertain cause of some IA repress u rization as discussed in the May 7 email (below). Through several shutdown and restart cycles during the past year PBU W -35 continues to exhibit tubing integrity. Confusion regarding a "water- only" restriction (per AIO 3.027) posted in the PBU W -35 wellhouse can be addressed by BPXA requesting cancellation of AIO 3.027. As a general guidance, an admin approval should remain posted in the well house until such time as it is cancelled by the Commission; a copy of this email should be included with the posted copy of AIO 3.027 acknowledging the Commission's approval to allow MI injection To avoid confusion for similar circumstances that may arise in the furture, it is important to ensure written correspondence (email or letter) from the Commission is posted in a wellhouse with an injector admin approval addressing authorized deviations (e.g., well restricted to water but allowed to be on temporary gas injection for evaluation). Jim Regg AOGCC NIL 333 W.7th Avenue, Suite 100 1�l ',t Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ma i Ito: AKDCWeIII nteg rityCoord inator@bp.com] Sent: Wednesday, November 24, 2010 2:01 PM To: Regg, James B (DOA) Subject: RE: PBU W -35 Jim, I have attached the TIO plot you requested per our phone conversation earlier. Thank you, Torin From: NSU, ADW Well Integrity Engineer Sent: Thursday, May 07, 2009 2:59 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: RE: PBU W -35 11/24/2010 • • Page 2 of 2 Hi Jim, agree this is an interesting well. I've included an updated TIO plot since the well has been on water injection on 4/15/09 and a plot comparing temperature and pressures. I do not see a strong correlation between temperature and IA pressure. The AA request was written for PWI only given the IA repressurization but the preference would be to keep this well on WAG cycles. Given the uncertain cause of the "repressurization ", a good approach might be to leave this well on the Monthly Injection Report, allow the well to return to MI for another WAG cycle, and again monitor the TIO plot, injection rates, and temperatures. Once you have a chance to review these plots, feel free to give me a call to discuss. Thank you, Anna (Dube, T E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 II From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, May 05, 2009 4:40 PM To: NSU, ADW Well Integrity Engineer Subject: PBU W -35 Interesting well and maybe a unique circumstance. Hard to determine if IA is really being affected by "repressure" or if this is result of a thermal anomaly due to wild MI rate. I'm not totally convinced of need for Admin Approval at this time. We should discuss. Questions: 1) Do you have a temperature plot? 2) Has well been swapped to water; if so, can you update TIO pressures? 3) Intent to continue injecting MI in future? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 11/24/2010 PBU W -35 PTD 1880330 11/25/2010 TIO Pressures Plot Well: W -35 4,000 I 3,000 i 0 Tbg - -F IA 2A00 —A— OA OOA �— OOOA On 1,000 09125110 1W62110 10/09110 10116110 10/23110 10130110 11106!10 11/13/10 11120110 3 • I I • • O ALASKA SEAN PARNELL, GOVERNOR AL&SHt>• OIL AND GAS 333 W. 71h AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CORMICTED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 3.027 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU W -35 (PTD 1880330) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: The Commission has corrected the Administrative Approval to reflect adding Rule 4 to Adminis- trative Approval number for AIO 3 -027. Pursuant to Rule 9 of Area Injection Order (AIO) 3.000, the Alaska Oil and Gas Conservation Commission ( AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. BPXA notified the Commission of inner annulus (IA) repressurization affecting PBU W- 35 while injecting miscible injectant (MI). Diagnostic mechanical integrity testing confirms the well exhibits competent tubing and production casing. Attempts to locate the sourece of pressure communication using a leak detect log and a tubing caliper survey were unsuccessful. BPXA has elected to perform no corrective action at this time on PBU W -35. r h The Commission believes that the well's condition does not compromise overall ell integrity so as to threaten the environment or human safety, if the well's operatio is subject to the certain constraints. AOGCC's administrative approval to continue er injection only in PBU W -35 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall limit the well's IA pressure to 2000 psi. S A10 3.027 December 7, 2009 Page 2 of 2 4. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated injection pressure, 5. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is April 18, 2009. DONE at Anchorage, Alaska and dated May 13, 2009. (Corrrlxed on De cember 7, 2009, A V , Da ' l T. Seamount, Jr. Cathy A, Foerster C air Commissioner cc: BPXA Well Integrity Coordinator, PRB -20 P.O. Box 196612 Anchorage, AK 99519 -6612 RECONSIDERATION AND APPEAL NOTICE -" As provided in AS 31.05.480(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and maybe appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is no included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m, on the next day that does not fall on a weekend or state holiday. ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, September 17, 2009 Jim Regg ~ P.I. Supervisor ~~~~ ~~~( ~~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-35 FROM: 7ohn Crisp PRUDHOE BAY UNIT W-35 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT W-35 API Well Number: 50-029-21799-00-00 Inspector Name: John Crisp Insp Num: mitJCr090914085435 Permit Number: 188-033-0 '~ Inspection Date: 9/12/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ' -- Well W-35 Type Inj. ~'~ TVD r-- -i- g340 ~ jA 1540 !- ~ -~--- 4000_ i 3960 3940 ~-- ~ P.T.Di ~g80330 ,TypeTest~SpT~Test psi --- - -- ~- ----~- - 2oss ~ ~ OA o ~ -1--- ' -~ ----- - _ o _ o i o - Interval °T~R p/F P - ----- -- i Tubing (_ io~o ~ -- io~o to~o io~o ---~ - NOtes: MIT IA post patch. 7.2 bbls pumped for test. p~,~~~~ ~ '~~~~ +/ ~ ~;r, ~!? ~ . , . ~)(~(Yi~ Thursday, September 17, 2009 Page 1 of 1 ~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical lnbegrity Test Email to:jim.regg~alaska.gov; tom.maunder@~alaska.gov;ba~_fleckenstein~a~ska.gav;c~a.aogcc.prudhoe.bay~alaska.gov OPERATOR: BP Ex~araqon (Alaska}, {nc. FIELD i UNIT / PAD: Prudhoe Bay / PBU ! W Pad DATE: 09/12i~9 OPERATOR REP: Toring Roschir~ger AOGCC REP: John Crisp Packer Pretest in~E 15 Min. 3d Min. Well W-35 T In. W TVD 8,34fY' T` 'f,f~2E} ' 'E,070 7,d7Q 1,070 Interval 4 P.T.D. 188Q330 T test P Test ` 2085 Ca~ 1,54Q 4,QOQ 3,9~ 3,940 P!F P Notes: AOGCC UIC MIT-IA to 4[~ ~~ pal~ah, ~e ~~ `` ' {)A U t3 0 0 Well T In'. 'fV~ ' T' Ir~terval P.T.D. T test T~k ' G' PtF Notes: OA Well T in'. TVQ Te~ ` Ir~tervai P.T.D. T test Tesf ' Gasi P/F Notes: OA Well T In _ T'1~ T' Irrterval P.T.D. T test ~es1 ' C' PIF Notes: OA Weil T In". TVF~ T" Interval P.T.D. T test ~~ ~ P/F Notes: OA TYPE INJ Codes D = Driliing Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water 71fPE TE3T Cc~s M = Annuleas Nbr-iforirx3 P = Staredanl ~e~satce Test R = {rrtemat R ` ` Trac~r Surrrey A = T~du~e Awac~aty Sa~raref+ D - • - T e Test ''~:~~~` ~, t,,~ t <.~ 2C'~i; ~~y ~' .~~ ; , . ~. ~~, ~iC~`SO INTERVAL Codes I = Ini6al Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Olher (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU W-35 09-12-09.x1s STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N -~1~~~ 1 ~l ~~ ~UG ~. 4 2Q09 8/90! REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ ~~~ ~~~~ ~~~~~. ~~~r~a~~~~~~ 1. Operations Abandon ~ Repair Weil Q_ Plug Perforations ~ Stimulate ~ Other ~ ~~~ pATCH Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time 6ctension ~ 1938'-1973' - Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~elopment ~ Exploratory ~ 188-0330 - 3. Address: P.O. Box 196612 Stratigraphic ~ Set'VICe -~' 6. API Number: Anchorage, AK 99519-6612 50-029-21799-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 90.8 KB - PBU W-35 - 8. Property Designation: 10. Field/Pool(s): ADLO-028262 - Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 10620 ~ feet Plugs (measured) None true vertical 9216.05 - feet Junk (measured) 10303' Effective Depth measured 10501 feet true vertical 9120.24 feet Casing Length Size MD ND Burst Collapse Conductor 110' 20" Surface - 147' Surtace - 147' SurFace 2623' 13-3/8" 68# L-80 SurFace - 2662' Surface - 2662' 4930 2270 Intermediate 9684' 9-5/8" 47# L-80 Surface - 9901' Surface - 8642' 6870 4760 Liner 967' 7" 26# L-80 9653' - 10620' 8454' - 9215' 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ ; - _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9623' 4-1/2" WL KB CHROME STRADDLE 1938' - 1973'_ Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" TIW HBBP-R-PKR 9498' p ,..,:_., ._~ ..,,,. ....__. ~ 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~ ~'`~" ~{~U~ ~.~..v.~°~ar't~~ ww~;,J ~~.' ~ iy? .. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 994 605 Subsequent to operation: 6477 1500 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development (` Service ~- Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas l~ WAG ~'- GINJ ~ WINJ ~+~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-223 Contact Gary Preble Printed Name Gary Pr Title Data Management Engineer Signature Phone 564-4944 Date 8/13/2009 Form 10-404 R~vised 04/2006 ~?'~ ~:~ r~~^~.~ „~ti, %~, ~ t~;4 ~~~~~ ubmi~a~~~~9 ~ ~/ W-35 188-0330 PERF ~4TT~4CHMENT • ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-35 5/5/88 PER 10,312. 10,332. 8,965.79 8,981.92 W-35 5/5/88 PER 10,332. 10,348. 8,981.92 8,994.86 W-35 5/5/88 PER 10,365. 10,375. 9,008.66 9,016.79 W-35 7/11/90 APF 10,400. 10,420. 9,037.2 9,053.57 W-35 7/11/90 APF 10,430. 10,437. 9,061.77 9,067.52 W-35 4/29/95 SQZ 10,312. 10,437. 8,965.79 9,067.52 W-35 5/5/95 APF 10,346. 10,352. 8,993.24 8,998.1 W-35 5/5/95 RPF 10,364. 10,380. 9,007.84 9,020.87 W-35 6/8/95 RPF 10,316. 10,338. 8,969.01 8,986.77 W-35 8/24/02 FIL 10,356. 10,577. 9,001.35 9,181.99 W-35 6/16/07 BPS 1,963. 10,437. 1,962.98 9,067.52 W-35 4/8/OS BPP 1,963. 10,437. 1,962.98 9,067.52 W-35 4/29/08 BPS 1,957. 10,312. 1,956.98 8,965.79 W-35 6/9/08 BPP 1,957. 10,312. 1,956.98 8,965.79 W-35 8/15/08 APF* 9,556. 9,561. 8,382.38 8,386.07 *pertorated tailpipe due to stuck plug AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ W-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 5 METHANOL 4 DIESEL 9 TOTAL • • - ~ ~; A ~ ~ -, ~ r. ~ ~~ ~ ~~ ~ t ~ ~ r~~n ~ . ~~r, p ;~ t r i . ; ~, I 'i r V `~ ~ a n r ~ ~ F ~ ~ r k " ~- ~ 1 ~p ~1 ~ ~ ~ ~ SARAH PALIN, CaOVERNOR ' , ~ i r ~ ~ ~ E ~ ~~m~ ~y~ !~ °. ~~ ~,t ~ y ` st _ ~_ '~,:~ c F._. ~._ ~' t` ~S~A D~j t'~`a~ Vct~s ~;~ 333 W. 7thAVENUE, SUITE 100 CO1~T5ERQA~`IO1~T COMAIIS51O1~T ~~ ANCHORAGE,ALASKA 99501-3539 ~ PHONE (907) 279-1433 f FAX (907) 276-7542 Ms. Carolyn Kirchner Production Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 ~`~ ~~ ~~ ;, ~~~" ~ ~~ ~~~~ Anchorage, Alaska 99519-6612 ~' a~~ Re. Prudhoe Bay, Prudhoe Bay Pool, PBU W 35 ~~ Sundry Number: 309-223 Dear Ms. Kirchner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, witYun 20 days after written notice of this decision, or such further time as the Cominission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next worlflng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of July, 2009 Encl. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSlON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~d-d9 ~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ~ Repair well Q Plug Perforations~ Stimulate ~ Time Extension ~ TUBING PATCH Change approved program ~ Pull Tubing ^ Perforate New Pool~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmen~ Exploratory ^ 188-0330 3. Address: P.O. Box 196612 Stratigraphic~ Service ^~ 6. API Number: Anchorage,AK 99519-6612 50-029-21799-00-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU W-35 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028262 90.8 KB Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDlTION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10620 9216.05 10501 9720.24 NONE 10303' Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface 147' SurFace 147' Surface 2623' 73-3/8" 68# L-80 Surtace 2662' Surface 2662' 4930 2270 Intermediate 9684' 9-5/8" 47# L-80 Surface 9901' Surtace 8642' 6870 4760 Liner 967' 7" 26# L-80 9653' 10620' 8454' 9275' 7240 5410 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 12.6# L-80 Surface - 9623' Packers and SSSV Type: 9-5/8"x4-1/2" TIW HBBP-R PKR Packers and SSSV MD (ft): 9498' 12. Attachments: Descriptive Summary Proposai ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development ~ Service Q 14. Estimated Date for 15. Weil Status after proposed work: Commencing Operations: 7/14/2009 OIL ~ GAS ~ PLUGGED ~ ABANDONED ~ 16. Verbal Approval: Date: WAG ^~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certiTy that the foregoing is true and correct to the best of my knowledge. Contact Carolyn Kirchner Printed Name Carolyn Kirchner Title P.E. Signature ~ ~ Phone 564-4190 Date 6/30/2009 COMMISSION USE ONLY ~`~~~ ~` Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,~~~ ~~~ Plugintegrity ~ BOPTest ~ MechanicallntegrityTest ~ LocationClearance ~ ~~~~~~G~ omer: ~UN ~ 0 ZQ09 , ~ ~~ ,;ut ~ ~s 2QQ9 ~I8S~4a ~!I ~ C~3S ~~Pi~"• ~m~~~J5t0~9 Subsequent Form Required: y~ Ae~chcar~g~ APPROVED BY o Approved by: C I THE COMMISSION Date: Form 10-403 Revised O6/20(96~ v~~~ U I I V~"1 ~ Submit in ~pl'~a~ ~~~~ W-35 188-0330 PERF ATTACHMENT • ~ U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-35 5/5/88 PER 10,312. 10,332. 8,965.79 8,981.92 W-35 5/5/88 PER 10,332. 10,348. 8,981.92 8,994.86 W-35 5/5/88 PER 10,365. 10,375. 9,008.66 9,016.79 W-35 7/11/90 APF 10,400. 10,420. 9,037.2 9,053.57 W-35 7/11/90 APF 10,430. 10,437. 9,061.77 9,067.52 W-35 4/29/95 SQZ 10,312. 10,437. 8,965.79 9,067.52 W-35 5/5/95 APF 10,346. 10,352. 8,993.24 8,998.1 W-35 5/5/95 RPF 10,364. 10,380. 9,007.84 9,020.87 W-35 6/8/95 RPF 10,376. 10,338. 8,969.01 8,986.77 W-35 8/24/02 FIL 10,356. 10,577. 9,001.35 9,181.99 W-35 6/16/07 BPS 1,963. 10,437. 1,962.98 9,067.52 W-35 4/8/08 BPP 1,963. 10,437. 1,962.98 9,067.52 W-35 4/29/08 BPS 1,957. 10,312. 1,956.98 8,965.79 W-35 6/9/08 BPP 1,957. 10,312. 1,956.98 8,965.79 W-35 8/15/08 APF* 9,556. 9,561. 8,382.38 8,386.07 *perforated tailpipe due to stuck plug AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FI~ FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • To: C. Olsen / J. Bixby, GPB Well Ops TL From: Carolyn Kirchner, PE Subject: W-35 Tubinq Patch Est. Cost: $80M PBWPDWL35-C Est. IOR: 250 BOPD Date: June 28, 2009 1 S Dumm atch drift 4.5"x44' atch w. X-ni le & WLEG 2 E Install tubin atch 3 F MITIA at 2500 si - establish LLR if MITIA fails Well status: PWI only - TxIA communication while on MI injection Typical Injection: Water: 1350 psi, 5000 BWPD; MI: 2600 psi, 10.5 mmscfd Max Deviation: 44 deg at 8800 MD Min. ID: 3.725" ID at 9591' MD 4-1/2" Otis XN nipple Last TD tag: 4/6/09 sat down high with 20' whipstock at 9159' SLM and worked through to 9526' SLM to tag fish 6/29/08 tagged WRP fish and pushed from 9507' to 9560' SLM. Last Downhole Ops: 4/5/09 caliper and LDL run to diagnose leak. Caliper lost an arm. H2S Level: N/A - injector Well History: Well W-35i was recently found to have Tx1A communication while on MI injection. The well passes an MIT-IA while on water injection. The last passing water injection MIT-IA was on 4/18/09 to 2400 psi. A caliper and LDL were run to try and identify the leak. The caliper found the 4.5" tubing to be in good to poor condition with a line of pits in jt 41-42 and an isolated pit in jt 53. The LDL was inconclusive, but indicated that the leak may be at the SSSV, perhaps a control line leak. This SSSV leak is the target for the patch. Due to the uncertainty of the leak location, the patch will be run and a RWO package is being completed as a fall back plan. W-35i supports W-27A, W-37A and W-30. The long term overall benefit from 2 more slugs of MI into W-35 MI is quantified at 1 MMBO. A post patch injection rate of 2600 psi, 10.5 mmscfd is expected. This should provide a pattern IOR of 250 bopd. Objective: The objective of this job is to set a patch across the SSSV profile to isolate a possible leak in this region. If this fails, a RWO will be planned for this well. An X nipple profile and MCX SSSV will need to be incorporated into the patch to meet state requirements for gas injection. This profile will be hung off the bottom of the patch with a WLEG. Fish: ~ The fish at 9526' SLM is a 4-1/2" WRP set for a tree change out. Previous fishing attempts were able to latch the WRP, but slipped off. The WRP is still in the well, so holes were shot in • • the tailpipe from 9556'-9561' MD to allow fluid to flow past. The remaining profile is an X profile in the sliding sleeve at 9437' MD. There are several fish in the well below the WRP including a rubber packing element from when the packer was originally set and TEL finger left in the well on 12/12/06. During the caliper run on 4/6/09, a caliper arm was left in the well above the WRP. Please cal! Carolyn Kirchner at 564-4190 (W) or 980-2926 (C) with questions or comments. cc w/a: Well File JOB PLANNING DETAILS: Tubing leak: 1966' MD near SSSV based on 4/5/09 PDS LDL. SSSV ID: 3.813" Patch specs: 35 foot E-E Baker KB Single Trip Straddle. ID of 2.44". Patch rated 3500 psi. Tailpipe with 2.313" ID X nipple and WLEG will be hung off bottom of patch. Total Length including patch & tailpipe assembly is 44' Patch setting depth: Bottom packer at 1973' MD, Top packer at 1938' MD Collar Locator Summary from eLine PDS LDL Log: CCL 1941' SSSV Top 1952' SSSV Bottom 1961' CCL 1979' CCL 2017' Tie-in Log: 4/5/09 PDS LDL NOTE: Ensure entire patch assembly (patch, nipple, WLEG) is all one material: either 18Cr or L-80. PROCEDURE: Pre-Patch 1. Assemble patch at shop and drift. Note max ID. 2. RU slickline. RIH and drift to 2100' MD with a 4-1/2"x44' dummy patch. See enclosed diagram. 3. Check Sundry materials are filed and approved. Patch Installation 4. RU EL. RIH with patch and tailpipe assembly and tie into jewelry near SSSV, reference log 4/5/09 PDS TecWell LDL log. Log up to setting depth. Install 4.5"x44' Baker KB single trip retrievable tubing patch with X-nipple and WLEG over interval 1938'-1973' MD. RD eline. Maximum differential pressure rating of the patch is 3500 psi. Patch ID of 2.44". X-nipple ID is 2.313". Post Patch 5. MITIA at 2500 psi. Establish LLR if MITIA fails. • 4/5/09 PDS Leak Detect Log C~ -100 Line Speed (Nmin) 100 0 WLO-A 5000 4000 CCL -400 0 WLD-B 5000 20 Temperature (degf) 220 0 WLD-C 5000 _ _._ ___ _ . ------ -- --- - - -- - --- __ 0 Temperature (degF) ___.. -1 Differential Temperature (tlegF) _ _ _ __ _ _.___ _. ... - ~ - - - __ - - -- -- - -- ~ F ~-{ ~ -- - --r - -- - i -- -- - _ - Lin e Sp eed -- - - - - --- -- - - - - Tem perat ure em pera ture ent Potenbal Lea e n t EG DiAerentlal Tempereture 2000 ~ ~ ~ ~ bp Baker Thru-Tubing ~ '~ 45 WL "KB" Single Trip Straddle ~ OPTION #1 - Single Set Baker Oil Tools we~~; W-35 Date: ~X Co. Man: ~ ~TV~ ~ OD ID Length ~ 9CR - 45 "KB" Upper Straddie Packer " . 4 GS Fishing Nedc Up 3.70" 31i2" Sl'L Pin Dovm 2.45" 5.51' 30K Shear Rele~e H819634511 5.51 (81'/:' - 20 Shear Pins ~ 11,320#'s (3rd Shear) Q , . 3.9 3' 35' 43.65' 30.24' I 13 CR - 3112" STL Full Joint 3.50" 2.972" 30.24' _.__ _ .83' -~~ 9CR - 45 "KB" Lovrer Straddle Packer „ „ . - 3 v~' Box up 3.70 2.45 5.40 ~ 5 qp~ WLEG Down 30K Shear Release •e• H819634511 ~ ~5)'h" - 20 ~ 70Tb#'s (i~~ Shear) (2) 5/16" -18 ~ 4,75fi#'a (2nd Shear) NOTE: Setting tool WLAK Dressed with (1) .410" Dia Shear Shid ~ 18-21K# (4'" Shear) 2.31" "X" Nipple 3.50" 2.370" -2.00' W~EG 3.50" 2.972" -0.50' .~ ~ ~ ~ TREE = 4-1116" C~N V11~1FlEAD = MC~VOY ACfUATOR= BAKH2 KB. ELEV = ~_86' 8F. H.EV = 54.33' . KOP = 4 -. 3200' A~x A ngle =~~ 44 Q 8800. Datum A~U =.'~_ 10218' OetumND=~ 8800'SS I 13-318' CSG. &8#. L-80. D= t2.4 i5" ! Minimum ID = 3.725" @ 9591' 4-1/2" OTIS XN NIPPLE gq9$' {--~4-1lYT8GSEALASSY ~ g49g~ Hs-srs° X a.,n• nov -sea-R ~ ? FISH-CB~IT'RALIZHtAWd(04 a ~n° isc- ~c, a2.s~, t-ao, .0152 bpf , D = 3.959' TOP f~ T tNR " CSG, 47#, L-80, ID = 8.681" PERFORATpN SUMAAARY R~ LaG: BHCS ON 05I01i88 ANGLE AT TOP PBiF: 34° Q 10513' Note: Refer W Roduatbn 08 fa hlstorical perf data SIZE SPF N'fB~VAL Opn/Sqz DATE 5" 5 10312 - 10348 S O4129/95 3316" 6 10316 - 10338 C 06/0&95 3-318" fi 10338 - 10346 S O4f19J95 3 3/8" 6 103A6 - tG352 C 05A5195 3318" 6 10364 - 10380 C 05105195 3-3/8° 4 l0400 - f0420 S O4129t95 3-3t8" 4 14430 - 10437 S O4J29i95 W-3 5 ~F~, ~~: ~ !2" OTS FIXO SSSV NF GAS LF'f M4NDRELS LV LA DA 8 2924 28~3 5 pTtS DAN RA 0 OB/25/02 7 5715 5248 37 OTIS DA~N ftA 0 08125l02 6 6691 6045 35 OT4S auTY RA 0 5 7233 6494 34 OTIS DMY RA 0 4 769fi 5877 34 OTtS ~~IY RA 0 3 $357 7409 40 0T5 DtuN RA 0 2 9179 8014 43 OTtS DNIY RA 0 1 9327 8123 43 OTTS ~l RA 0 9$5$' ~--~4-12" OT1S X NP, D= 3.813' 9558~ 41J2" WRP(04109108) 9$91' 4-1l2" 0T6 XN NP, D= 3.725' 9623' H4-1PZ"TBGTAL,ID=3.958° 9628' ~MD TT LOG~ 98fD7194 T" LNR, 26#, L-~, 0.0383 bpf, D= DATE FiLa/ BY COM9rEITS DsATE REV BY CONM~ENTS 05/05188 GRV OWGINALCOMPLEfION 08~15r08 SEWfSV SEfWRP{08/29l08 OSl08l01 RWTP COF~iBCTpNS 08117~8 RimISV TIJBNGPUNC~1{48/15l08} 08130/02 DTR/TP GA~FT {70 72/03N8 ?/ PJC SSSV CORRECfIJN 1020/02 PPIKAK F~ ~ECTpNS Ofi+31/fl9 SWCJ7LH FSH (04l06I09) 12/1M06 9?9(fLH FISH (TH. FlNGBtj 05l31/08 FL8/PJC ACTUATOW tYV WRRECTION PRUDFIOE BAY ld~T W~L: W-35 P~AR No: 1880330 A PI No: 5D-028-21 799-00 SEC21, T17N, R92E, 1251'SN.& 145~' VUEL 9P Exploration (Alaska) SARAH PAULA, GOVERNOR AL&SKA OIL AND GAS 333 W 71h AVENUE, SUITE 100 CONSERVATION COI~ HSSION ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 3.027 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU W -35 PTD 1880330) Request for Administrative Approval ( q PP Prudhoe Bay Oil Pool Dear Mr. Rossber : g Pursuant to Rule 9 of Area lniection Order (AIO) 3.000, the Alaska Oil and Gas Conservation Commission ( AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. BPXA notified the Commission of inner annulus (IA) repressurization affecting PBU W- 35 while injecting miscible injectant (MI). Diagnostic mechanical integrity testing confirms the well exhibits competent tubing and production casing. Attempts to locate the sourece of pressure communication using a leak detect log and a tubing caliper survey were unsuccessful. BPXA has elected to perform no corrective action at this time on PBU W -35. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the certain constraints. AOGCC's administrative approval to continue water injection only in PBU W -35 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall limit the well's IA pressure to 2000 psi. A10 3.027 titay 1 3, 2009 Page 2 of 2 5. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7_ The MIT anniversary date is April 18, 2009. DONE at Anchorage, Alaska and dated May 1 , 2009. ..� 41i.A Ulf Daniel T. Sean3ount, Jr. Cathy . Foerster� Chair Commissioner cc: BPXA Well Integrity Coordinator, PRB -20 P.O. Box 196612 Anchorage, AK 99519 -6612 C O . RECONSIDERATION AND APPEAL NOTICE As provided in AS 31 05.0 80(a), within 20 days alter written notice of the entry of this order or decision, or such liuther ume as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it If the notice was mailed, then the period of time shall be 23 days An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL. and may be appealed to superior court The appeal MUST be filed within 33 days after the date on which the Com- mission malls, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final Bather, the order or decision on re- consideration will be die FINAL order of decision of the Commission, and it may be appealed to superior court That appeal MUST be tiled within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes. the order or decision on rc- consideration. As provided in AS 3105 080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." i Ir. computing a period of time above, the date of the event or default alter which the designated period begins to run is not included in the pe- riod the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5,00 p m on the next d ay that does not fall oil weekend or state holiday. by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 C E I VE 0 APR 2 9 2009 April 23, 2009 ^Alaska Oil & Gas Cons. Commission Ancharap Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well W -35 (PTD #1880330) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well W -35. Well W -35 exhibits inner annulus repressurization of approximately 200 psi /day while on MI injection. However, a pressure test of the inner annulus passed to 2400 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well W -35 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564 -5637 or Anna Dube / Andrea Hughes at 659 -5102. Sincerely, R. Steven Rossberg BPXA, Wells Manager I Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby /Olsen Dube /Hughes West Area Manager Dan Robertson Harry Engel Janice Vosika 0 • Prudhoe Bay Oil Pool Well W -35 Technical Justification for Administrative Approval Request April 23, 2009 Well History and Status Prudhoe Bay well W -35 (PTD #1880330) exhibits inner annulus repressurization while on MI injection indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 2400 psi passed on 04/18/09 indicating competent tubing and production casing. Recent Well Events: ➢ 03/27/09: IA Pressure build-up ate of 200 psi/day while on MI injection P P Y 1 ➢ 04/03/09: MIT -IA Passed to 2400 psi ➢ 04/06/09: Caliper tubing, memory TecWel LDL did not identify location of leak to MI ➢ 04/18/09: AOGCC MIT -IA Passed to 2400 psi witnessed by John Crisp Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2400 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 4 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut -in and the AOGCC notified if there is any change in the wells mechanical condition. W-35 TIO Plot 4000 -.0-- Tbg *-- LA on 0414 1 , 110 )111, seams w GA 2000 ■ 521 Me OOA DOCA I Hasse IS oft On 1,000 ■ "N"M rw- ■■■" SMINIM■■■ as ago ( s e e ms 01/24/09 01/31/09 02)07105 02/14/09 02/21/09 OMISKO MUM 02)14109 WW1109 03128/09 04/04/09 OVUM 04/16/09 W-35 Injection Plot - --- ----- -14,000 3500 -12,000 3,000 - 10 2.500 WHIP B'Ow Sw _PW MI -6,000 9 - G 1500 O -4,.0 on 1.000 2000 5m 01/24/09 01/31109 02. OW 4. 02!21 /09 02/28M 03/07/09 03114M9 0321.1119 0328109 04A04M 04/71M 04,'16109 s • Schematic 7RIL 4- 1114tsn OY W 35 UYN�S: - BAKER R N FLW - 9Q BF. ELEV r 5437 K®P- 3204 Mat An* 44 @ SS 1 g� 4 -ild OM 141(0 SSSIi NP D -1813 Cb4Ya kD- .. _ .... -. 1=021$ GASLFrMANCIFIE.S CsfrrelVl]- 8BA0'SS ST AO 7VC I Ct1/ ME YLV LA7CH CATS a 2924 2833 5 0713 OW RA 0 0"102 7 5715 6248 37 o71S WAY FA 0 082LW 1338<' TSCs 68M 8,80. D ° 12415' ?9 6 6891 0015 35 o78S CMY FM 0 5 7233 6494 34 oms WAY FA 0 4 7696 6811 34 OW WAY RA 0 3 8M7 7" 40 0785 WAY FA 0 2 9179 8014 1 43 1 0785 W1Y FA 0 1 9327 8123 43 078 MW FA 0 Minimum ID a 1725" @ 9591' 4 -112" OTISXN NIPPLE 8432 12 OMSS DSLV. Dt? game 412 7@6 SGkL AS�W $or "Wx4 VT TWMWRPQR D� -4.0' 77B/1G W,elf91 [0B115dQ8) 9 �$' 412O183XNP,De3:843' �$' 4.111'4{3Rp(641tf9�08) 4•N 2"0T8108NP,D �3.725 - 1/ ?T83G 228/ L-M. 8873` 01 =2 8pr, D 1968' 9873' 4.12 IM TAI, F]+ 3.85ir' g e m 9878' 13ADTT ta fflaiB4 GPOF r Lm 9 il6• cs� 4731, L80, � <aear g9 ' i0D1T PEWCMTM SA8RMIRY FuLOC�Bt3CS®N05OUl8 ? F1SF/- 41272i€NC,fli(12119�05i ANGLE ATTCP F€ W- 34• @ 10513° 1O3D PAN. MR F8 M R tkff& FAlar b Rod4ed8�e� Mr tbtuioal peer data S82f SPF WIMMWAL owjSgx CAT€ 5• 5 10312 -10348 S O4MM 3,814 6 10316 -10136 C O80M 3. 1Ft 6 10338 -10148 S "29M 3"Ar 6 low -t0362 05!06195 344 6 10364 - Iwo o .. 95!OM 3.3Ar 4 10400 -1042D S O4MM5 34W 4 10430.10=31 S 04MISS PFJTTD 1057T 7- MR. 2W.L 0. M 8 3 t0f. D -8274 LATE REV BY ccm @ITS CATS REV BY C>dAt�]J15 �I�EBAY UWf 05!8358 9Far QNM ML COUPLET10N 0816108 s7BN SV SEr WWW 082910® L W WEL-M 0®!0801 RWTP H:n7 S MUM FUMM TUBM OBdi5O8 POW Na1tiM0330 OB130O2 oTFNTP CtMFT(YO 12103MB ?IPJC SSSV A TK)N ANCZ 50029. 21799.00 J 112002 PPVAFC SM21,T1ttLR12E 125rSNL&1451'NiR W1406 ?7MLt1 FS8(TTLF 5)31!08 FLaVX AC)1FAmn t8-V CfCN BP Upbration (Ak■ ka) To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration ~Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. .Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1 ] Leak Detection - WLD 05 Apr09 W~5 2] r ~I Signed : (~~'/i' ~- - 1~db LM ~~ ~~yi.~d ~tr~~i3k ~ ~" ~' 9~ L V ~~ Color Log / EDE 5029-21799-00 Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAK: (9071245-68952 E-MAIL.._ .'___a_. _.. ._.w _._ _..__ WEBSITE _.._ _ ~ . ____ C:\Documenis and Settings\OwneilDesktop\Transmit_BP.docx MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 20, 2009 To: Jim Regg 'I~ l P.I. Supervisor 1~~~~ ~(z~/ ~ ~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-3s FROM: John Crisp PRUDHOE BAY iINIT W-35 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~r~~ NON-CONFIDENTIAL Comm Well Name• PRUDHOE BAY UNIT R'-35 Insp Num• mitTC~90419085810 Rel Insp Num: API Well Number: 50-029-21794-00-00 Permit Number 188-033-0 i Inspector Name: John Crisp Inspection Date• 4/18/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weli W_35 Type I2t~• W TVD 8340 '~ IA s20 2400 ~ 2360 2350 P T• isao33o TypeTest SPT Test psi toss ,/ pA o 0 0 0 Interval OTHER P~F P .. Tltbing 300 300 300 300 Notes: MITIA to 2400 psi pre AA for slow TxIA ommunication. / tu~6.:~,1"1a ~ • Monday, Apri120, 2009 Page 1 of 1 OPERABLE: W-35 (PTD #1880330) PWI Only due to TxIA Communication when on MI Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] '~~~ Z'7~ ~L~ Sent: Saturday, April 18, 2009 2:32 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Robertson, Daniel B(Alaska) Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-35 (PTD #1880330) PWI Only due to TxIA Communication when on MI Attachments: W-35 TIO and Injection Comparison.ZlP All, Well W-35 (PTD #1880330) has been under evaluation for possible TxIA communicaiton while on MI injection. Although a leak detection log was completed on 04/06l09, the depth of the leak was not ide~fied. The we I passed an AOGCC witnessed MITIA on 04/18/09. The well has been reclassified as Operable and is limited to PW injection only. A request for AOGCC Administrative Approval will be sent shortly. A TIO Plot and Injeciton Plot comparison has been included for reference. ~~,~' «W-35 TIO and Injection Comparison.ZlP» ~,/ ~~ ~` ~ z7 ' C'f,~ Please let us know if there are any questions. ~ v Thank you, ~~~~~~~ Anna ~Du6e, ~.~. Well Integrity Coordinator : ~,:,- ~ ,~_• . `:~ ~~~~~~~ GPB Wells Group ~'~~~~a~~`~-^~°~° '~~'~°` " ~ '~ Phone: (907} 659-5102 Pager: (9Q7} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, March 21, 2009 9:25 AM To: 'Regg, ]ames B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Robertson, Daniel B (Alaska) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-35 (PTD #1880330) High IA Pressure AI I, Well W-35 (PTD #1880330) is a gas injector currently on MI injection. The well has been reclassified as Under Evaluation to monitor the TIO plot due to concerns of possible IA repressurization. The MI injection rate has not been stable of the last three months adding difficulty to the analysis. The IA pressure will be bled to under 1000 psi and monitored. The well may remain on MI injection while the pressures are being monitored. A TIO plot and Injection Plot comparison has been included as well as a wellbore schematic. Please notify us if there are any questions. Thank you, 7/29/2009 OPERABLE: W-35 (PTD #1880330) PWI Only due to TxIA Communication when on MI Page 2 of 2 Anna ~Du6e, ~P. E. Well integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 7/29/2009 W-35 (PTD #1880330) TIO and Injection Comparison 4.OOGT ............................................ .......................................~ .. 3,OOU t Tbg a a z.ooo -+- on ^ ~ ~ ~ ooa . oooa ~ ~_~~ ` ~~ ~ i ~ On -~ ~~ i ,.ooo 'I~r ~ ii OV24/09 Ot/31/09 02IW/09 02/14/09 02/21/09 02l28I09 03/07/09 03/14I09 03l21l09 03/29/09 04/04/p3 _~a;'ii 9 3,Sp0 ............................................ ...................................... . tap00 ~ 3,60i i 1 ~ A00 3AD0 1 3,200 ' f l 72A00 3,000 ~ ( ~ 1t,000 2 800 ~ h I , ~ 10,000 2,600 ~ ~ 2 400 I 9,000 , 2,200 _ 3 000 ~-` a 2.000 Y~ ° ' ~ - 7.UOLl 1,600 ~ 1,600 s.On[i T 0 1,400 5,OUC~ 1,200 1,000 j1 4,000 800 ~ 3,000 6D0 2,000 400 200 1.000 - WHIP SW - PvJ - MI - GI - Othu ~ On 01/31/09 02/14/05 02/28/09 03/14l09 03/26J09 D4/11 UNDER EVALUATION: W-i~PTD #1880330) High IA Pressure • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, March 21, 2009 9:25 AM ~~~~~ 3~y~o~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Robertson, Daniel B (Alaska) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-35 (PTD #1880330) High IA Pressure Attachments: W-35 TIO Injection Comparison.pdf; W-35.pdf All, Well W-35 (PTD #1880330) is a gas in'ector current) on MI injection. The well has been reclassified as Under Evaluation to monitor the TIO plot ue to concerns of possible IA repressurization. The MI injection rate has not been stable of the last three months adding difficulty to the analysis. The IA pressure will be bled to under 10 0 psi and monitored. The well may remain on MI injection while the pressures are being monitored. A TIO plot and Injection Plot comparison has been included as well as a weilbore schematic. «W-35 TIO Injection Comparison.pdf» «W-35.pdf» Please notify us if there are any questions. Thank you, Anna ~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907j 659-5100 x1154 3/23/2009 • ~ ~ 3~~~c~oa ^ a ~ a[ o o c ~? o 0 0 o BV./PD I MCFPD ~* . I 0 0 0 0 °o °o °o °o o °o °o °o ~~ T o 0 0 0 0 ~ oo cd v' ni 0 N ~L cQ G 0 V a AQ W Q a `O r M • • ^ ^ ^ ^ • ^ ^ ^ ^ ^ ^ 0 v Ci ~ I i v v n 0 o ~ I 0 N O i O N N O 07 O i N O O n O N O m o ~ M i o o ~ N ~_ O O ~__ O 07 O O O 07 O t C'7 O O O N 1 N r ` O O O O O O O O O O ~ ~ O t~ O V M N r C 1 N N r ..__ __.._._._..d.__..e~.._..._ ~..__.~___J ~ j diH,~r O O 1 ti O 1 N 0 m 0 c, 0 m 0 v N O 4l O 1 l O O O O ~ ++ O I ~J O 1 C''7 O 1 G O O N 1 N TREE= 4-1/16" CM/ W-35 SAFET ES: WELLHEAD = MCEVOY ACTUATOR = BAKER C KB. ELEV = 90.88' BF. ELEV - 54.33' KOP = 3200' Max Angle = 44 @ 8800' Datum MD = 10218' Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" @ 9591' 4-1 /2" OTIS XN NIPPLE ~ TUBING PUNCH (08/15/08) I 4-1/2" TBG- IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 05/01/88 ANGLE AT TOP PERF: 34° @ 10513' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 5" 5 10312 - 10348 S 04!29/95 3-3/8" 6 10316 - 10338 C 06/08/95 3-3/8" 6 10338 - 10346 S 04/29/95 3-3/8" 6 10346 - 10352 C 05/05/95 3-3/8" 6 10364 - 10380 C; 05/05/95 3-3/8" 4 10400 - 10420 S 04/29/95 3-3/8" 4 10430 - 10437 S 04/29/95 PBTD 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" I 10577' I 1983 I-~4-1/2" OTIS HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2924 2833 5 OTIS DMY RA 0 08/25/02 7 5715 5248 37 OTIS DMY RA 0 08/25/02 6 6691 6045 35 OTIS DMY RA 0 5 7233 6494 34 OTIS DMY RA 0 4 7696 6877 34 OTIS DMY RA 0 3 8357 7409 40 OTIS DMY RA 0 2 9179 8014 43 OTIS DMY RA 0 1 9327 8123 43 OTIS DMY RA 0 9437' IJ4-1/2" OTIS SLD SLV, ID = ? ~ 9498' ~I4-1/2" TBG SEAL ASSY 9498 9-5/8" x 4-1/2" TM/ HBBP-R PKR, ID = 4.0" 9558 4-1/2" OTIS X NIP, ID = 3.813" 9558 4-1/2" WRP(04l09/08) 9591' 4-1/2" OTIS XN NIP, ID = 3.725" 9623 4-1/2" TBG TAIL, ID = 3.958" 9628 ~ ELMD TT LOGGED 08/07/94 10017' ~ MARKER JOINT FISH - 4-1/2" TEL FINGER (12/1 103- 0~ FISH - PKR RUBBER DATE REV BY COMMENTS DATE REV BY COMMENTS 05/05/88 GRV ORIGINAL COMPLETION 08/15/08 SEW/SV SET WRP (06/29/08) 09/08/01 RN/TP CORRECTIONS 08/17/08 RRD/SV TUBING PUNCH (08/15/08) 08/30/02 DTR/TP GASLIFT C/O 12/03/08 ?/ PJC SSSV CORRECTION 10/20/02 PPlKAK PERF CORRECTIONS 12/14/06 ???/TLH FISH (TEL FINGER) 05/31/08 FLS/PJC ACTUATOR/ GLV CORRECTION PRUDHOE BAY UNff WELL: W-35 PERMfI- No: 1880330 API No: 50-029-21799-00 SEC 21, T11N, R12E, 1251' SNL & 1451' WEL BP Exploration (Alaska) W-35 Plan Guidance • Page 1 of 1 • Regg, James B (DOA) 1 ' °~' ~~'"' From: Regg, James B (DOA) Sent: Thursday, December 04, 2008 3:05 PM ~ ~Z`4~Z To: 'NSU, ADW Well Integrity Engineer' ~~ 1 Cc: Maunder, Thomas E (DOA) Subject: RE: W-35 Plan Guidance As discussed, it does appear that the IA pressure is stable and the spike that occurred on or about 11/23 can be explained by the signi#icant increase in M! injection (thermal effect). We concur with the decision to defer running the leak detect log and to leave W-35 on MI injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~'~ ~F H ~ ~ ~~~~ Anchorage, AK 99S01 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, December 04, 2008 11:34 AM To: Regg, James 6 (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: W-35 Plan Guidance Jim, W-35 is an injector that was placed Under Evaluation for TxIA communication while on MI. Approval was given to keep the well on MI while we conducted an LDL before swapping to water injection while we evaluated a repair option. Included in the email is a copy of the recent TIO and Injection plots. In the current conditions of this well I am unsure if the rate of repressurization of the IA will show a leak in the IA. I wanted to discuss these with you to get your guidance on the plans for this well. Is there a time that would be good for me to call and discuss? «W-35 TIO 12-04-08.ZIP» Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 12/4/2008 • PBU W-35 PTD 188-033 12/4/2008 UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Page 1 of 4 • , Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, November 28, 2008 1:03 PM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Attachments: W-35 TIO with Temp.xls Jim, ~ ;1 ~Z`~i`Zti~ The enclosed file has the temperature overlaid on top of the TIO plot. Let me know if you need it overplayed on the rate plot as well. Currently the TIO and the rate plots can be generated without too much trouble but the temperature data is captured and stored in a different data source. We are currently working with our computer programmers to have the temperature added to the plots but it has not been completed as of yet. Also for the background color of the other plots, this is another bug that we have requested to be changed as well. For now I have also included copies of the legends here. Another option is to increase the zoom of the plot to -200%. Rate Plot TIO Plot Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes , ~~~~ SEC ~ .~ X008 Office: 659-5102 "~-~; - Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2008 10:00 AM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Can you add temp to the TIO pressures or rate plot? / Also, we cannot read the key on the plots that you did send. Is there any way for you to change the background color from dark blue or annotate some other way? 11 /28/2008 UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Page 2 of 4 • • Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 28, 2008 9:33 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Jim, For W-35 the temperatures are taken with a daily read from the S-Riser. Let me know if there is any other information you would like. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2008 8:59 AM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Thank you for the additional information; da you monitor temperature at/near the wellhead? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, November 26, 2008 9:54 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Jim, Thank you for your e-mail. Without any unforeseen delays, the leak detection log on Well W-35 should be completed within one week. ~~ A comparison of the T10 plot and injection plot has been included for reference. Although the plots are not of the same 11/28/2008 UNDER EVALUATION: W-35 (PTD #1880330} WAG Injector with IA repressurization Page 3 of 4 • scale, an attempt was made to align the plots for comparision. In mid-October, the swings in IA pressure were atributed to the swings in injection rates and therefore t e on the annulus. The bleed history since the waif was put on MI injections only two bleed events. The first bleed event occurred on 10/17/08 when the IA pressure was hied from 1220 psi to 530 psi. The following day the fA pressure was 540 psi. The second bleed event occurred on 11/23/0$ after notification of increasing IA pressure by the aperator. The IA pressure was bled from 2180 psi to 400 psi. The o lowing day the AOGCC was notified of IA repressurization when the IA pressure increased to 780 psi. Please let us know if you have any questions. Thank you, Anna Dube From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, November 26, 2008 10:22 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization I concur with the decision to keep on ME to accomplish the leak detect log - it is not clear what you mean by "short amount of time°' . Perhaps in the future you could give a better time assessment. i would think you could pin down the LDL within +/- a week. I would like an explanation of why it took so long to report the IA repressurization. We have had this discussion before on other webs. What I see from the pressure record does not seem consistent with the injection order which requires notification whenever operating pressure observances indicate communication or leakage of any casing, tubing, or packer. Since the T10 plot is nat annotated, 1 cannot for certain say pressure fluctuations are due to bleed events, but active pressure management is what appears has been ongoing since placed on MI injection in late September. A pressure bleed event and repressurization is an indication of leak giving no change in thermal conditions of the well. Specific to W-35, it appears this notice should have been made to Commission in October. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, November 24, 2008 1:54 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Makarov, Egor; GPB, Well Pad MN; GPB, Prod Controllers; Julian, Jennifer Y; Oakley, Ray (PRA); GPB, Well Pad SW Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization All, Well W-35 (PTD #1880330) is a WAG injector currently on MI iniection with IA repressurization. The wellhead pressures were tubing/IA/OA equal to 2540/1600/0 on 11/22/08. The well has been reclassified as Under . The well shall remain on MI for a short amount of time to conduct a leak detection log on MI and then must be swapped to water for an AOGCC M I IA. The plan forward for this well is as follows: 1. Eline: TecWel LDL 2. Operations: Swap well to water injection 11/28/2008 UNDER EVALUATION: W-35 (PTD #1880330) WAG Injector with IA repressurization Page 4 of 4 • , 3. Fullbore: AOGCC MITIA 4. Well Integrity Engineer: Evaluate log and MITIA results for plan forward A TIO plot and wellbore schematic have been included for reference. «W-35 TIO PIot.ZIP» «W-35.pdf» Please call with any questions or concerns. Thank you, Anna ~Du6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phane: (907} 659-5102 Pager: {907} 659-5100 x1154 11/28/2008 W-35 TIO Pressures and Temperature vs. Date 4000 c~~~ ~~v-u'~3 140 120 3000 N a 2000 N a 1000 0 00 00 00 00 O`b 00 00 00 00 00 00 00 00 00 00 ~~O ~~O \~O ~~O ~~O ~~O ~~O ~r~0 ~~O ~~O ~cLO ~~O ~~O ~~O ~~O 0~~~ 0~~0 0~~~ 000 ~0~~ ~O~~O ~O~^~ ,~O~~O ~0~~~ ,~0~00 '~~\~ '~~\O ,~'~~~~ ^'~~~0 ~'~~~~ Date Page 1 100 ~ _ m 80 -~- IA Pressure ~ m --~ Tubing Pressure ~ ~-- OA Pressure 60 ~ -t Online -se - Temperature d 40 20 Vertical lines represent bleed events 0 • • • c~ 3 4 M m 0 ~a~o ~~o t~0 -~- s~-M ~~ 8001816 800ZltrZJB ov , 000 4 d~~'1~N~! '~ ~ ' 000' ~ 800Z161Z 6 800Z1tr~1 L L $OOZ18J 4 6 800Z1trZ10 L $OOZ1610 4 800~l8U6 TREE= 4-1116" CM/ WELLHEAD- MCEVOYa ACT~UATOR BAKER C ~ KB. Eli EV = 90.88' BF. EIEV - 54.33' KOP = _ 3200' Max Angle = 44 @ _8800' 'Datum MD = 10218' Datum TV D = 8800' SS • W-35 SAF TES: 19$3' --~ 4-112" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDREL S ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2924 2833 5 OTIS DMY RA 0 08/25/02 7 5715 5248 37 OTIS DMY RA 4 08/25/02 6 6691 6045 35 OTIS DMY RA 0 5 7233 6494 34 OTIS DMY RA 0 4 7696 6877 34 OTIS DMY RA 0 3 8357 7409 40 OTIS DMY RA 0 2 9179 8014 43 OTIS DMY RA 0 1 9327 8123 43 OTIS DMY RA 0 13-318" CSG, 68#, L-8Q, ID = 12.415" Minimum iD = 3.725" @ 9591' 4-112" OT1S XN NtPPLE TUBING PUNCH (08115108) E-{ 9556' f 4-1t2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMftr1ARY REF LOG: BHCS ON 05101(88 ANGLE AT TOP PERF: 34° @ 10513' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 5" 5 10312 - 10348 S 04/29/95 3-318" 6 10316 - 10338 C 06!08/95 3-3f 8" 6 10338 - 10346 S 04(29195 3-318" & 10346 - 10352 C 05/05195 3-318" 6 10364 - 10380 C 05105195 3-318" 4 10400 - 10420 S 04129/95 3-3f8" 4 10430 - 10437 S 04/29/95 PBTD - j 10577' 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" 10620 9437' ~J 4-112" OTIS SLD SLV, ID = ? 949$' F-'4-112" TBG SEAL ASSY 949$' 9-518" x 4-1/2" TMt HBBP-R PKR ID = 4.0" 955$' 4-112" OTIS X NIP. ID = 3.813" 955$' 4-1/2" WRP{06/29(08) 9591' 4-112" OTIS XN NIP, ID = 3.725" 9623' 4-1/2" TBG TAIL: ID = 3.958" 9628' ELMD TT LOGGED 08(07!94 10Q17, ~-! MARKER JOJNT FISH - 4-1l2" TE1_ FINGER (12!13!06) 10303' FISH - PKR RUBBER DATE REV BY COMMENTS DATE REV BY COMMENTS 05/05F88 GRV ORIGIiVAL COMPLETION 08/15/08 SEW/SV SET WRP{06l29J08) 09/08/01 RNtTP CORRECTIONS 08.'17/08 RRD/SV TUBING PUNCH {08!15108) 08/30102 DTR/TP GASLIFT C/O 10;'20102 PPIKAK PERF CORRECTIONS 12/14f06 ???ITCH FISH {TEL FINGER) 05131108 FLSIPJC ACTUATORI GLV CORRECTION PRUDHOE BAY UNff WELL: W-35 PERMIT No: 1880330 API No: 50-029-21799-00 SEC 21, T11 N, R12E, 1251' SNL & 1451 ` WEL BP Exploration {A(aska} Injection History for 188-033-0 50-029-21799-00-00 PRUDHOE BAY UNIT W-35 Pool Injection Inj Gas Pool Name Code RptDate (MCF) InjDly AvgGas ~If no Avg value exists for the record in tblUicMonitor, it is calculated here (Vol/InjDays). Inj Wtr *InjDly Inj (BBL) AvgWtr Days PRUDHOE OIL 640150 1/1/2003 0 0 0 0 0 PRUDHOE OIL 640150 2/1/2003 0 0 0 0 0 PRUDHOE OIL 640150 3/1/2003 0 0 0 0 0 PRUDHOE OIL 640150 4/1!2003 5615 5615 Q 0 1 PRUDHOE OIL 640150 5/1/2003 292739 9758 0 0 30 PRUDHOE OIL 640150 6/1/2003 156449 5215 0 0 30 PRUDHOE OIL 640150 7/1/2003 115419 4122 0 0 28 PRUDHOE OIL 640150 8/1/2003 344154 11472 0 0 30 PRUDHOE OIL 640150 9/1!2003 399894 13330 0 0 30 PRUDHOE OIL 640150 10/1/2003 635394 20497 0 0 31 PRUDHOE OIL 640150 11/1/2003 609860 20329 0 0 30 PRUDHOE OIL 640150 12/1/2003 59182 19727 0 0 3 PRUDHOE OIL 640150 1/1/2004 0 0 0 0 0 PRUDHOE OIL 640150 2/1/2004 0 0 0 0 0 PRUDHOE OIL 640150 3/1!2004 0 0 0 0 0 PRUDHOE OIL 640150 4/1/2004 142938 12994 0 0 11 PRUDHOE OIL 640150 5/1/2004 350433 11304 0 0 31 PRUDHOE OIL 640150 6/1/2004 393072 15723 0 0 25 PRUDHOE OIL 640150 7/1/2004 349725 11281 0 0 31 PRUDHOE OIL 640150 8/1./2004 155818 15582 0 0 10 PRUDHOE OIL 640150 9/1/2004 165328 9185 0 0 18 PRUDHOE OIL 640150 10/1/2004 541787 17477 0 0 31 PRUDHOE OIL 640150 11/1/2004 248941 10824 0 0 23 PRUDHOE OIL 640150 12/1/2004 362356 11689 0 0 31 PRUDHOE OIL 640150 1/1!2005 332015 10710 0 0 31 PRUDHOE OIL 640150 2/1/2005 241838 8637 0 0 28 PRUDHOE OIL 640150 3/1/2005 305127 9843 0 0 31 PRUDHOE OIL 640150 4!1/2005 6805 227 48000 1655 30 PRUDHOE OIL 640150 5/1/2005 0 0 62000 2000 31 PRUDHOE OIL 640150 6/1/2005 0 0 60000 2000 30 PRUDHOE OIL 640150 7/1/2005 0 0 45734 1475 31 PRUDHOE OIL 640150 8/1/2005 0 0 111967 3612 31 PRUDHOE OIL 640150 9/1/2005 0 0 225979 7533 30 PRUDHOE OIL 640150 10/1/2005 0 0 199165 6425 31 PRUDHOE OIL 640150 11/1!2005 0 0 187651 6255 30 PRUDHOE OIL 640150 12/1/2005 0 0 166378 5367 31 PRUDHOE OIL 640150 1/1/2006 0 0 243572 7857 31 PRUDHOE OIL 640150 2/1/2006 0 0 260923 9319 28 PRUDHOE OIL 640150 3/1/2006 0 0 200266 6460 31 PRUDHOE OIL 640150 4/1/2006 0 0 253500 8450 30 PRUDHOE OIL 640150 5/1/2006 0 0 228674 7377 31 PRUDHOE OIL 640150 6/1/2006 0 0 265512 8850 30 PRUDHOE OIL 640150 7/1/2006 0 0 244944 7901 31 PRUDHOE OIL 640150 8/1/2006 0 0 304236 10866 28 PRUDHOE OIL 640150 9!1/2006 0 0 337370 11246 30 PRUDHOE OIL 640150 10/1/2006 0 0 186876 6674 28 PRUDHOE OIL 640150 11/1/2006 0 0 137263 4575 30 PRUDHOE OIL 640150 12/1/2006 0 0 125550 4050 31 PRUDHOE OIL 640150 1/1/2007 0 0 131991 4258 31 PRUDHOE OIL 640150 2/1/2007 0 0 215491 7696 28 Wednesday, November 26, 24(18 Page 1 of l Injection History for 188-033 ~ 50-029-21799-00-00 ~f no Avg value exists for the record in tblUicMonitor, it is PRUDHOE BAY UNIT W-35 calculated he re (VoUInjDays). Pool Injection Inj Gas *InjDly Inj Wtr *InjDly Inj Pool Name Code RptDate (MCF) AvgGas (BBL} AvgWtr Days PRUDHOE OIL 640150 3/1/2007 0 0 178201 5748 31 PRUDHOE OIL 640150 4/1/2007 0 0 168009 5600 30 PRUDHOE OIL 640150 5/1/2007 0 0 175528 5662 31 PRUDHOE OIL 640150 6/1/2007 0 0 49549 2359 21 PRUDHOE OIL 640150 7/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 8/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 9/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 10/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 11/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 12/1/2007 0 0 0 0 0 PRUDHOE OIL 640150 1/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 2/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 3/1/2008 33342 4168 0 0 8 PRUDHOE OIL 640150 4/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 5/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 6/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 7/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 8/1/2008 0 0 0 0 0 PRUDHOE OIL 640150 9/1/2008 48689 6956 0 0 7 PRUDHOE OIL 640150 10/1/2008 279928 9997 0 0 28 Injection Total 6,576,848 4,814,329 Gas (MCF) Wtr (BBL) W'ednesday,lVovember 26, 2flti8 Page 2 of l STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS v~ ~~08 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ ~~IVaiver[] Time Extension ,},~~ ` ~ .e Change Approved Program ~ Operat. Shutdown a to Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory ~~ 1ss-o33o- 3. Address: P.O. Box 196612 Stratigraphic Service - ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21799-00-00' 7. KB Elevation (ft): 9. Well Name and Number: 90.8 KB i PBU W-35- 8. Property Designation: 10. Field/Pool(s): ADLO-028262 ' Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 10620 ~ feet Plugs (measured) None true vertical 9216.05 - feet Junk (measured) 10303' Effective Depth measured 10501 feet true vertical 9120.24 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 147' Surface - 147' Surface 2623' 13-3/8" 68# L-80 Surface - 2662' Surface - 2662' 4930 2270 Intermediate 9684' 9-5/8" 47# L-80 Surface - 9901' Surface - 8642' 6870 4760 Liner 967' 7" 26# L-80 9653' - 10620' 8454' - 9215' 7240 5410 ~~N~E~ SAP ~. ~ 20D8 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9623' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" TIW HBBP-R-PKR 9498' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1251 3217 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG +~' GINJ ~ WINJ ~ WDSPL ~N 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: 308-265 Contact Gary Preble Printed Name Gary Prebl ~ Title Data Management Engineer Signature ~ __. Phone 564-4944 Date 8/18/2008 ,~ .b Form 10-404 Revised 04/2006 (1 ~ 1 ~ ~ 1` ~ ~ Submit Original Only C~ j W-35 188-0330 PERF ATTACHMENT r~ L. J • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-35 5/5/88 PER 10,312. 10,332. 8,965.79 8,981.92 W-35 5/5/88 PER 10,332. 10,348. 8,981.92 8,994.86 W-35 5/5/88 PER 10,365. 10,375. 9,008.66 9,016.79 W-35 7/11/90 APF 10,400. 10,420. 9,037.2 9,053.57 W-35 7/11/90 APF 10,430. 10,437. 9,061.77 9,067.52 W-35 4/29/95 SQZ 10,312. 10,437. 8,965.79 9,067.52 W-35 5/5/95 APF 10,346. 10,352. 8,993.24 8,998.1 W-35 5/5/95 RPF 10,364. 10,380. 9,007.84 9,020.87 W-35 6/8/95 RPF 10,316. 10,338. 8,969.01 8,986.77 W-35 8/24/02 FIL 10,356. 10,577. 9,001.35 9,181.99 W-35 6/16/07 BPS 1,963. _ 10,437. 1,962.98 9,067.52 W-35 4/8/08 BPP 1,963. 10,437. 1,962.98 9,067.52 W-35 4/29/08 BPS 1,957. 10,312. 1,956.98 8,965.79 W-35 6/9/08 BPP 1,957. 10,312. 1,956.98 8,965.79 W-35 8/15/08 APF 9,556. 9,561. 8,382.38 8,386.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK ST O STRADDLE PACK, OPEN OH _ OPEN HOLE _ W-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY - - - -- ACTIVITYDATE ~ SUPJIMARY 8/15/2008 INITIAL T/I/O = 500 / 0 / 0 PSI. VALVE POSITIONS ON ARRIVAL: SWAB, SSV CLOSED; ALL OTHERS OPEN. 'RAN 5' TUBING PUNCHER LOADED WITH LARGE CHARGES (21 SHOTS). FIRED FROM 9555.7 - 9560.7. VALVE POSITIONS LEFT AS ON ARRIVAL. FINAL T/I/O = 500 / 0 / 0 PSI. TOP DEPTH BOTTOM DEPTH GUN DIA_M_ETER SHOT_DENSITY 9,556 9,561 ~~~~ 1.560 4.00 '**JOB COMPLETE**'` FLUIDS PUMPED BBLS 1 diesel 1 Total • (~ ~ ~,--~ ~ C~y; ~ ~~ ~-, SARAH PALIN, GOVERNOR t»i UUU / Liiilt~-71~A OITj ~ ~ / 333 W. 7th AVENUE, SUITE 100 COI~TSERVATIOl~T COMhIISSIOI~T ,1 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Daniel Robertson Sr. Petroleum Engineer BP Exploration Alaska Inc. ~~ ~~~~~ AU G ~ ~ 2008 ~ 33 PO Box 196612 ~ J " .• Anchorage, AK 99519-6612 ~, Re: Prudhoe Bay Wield, Prudhoe Bay Oil Pool, PBU W-35 Sundry Number: 308-265 Dear Mr. Robertson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this / day of August, 2008 Encl. °~~ ~ ~_ ~' ' ~ ~ ~ J • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~~~.~~ ~~~~- ~L~flg y ~[ g ~" 1 APPLICATION FOR SUNDRY APPROVAL ,,,~ , ., ~ <-~ . ~~ 20 AAC 25.280 `~~~~~ a ~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Wai~/eY ^ ~- Othe ~ Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Shooting TP ~ Change approved program^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 188-0330 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-21799-00-00 - 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 W-35 _ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028262 ~ 90.8 KB ~ 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): 10620 - 9216.05 ~ 10501 9120.24 NONE 10303' Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface 147' Surface 147' Surface 2623' 13-3/8" 68# L-80 Surface 2662' Surface 2662' 4930 2270 Intermediate 9684' 9-5/8" 47# L-80 Surface 9901' Surface 8642' 6870 4760 Liner 967' 7" 26# L-80 9653' 10620' 8454' 9215' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 12.6# L-80 Surface - 9623' Packers and SSSV Type: 9-5/8"x4-1/2" TIW HBBP-R PKR Packers and SSSV MD (ft): 9498' 12. Attachments: Descriptive Summary 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: 8/7/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Na niel obertson Title Sr. Petroleum Engineer Signature Phone 564-5546 Date 7/24/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2~/ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form fired: ~, w APPROVED BY ~ ~ S / Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/200 R l G I ~ A L ~ ~~~ ~U~ Q ? ~Q~~ Submit in Duplicate W-35 188-0330 PERF ATTACHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-35 5/5/88 PER 10,312. 10,332. 8,965.79 8,981.92 W-35 5/5/88 PER 10,332. 10,348. 8,981.92 8,994.86 W-35 5/5/88 PER 10,365. 10,375. 9,008.66 9,016.79 W-35 7/11/90 APF 10,400. 10,420. 9,037.2 9,053.57 W-35 7/11/90 APF 10,430. 10,437. 9,061.77 9,067.52 W-35 4/29/95 SQZ 10,312. 10,437. 8,965.79 9,067.52 W-35 5/5/95 APF 10,346. 10,352. 8,993.24 8,998.1 W-35 5/5/95 RPF 10,364. 10,380. 9,007.84 9,020.87 W-35 6/8/95 RPF 10,316. 10,338. 8,969.01 8,986.77 W-35 8/24/02 FIL 10,356. 10,577. 9,001.35 9,181.99 W-35 6/16/07 BPS 1,963. 10,437. 1,962.98 9,067.52 W-35 9/29/07 BPP 1,963. 10,437. 1,962.98 9,067.52 W-35 4/8/08 BPP 1,963. 10,437. 1,962.98 9,067.52 W-35 4/9/08 BPS 1,963. 10,437. 1,962.98 9,067.52 W-35 4/29/08 BPS 1,957. 10,312. 1,956.98 8,965.79 W-35 6/9/08 BPP 1,957. 10,312. 1,956.98 8,965.79 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE '~ • ~~; .•i ~~s :~~ To: Clark Olsen/Jerry Bixby, GPB Well Ops TL From: Dan Robertson, Area PE Kirsten Schultz, Engineering Intern • Date: 07/24/2008 Subject: W-35 Tubing Punch Est. Cost: $30 M PBWPDWL35-R IOR: 350 BOPD This procedure includes only one step as it has already been drifted multiple times recently during fishing operations. Type Operation 1. E Tubing punch tailpipe below packer, above WRP fish Current Status: Shut in WAG injector Max Deviation: 44 degrees at 8800' MD Min. ID: 3.725" @ 9591' (4 'h " OTIS XN NIPPLE) Last TD tags: 06/29/2008 Pushed 4'/2"WRP down hole from 9507' SLM TO 9554' Last Downhole Ops: 06/29/2008 Pushed 4'/2"WRP down hole from 9507' SLM TO 9554' Latest H2S level: N/A (injector) Objective: 1. The objective of this procedure is to punch holes in middle of the full joint above the fish in the XN nipple to allow water and MI injection. Notes: WAG injection well W-35 is currently shut in due to a wireline retrievable plug stuck at the XN nipple. There have been multiple unsuccessful attempts to fish this plug. The fishing neck is now broken making it even more difficult to fish. It is planned to punch holes in the tubing tail above the fish to allow resumption of injection. If you have any questions or comments regarding this procedure, please call Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C). cc: w/a: Well File Procedure• E-line: C ^ Note: The well was drifted multiple times while fishing. No additional drift is required. 1. RU E-line. RIH with 5' x 1 11/16" diameter tubing punch gun loaded at 4 spf with 20-DL tubing punch charges. EHD=0.37" 2. Correlate to AWS 8/7/94 GR/CCL jewelry log, perform tubing punch. 3. When tubing punches are complete, POH and RD. Return to MI injection. Tubing Tallies: ~ • ' nrL~c s~_~14Y ' ~xa¢; :1 3_r ~5.~~~ i Fig _, .C. nn~ct: .5/~C~r~- .Tr ~ •:k7i li!.l:G.• 33a~n. 1T.i K4N. ;7 • . F .f r4 W':. .. - °r rr_~ =~~i, ~f~',_~: =r max. . ili.3f t°: vt~i L45f US1G" ST$=h'ri ~ !' ~ ` .. - - ~ . _ •_ ___~ ITEJi - G,tr~~r: 1~5' ~r~;~.: 7: ~:ESSP:P^_ J / :ff ;Rlfl. ~ r:. ,,, ... ~3 ~ . ~' Si,'pf~Y~ 4 ~~.. .h~_P //nu+ h._ <af,y ~.:> 5'r? r.-s./ ~d~rL. ...... .. °1. r5} . ~}~'~ .. - _ t%I,~••s.r.~~-2,cY[°S LdL1 Y r?~.~olc _.. - r.~~ . "I,S'a 8„a.i _. .. ~J .Y y enN .-~'+- " _ + ,,55 Y ~JrJ ."!r l r+'JJC z ~.!! ~T19.l3.~. . ~ . , " i~-•".y.J. 'Z.~.~+'/ rf r•.• r.r~:~. "['.T? ~TYff~•a h~s 2icr. ~Sy~ ._. Te ~,r rr~ ~ CI.J• _ _ .J/•¢~• . (( _• _':'C7J.7d.~1"2bJdQtO"J.V/ /.~ ' _ .. f `l' ~ f .i" -. 'rA..~x , ;r Y~raay -_ .:~~ u~oxe~ rs,~ v%~ .... •r ... ~, X11 .. >`'f -7 {' ..._. :[• •s' n,~. ~~ _.. ._. i• ...~ 1'~J }'~ '~ ~:.SG ,~~•8 I / ~ ° .~ ~Jf~ r~~d .'-.VGrd?',.s~fe,~ ' %'i? Y~ ~' '.T" fA.J'l • rld_5Y; i' ,~ rYh Y•` '~Y„„•~ _ L• sr> .+.1N_m./ -.J•r.s 4'%~~ :'C r: :+i'a'ry ._, .- 74f.N~ ?g.Z,T.7.3 -~ ~-' •~r- ~ • +l.:J r`•v+: ~ f ~ :0..3'? =r,~y- ' - 1-fY:.~B,t.!.gd J.7s Yi:~ .f• ~ 'frfJ r 24v (,l~ -.:SK ~ ~ cJr3'.?~ _°l ~-" _ 7r"3.J~ Y~ + + r_ ,r _ 1!J' !'~:,~7r _ - I f0•y5' •-~ J ~~.~.~. - ' _. ._ - ~ r ,`~~,~ r. rr !t.• f/ Li• ll. ",.,.. ,T ___ •'~, J,Oa~ 7'/.! ;y ~G 1 ~ + ~f~ f: ~ f .'~G. (r~ '•~7?+S 1'S ,'+/i11 nJ r, L-9P,~-'iJM :_1 -~' (J•rJ f6'~ t 9r • ff.eY~-- t7 fG! rl9 'fly T'la;a~1 _.._ .. ~ --r .. . ~ • ~ rf y'• • ~ l% _ .__f _ R ~ ~ ~ ~r•'.F -. . ~'f~• * r - ~ ..,t-st,.-0M'~r k{ ... ~..'J~~`' // ~ •-~~l•~' ... • --r. - - ~~ .. ..._ r TUB=t;G $!<7?~O~LtiRY _ ft~ - 3 .S JTS ON PACK, ,~,~ JT5 RAV, FT QN RACK. ~/,„~f FT R~2.1, i.dCT !'ASTVf: STRTW: 0 ~• UATE: ~~~~8~ _ KB 1~ JTS OCT, ~,#• F i OUT , LT LTF'{ LEN6TFt T4P BpTTpM RE$GRI~:IO:: .- 7 f,) ' 7"L ~J~ ~ fG ~ ~ ~ ~~~7„S~ ~r ~r .l f ~ _ _ SJ .~ J ~J. li S~ 1 _ ~ ._. ~1 U af'~ ,~ ~ i. -; ..._. ' -.~ . . ' ~ .~ Weli: W-35 Date : .............................07/23/08 Cost Est: $30M .............................................................................. CC or AFE: PBWPDWL35-C • • Tubing Punch PROCEDURE ~e~,.z,Re~,o~2,/0, API #: 50-029-21799-00 ................................................... ........... Prod Engr Dan Robertson Office Ph: 5645546 H2S Level: Home Ph :...........................346.3714,,,,,,,,,,,,,,,,,,,,,.,,... WA (injector) Cell/Pager: 529-5818 ............................................................................. WBL Entries IOR Type Work Desciption 1 .................350 i................E 'tubing..l?.unch...................................................................................................................................................................................... Well Objectives and Notes: The purpose of this procedure is to punch holes in the full joint above the fish in the XN nipple to allow continued injection. Add 5' of .37' tubing holes using 20-DL tubing punch chargers at 4 shots per foot. Attachment: total ,5 Requested Gun Size: 1 "/,6" (OD), 5' (length) Charge: 20-DL Is Drawdown Necessary/Desired/Unnecessary During Pertorating N/A Preferred Amount of DrawdowNSuggestions to Achieve Drawdown N/A . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . last Tag: .9:507 ff MD on ,6/29/2008 Est Res. Pres. ~ ..,..,...10;092 MD is ,,,,,,,,,,,,,,,, .3444. psi from 04!15/04 RST Perforation Summary Summary Dist Well: W-35 Town: Date: API#: 50-029-21799-00 Prod Engr: Anch Prod Engr ...................................................................... P.D. Center PBTD General Comments: Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf TREE= 4-1/16" CMI i W-35 SAFET TES: WELLHEAD= MCEVOY ACTUATOR = BAKER C KB. ELEV = 90.88' BF. ELEV - 54.33' KOP = 3200' Max Angle = 44 @ 8800' Datum MD = 10218' Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" @ 9591' 4-1 /2" OTIS XN NIPPLE Q 1983' -{4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2924 2833 5 OTIS DMY RA 0 08/25/02 7 5715 5248 37 OTIS DMY RA 0 08/25/02 6 6691 6045 35 OTIS DMY RA 0 5 7233 6494 34 OTIS DMY RA 0 4 7696 6877 34 OTIS DMY RA 0 3 8357 7409 40 OTIS DMY RA 0 2 9179 8014 43 OTIS DMY RA 0 1 9327 8123 43 OTIS DMY RA 0 9437' ~~ 4-1 /2" OTIS SLD SLV, ID = ? { 9498' ~{4-1/2" TBG SEAL ASSY I 9498' H 9-5/8" x 4-1/2" TMJ HBBP-R PKR, ID = 4.0" 9558' 4-1 /2" OTIS X NIP, ID = 3.813" ~ 9591' 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 9623' 9623' 4-1/2" TBG TAIL, ID = 3.958" TOP OF 7" LNR 9653' 9628 ELMD TT LOGGED 08/07/94 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 05/01/88 ANGLE AT TOP PERF: 34 @ 10513' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 5" 5 10312 - 10348 S 04/29/95 3-3/8" 6 10316 - 10338 O 06/08/95 3-3/8" 6 10338 - 10346 S 04/29/95 3-3/8" 6 10346 - 10352 O 05/05/95 3-3/8" 6 10364 - 10380 O 05/05/95 3-3/8" 4 10400 - 10420 S 04/29/95 3-3/8" 4 10430 - 10437 S 04/29/95 PBTD 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" ( 10577' 1 10017' - j MARKER JOINT FISH - 4-1/2" TEL FINGER (12/13/06) 10303' FISH - PKR RUBBER DATE REV BY COMMENTS DATE REV BY COMMENTS 05/05/88 GRV ORIGINAL COMPLETION 09/08/01 RN/TP CORRECTIONS 08/30/02 DTR/TP GASLIFT C/O 10/20/02 PP/KAK PERF CORRECTIONS 12/14/06 ???/TLH FISH (TEL FINGER) 05/31/08 FLS/PJC ACTUATOR/ GLV CORRECTION PRUDHOE BAY UNIT WELL: W-35 PERMfr No: "'1880330 API No: 50-029-21799-00 SEC 21, T11 N, R12E, 1251' SNL & 1451' WEL BP Exploration (Alaska) . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.L Supervisor ....---.-, 1-:'/ L '\&1 b{ t 07 r - DATE: Friday, Ì\;!ay 11,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATJO:-; (ALASKA) [;\IC \V-35 o~? C'fJ e& ~ \ FROM: Bob Noble Petroleum Inspector PRüDHOE BAY UNIT W -35 Src: Inspector Reviewed By: p.r. Suprv :ß'J!--- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT W-35 Insp Num: mitRCN070507080047 ReI Insp Num: API Well Number: 50-029-21799-00-00 Permit Number: 188-033-0 Inspector Name: Bob Noble Inspection Date: 5í6í2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I I I ~- 4000 I 3940 I 3910 .~ ]5'T --- ]5 ]5 i - ' - ~ I lí60 : 1760 i ]760 - Well ,-- W-35 ·,Type Inj. I W TVD ' 8340 ,lA' 1 440 i . I : P.T.D' 1880330 ]TypeTest ¡ SPT Test psi I 2085" i OA I ]5 Interval 4YRTST P/F P ¡/ Tubing I 1760 --- . Notes: SCANNED JUN 0 6 2007 Friday, May 11, 2007 Page 1 of 1 Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth f )- c... v.l 1 'lSis' -033 4=t {L(f)L(1- 02/22/2007 NO. 4158 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# LOQ Description Date BL Color CD MPS-33A 11676926 CH EDIT USIT (PDC-GR) 01/31/07 1 1 W-35 11486088 RST 12/15/06 1 1 J-02B 10964121 RST 01/26/05 1 1 C-36A 11209600 MCNL 04/24/06 1 1 04-38 . 11477734 RST 12/02/06 1 1 A-05A N/A USIT (CEMENT EVALUATION) 01/09/07 1 A-05A 11626272 USIT (CEMENT EVALUATION) 01/30/07 1 . .-.... . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 SCANNED APR 0 3..2007 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: '1AR 2 Ä Z007 Oil if! G¡:¡s Com:. C;ormni§3íon j Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9.950. '-"~.'.....I ATTN: Beth . ~\ ;' Received by: (1 j 'IL- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrichz3 z3~x~,/.~j.j~.~//~.~ DATE: May 6, 2003 Commissioner THRU' Jim Regg P.I. Supervisor FROM' John Crisp Petroleum Inspector /1,~'~ SUBJECT: Mechanical Integrity Tests BPX PBU WOA-EOA Prudhoe Bay Prudhoe Bay Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I A-27A I Typelnj. I G I T.v.D.I 8317 I Tubingl 820 I~o I~o I~o I,nt~rv~,l P.T.D.I 1982350 ITypetestl P ITestpsil 3500 ICasingI 0 I 35101 3500l 35001 P/F Notes: OA increased F/0 to 100 psi. during test. This test is prior to MI being injected. 8 BBL. Pumped. w~,,I w-~ IT~.e,~i.I N I T.V.O.I ~ I Tu~in~l o I o I o I o I,nterva, I ~ P.T.D.I 2020660 ITypetestl P I Testpsil 1500 1CasingI 280 I 1610 I 1525 I 1485I P/FIE Notes: OA remained @ 280 psi during test. 7 BBL's pumped for test. We,,I w-~s I~YPe,,i.I ~ I T.V.D. I~ I Tu~,,~I2~0 12~0 12~0 12~0 I,,,~,1 P.T.D.I 1880330 ITypetestl P Imestpsil 3510 I CasingI 600 I 35101 35251 35401 P/F Notes: OA remained 0 during test. Gauge was removed F/OA & 0 Positive was confirmed. WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER IN J, 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 Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 3 Attachments: Number of Failures: 0 Total Time during tests: 8 hrs. CC: MIT report form 5/12/00 L.G. ~CANNEC', ~JU[. 1 6 2003 MIT BPX PBU 05-06-03 JC.xls 5/12/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us ~?OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP; AOGCC R_EP: <y,~/~) ~) ~ W Well IW-35 P.T.D.I 1880330 Notes: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / W 05/06/03 JOHN CUBBON JOHN CRISP I Packer Depths (ft.) ~ Pretest Inil~al 15 Min. 30 Min. ITy"e'nj-I~ I MDrtV~l ~'""~'1 8'3391 Tubingl 27201 27701 27801 27101 Intervat I I TypetestI P I Test psil 20851 I Casin~l 6001 35101 35251 354O1 P/FI P Type Inj. Type Inj. Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Well P.T.D. Notes: Type Inj. Type Inj. Test Details: Initial MITIA post MI injection startup. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test IN~RVAL C~es Initial Test 4 = Four Year ~cle = Required by Variance = Test during Workover = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU W-35 05-06-03.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _ CONVERSION - WAG INJECTOR Pull tubing _ Alter casing _ Repair well_ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1250' FNL, 1451' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 2462' FNL, 5166' FEL, Sec. 21, T11N, R12E, UM At effective depth 2432' FNL, 177' FEL, Sec. 20, T11N, R12E, UM At total depth 2432' FNL, 203' FEL, Sec. 20, T11N, R12E, UM 5. Type of Well: Development __ Explorato~__ Strat~graph~c__ Service__X (asp's 611789, 5959003) (asp's 608095, 5957737) (asp's 607804, 5957762) (asp's 607778, 5957762) 6. Datum elevation (DF or KB feet) RKB 91 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-35 9. Permit number / approval number 188-033 / 302-284 10. APl number 50-029-21799-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2623' Intermediate 9864' Liner 967' 10620 feet Plugs (measured) 9216 feet 10577 feet Junk (measured) 9182 feet Packer Rubber @ 10303' left by CTU (11/17/96) Size Cemented Measured Depth True Vertical Depth 20" 72 c.f. Concrete 147' 147' 13-3/8" 3844 c.f. 2660' 2660' 9-5/8" 2040 c.f. 9901' 8642' 7" 347 c.f. 9653' - 10620' 8454' - 9215' Perforation depth: measured true vertical 'ubing (size, grade, and measured depth) Open Peds 10316'-10338',10346'~10352',10364'-10380' Sqzd Peds 10312'-10316',10338'-10346',10400'-10420',10430'-10437' Open Peds 8969'-8987',8993'-8998',9008'~9021' Sqzd Peds 8966'-8969',8987'-8993',9037'-9054',9062'-9068' 4-1/2",12.6#,L-80 Tubing @ 9498' MD. 4-1/2"12.6# L-80 Tubing Tail @ 9623' MD. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer @ 9498'. 4-1/2" Otis SSSV Nipple @ 1983' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure .... 14. Representative Daily Average Production or Inlecbon ~"ata' ~" "- ..... OiI-Bbl Gas-Mcr Water-Bbl Ca~g ~r~s~ufa'*;~C~Tubing Pressure Prior to well operation 01/03/2003 SHUT-IN Subsequent to operation 02/21/2003 SHUT-IN 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas __ Suspended __ Service WAG INJECTOR DeWar/ne R. Schnorr Form 10-404 Rev 06/15/88 2~ Date February 21,2003 Prepared b)/DeWar/ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 08/24/2002 08/25/2002 O8/25/2OO2 08/26/2OO2 O8/26/2OO2 O8/27/2002 08/30/2002 08/31/2002 09/01/2002 12/08/2002 01/04/2003 02/20/2003 O8/24/02 O8/25~O2 O8/25/O2 08/26/02 08/26/02 W-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM (AC-EVAL AND (AC-EVAL AND (AC-EVAL AN D (AC-EVAL AND (AC-EVAL AND (AC-EVAL AND (AC-EVAL AND REPAIR): GAS LIFT--TO DUMMY VALVES REPAIR): DRIFT/TAG; GAS LIFT--FOR RATE; REPAIR): LOAD WELL TO SECURE; MIT-IA REPAIR): DRIFT/TAG; GAS LIFT--TO DUMMY REPAIR): AC-EVAL; AC-WELLHEAD TESTING REPAIR): DRIFT/TAG; GAS LIFT--TO DUMMY REPAIR): AC-BLEED; AC-FLUID LEVEL ANN-COMM (AC-EVAL AND REPAIR): AC-MITIA T/I/O = 300/550/0. Monitor WHP's post MIT-IA. ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL FIRST DAY OF MI GAS INJECTION TESTEVENT --- IN.1ECTION PRESSURE, PSI: 0 TYPE: MI VOLUME: 0 EVENT SUMMARY DRIFT W/3.5" CENTRALIZER TO TD @ 10333' WLM (10356' CORRECTED). 24' OF FILL ABOVE DEEPEST OPEN PERFS. BAILER EMPTY. SET CATCHER. IN PULL STA 8... 1 1/2 LGLV, RA. PULL STA 7... 1 1/20GLV, RA. SET STA 8... 1 1/2 DGLV, RA. PUMP 277 BLS INHIBITED SEAWATER, 136 BBLS METH. SET STA 7... 1 1/2 DGLV, RA. PUMPED 25 BBLS METH WITHOUT PRESSURING UP. RUN IN TO TAP DOWN ON DGLV's IN STA #7 & #8. MIT-IA INCOMPLETE. CAME BACK W/VALVE FROM STA #8. SET I 1/2" DGLV & RA IN STA #8. IN PROGRESS. FOUND LOCK DOWN BOLTS ON TBG AND IA LEAKING SLIGHTLY. CAMERON CAME OUT. TIGHTENED BOLTS / SEALS. TESTED SEAL TBG-IA TO 5000 PSI. PASSED. COULD NOT GET TEST ON IA-CA SEAL. LOAD IA W/FLUID THEN PRESSURE TEST. ATTEMPT TO PULL CATCHER FROM XNLN. BALLED 2 GALLONS OF PLASTIC & SAND. IN PROGRESS. PPPOT-T PASSED. WELLHEAD DESCRIPTION: McEVOY SSH SYSTEM. 13-5/8 x 4-1/8 5000 (5) SEAL ADAPER / 4-?" (5) SEAL HANGER. WlRELINE CREW NOTICED GLAND NUTS FOR LOCKSCREWS ON TUBING HANGER FLANGE WERE LEAKING. OPENED BLEEDER SCREW FOR TUBING HANGER VOID, PRESSURE WOULD NOT BLEED OFF. TIGHTENED ALL LOCKSCREWS ON TUBING SPOOL TO RE-ENERGIZE BODY SEAL, LOCKSCREWS WERE LOOSE. OPENED BLEEDER SCREW FOR VOID, PRESSURE BLED OFF. TIGHTENED GLAND NUSTS ON TUBING SPOOL, ALL WERE LOOSE. PRESSUREED UP TO 5000 PSI ON TUBING HANGER VOID AND SEALS. HELD TEST FOR 30 MINUTES, NO PRESSURE LOSS. Page I W-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/26/02 (continued) TUBING HANGER VOID AND SEALS TESTED GOOD. OPENED BLEEDER SCREW FOR 9-5/8 PACK-OFF VOID, PRESSURE WOULD NOT BLEED OFF. TIGHTENED LOCKSCREWS ON CASING HEAD TO RE-ENERGIZE BODY SEAL. OPENED BLEEDER SCREW FOR VOID, PRESSURE WOULD STILL NOT BLEED CHECKED PACKING BLEEDER FOR PRESSURE, PRESSURE ON PACKING VOID. UNABLE TO RE-ENERGIZE Y-SEAL. TIGHTENED ALL GLAND NUTS ON CASING HEAD. 08/27/02 PULLED CATCHER. RETURNED WELL TO OPER FOR PROD. 08/30/02 T/I/O = 300/1160/0. TEMP = 887. IA FL AND BLEED IA. (INJECTOR CONVERSION). IA FL @ 240' (13 BBLS). BLED IA FROM 1160 PSI TO 400 PSI IN 2 HOURS. BLED MOSTLY GAS AND SOME FLUID. MONITORED lAP FOR 30 MINUTES. lAP INCREASED TO 500 PSI. AL GATE VALVE APPEARS TO BE LEAKING. HAD PAD OPERATOR SHUT-IN AL AT SKID. BLED IA AND AL LINE TO 350 PSI IN 1.5 HOURS. FLUID TO SURFACE. SI BLEED AND MONITORED FOR 30 MINUTES. lAP INCREASED TO 440 PSi (AL LINE PRESSURE). CALLED GREASE CREW TO SERVICE AL GATE VALVE. FINAL WHP's = 300/440/0. 08/31/02 MIT-IA TO 2200 PSI PASSED. (INJECTOR CONVERSION.) 09/01/02 T/I/O = 300/550/0. MONITOR WHP's POST MIT-IA. 12/08/02 T/I/O= SI/280/0. IA FL @ 558' (30 BBLS). (PRE MIT IA). 01/04/2003 FTRST DAY OF MI GAS IN3ECTION 02/20/03 TESTEVENT--- INJECTION PRESSURE, PSI: 0 TYPE MI VOLUME: 0 Fluids Pumped BBLS 162 NEAT METHANOL 277 INHIBITED SEA WATER 439 TOTAL Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Conversion from Prod to WAG Inj Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Conversion fl PROD to WAG INJ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1250' FNL, 1451' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 2462' FNL, 5166' FEL, Sec. 21, T11 N, R12E, UM At effective depth 2432' FNL, 177' FEL, Sec. 20, T11N, R12E, UM At total depth 2432' FNL, 203' FEL, Sec. 20 T11N, R12E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 611789, 5959003) (asp's 608095, 5957737) (asp's 607804, 5957762) (asp's 607778, 5957762) 6. Datum elevation (DF or KB feet) RKB 90.9 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-35 9. Permit number / approval number 188-033 10. APl number 50-029-21799-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2623' Intermediate 9864' Liner 967' 10620 feet Plugs (rr~easured) 9216 feet 10577 feet Junk (measured) Packer Rubber @ 10303' left by CTU (11/17/96) 9182 feet Size Cemented Measured Depth True vertical Depth 20" 72 c.f. concrete 147' 147' 13-3/8" 3844 c.f. 2660' 2660' 9-5/8" 2040 c.f. 9901' 8642' 7" 347 c.f. 9653' - 10620' 8454' - 9215' Perforation depth: measured Open Perfs 10316' - 10338', 10346' - 10352', 10364' - 10380' Sqzd Perfs 10312'- 10316', 10338'- 10346', 10400'- 10420', 1043'0'/.-_'10437' ~ true vertical Open Perfs 8969'-8987', 8993'-8998', 9008'-9021' Sqzd Perfs 8966'-8969', 8987'-8993', 9037'-9054', 9062'-9068' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 TBG to 9498' MD. Tubing Tail @ 9623'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer set @ 9498' ~D. 4-1/2" Otis SSSV Nipple @ 1983' MD. 13. Attachments Description summary of proposal __X 14. Estimated date for commencing operation October 2002 16. If proposal was verbally approved Name of approver Date approved Detailed operations program __ BOP sketch _ 15. Status of well classification as: Oil __ Gas __ Suspended _ Service WAG Injection Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Amy Frankenburcj Questions? Call Amy Frankenburg @ 564-4503. Title: Prudhoe Bay Petroleum Engineer FOR COMMISSION USE ONLY Date August 251 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Plug integrity __ ~B~DP Test__ Location clearance __ ,-J Ii Mechanical Integrity Test -i-~,. Subsequent form required 10- V'~'~J )~,~O;NAL SIGNED BY Approved by order of the Commission -~ T~vlor Se~mcltlnf Commissioner , CANNED NOV ! 21392 Form 10-403 Rev 06/15/88 · Approval SUBMIT IN TRIPLICATE bp BP Exploration (Alaska), Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 4 September 02 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry notice for W-35 swap from producer to WAG injection BP Exploration Alaska, Inc proposes the following wellwork to prepare to swap W-35 from production to WAG (water alternating gas) injection with MI start-up estimated to occur in November, 2002. MITIA (witnessed by AOGCC) W-35 is currently producing 350 BOPD. It will be tied in as a WAG injector (beginning with a slug of MI) in November 2002. A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions ' Sincerely, Amy Frankenburi~~~- EWE Production Engineer ACF (9/4/2002) 1 of I SCANNED NOV 1 ~ 2002 TREE'= 4-1/16" ClW WR LI-EAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 90.88' BF. ELEV = 54.33' KOP = 3200' Max Angle = 44 @ 8800' Datum MD = 10218' Datum TVD = 8800' SS W-35 SAFETY NOTES: 1983' H4-1/2" OTIS SSSV I"iP, ID = 3-813"I GAS LIFT MAI',DRELS I 13-3/8"C, SG, 68#, L-80,1D=12.415" H 2662' IMinimum ID = 3.725" @ 9591' I 4-1/2" OTIS XN NIPPLE 9437' H4-1/2" OTIS SLIDING SLEEVE I 4-1/2"TBG, 12.6~, L-80, 0.0152 bpf, D =3.958" H 9623' I TOPOF7" LNR H 9653' I 9-5/8" CSG, 47#, L-80, ID =8.681" H 9901' PERFORATION SUMMARY REF LOG: BHCS ON 05/01/'88 ANGLE AT TOPPERF: 34 @ 10513' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 5" 5 10312 - 10348 S 04129195 3-3/8" 6 10316 - 10338 O 06108195 3-3/8" 6 10346 - 10352 O 05105195 3-3/8" 6 10364 - 1 0380 O 05105195 3-3/I~' 4 1 0400 - 1 0420 S 04129195 3-3/8" 4 1 0430 - 1 0437 S 04129195 J PBTD H 7" LNR, 2F:~, L-80, 0.0383 bpf, ID = 6.276" H 10577' 10620' 9498' 9498' 9558' 9591' 9623' I 9628' J 10303' H4-1/2" TBG SEAL ASSY j 4-1/Z' TIWI-IBBP-RPKI~ ID=4.0" J H4-1/2" OTISXNIP, ID= 3.813" J H4-1/2" OTIS XN NP, ID = 3.725" H4-1/2" TBG TAIL, ID = 3.958" 1 HELMD'I-I' LOGGIa) 08107/94 J HMARKER JOINT J HPKR RUBBER I DATE REV BY COtvWIENTS DATE REV BY COMErr_NTS 05/05188 GRV ORIGINAL COIVPI_EF~ 02/15101 SIS-QAA CONVERTED TO CANVAS 03/05/01 SIS-LG FINAL 09/08/01 RN/I'P CORRECTIONS 08/30102 D'IPJIP GASLIFT C/O PRUDHOE BAY UNIT WELl' W-35 PERMIT No: 1880330 APl No: 50-029-21799-00 SEC21, Tll N, R12E BP Exploration (Alas ka) SCANNFi3 Nnv 1 ¢. Pr~CHANICAL iNlqEGItITT R_E?ORT ' W~_LL DATA inet' V" 9,,,'94' -ubing: ~- ~ Packer q(~g'~ T'q-D; Set at iNTEGRiTY - P.~_RT ~! Annulus Press Test: v_? ; !5 rain ; 30 min iNTEGRITY - PART ~2 . Cement Bond Log (Yes or No) '~ .; In AOGCC File LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 Run ECC No. 5830.03 6031.05 6245.05 6251.03 Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: Please sign and r. eturn ~; Petrotechnical. Data Cente~ BP Exploration (Alaska) 900 East Benson Boulevar~ Received by JUN 1 6 1995 Alaska Oil & Gas O~s, LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP W-35 (12-21-11-12) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE +'LIS Date: RE: 9 June 1995 Transmittal of Data ECC #: 6251.02 Sent by: PRIORITY MAIL Data: LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: P:].ease sign and ~'etur,n Petrotechnieal Data Cente=, BP_E~Exploration (Alaska) _9QO~ast Benson Boulevard ~¢.~~~.I ..~. Alaska, 99508, .... ~---~R~'eive~ by- - ~ L Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 CCL/PERF FINAL BL+RF 1 CN/GR FINAL BL+RF ECC No. Run # 1 3901.02 Run # 1 5832.03 Run # 1 6251.02 Please sign and return'to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s~gn and t~um Fe~rotechni~al Data BP Exploration (Alaska) Ino 900 East Benson Boulevard JUN 0 8 1995 Oi~ & G~s Cons. Commissio~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~-z-~ ~-0~-~-~.~ E-13 (01-11-13) E-13 (01-11-13) Q-O1 (24-09-11-13) DESCRIPTION PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF CCL/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 3916.02 Run # 1 Run # 1 5955.05 Run # 1 5955.06 Run # 1 6078.03 Run # 1 6251.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: ~.~.~ .~ .~ ,~ ~, E C E IV E D Petro.technioml Da'ts. Cen~F BP ExploratiOn (Alaska) I~Y 1 2 1995 $00 Ees~Benson ~ulev~ ~chor~~~ka ',~~011 & Gas O~s. Commission R~ceived by ' Alaska 011 & Gas sion Anchorage '" ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 August 1994 RE: , Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL H-06 (43-21-11-13) DESCRIPTION 1 PL/PROFILE FINAL BL 1 PL/PROFILE RF SEPIA ECC No. Run # I 4930.01 Run # 1 ~'~ '~ W-20 1 PL/TURBSPNR FINAL BL Run # 1 6252.00 1 PL/PROFILE FINAL BL Run # 1 1 PL/TURBSPNR RF SEPIA Run # 1 1 PL/PROFILE RF SEPIA Run # 1 1 GR/CCL JEWL.FINAL BL Run # 1 1 PLS FINAL RF SEPIA Run # 1 1 GR/CCL JEWL.RF SEPIA Run # 1 ~O--{~) C-16 (30-11-14) 1 PL/SPNR FINAL BL 1 PL/SPNR RF SEPIA 7 ~-P~ x-01 (14-5-10-14) Run # 1 868.01 Run # 1 Run # 1 3986.03 Run # 1 1 PLS LEAKDET.FINAL BL 1 PLS LEAKDET.RF SEPIA &~--7~ J-01 (09-11-13) 1 CN/G~ FINAL BL Run # 1 3987.02 1 CN/GR FINAL RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK~ 99518 ~ttn. Rod~y/~. Paulson Please s!En and return to: ~. / /// ec iv d b · / / ~ Date- pe~rote_~__9, _ ~: _ . ~ / /// ~~ Date: 900 East Benson Boulevard / / ~cnorage, ~as~ ~908 / Received b ';~ ...... Date BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: FROM: SUBJECT: DISTRIBUTION Information Control Well Records LR2-1 BP CASED HOLE FINALS Date:04/30/91 T#:82383 Enclosed is your copy of the material listed below, if you have any questions, please contact BP Well Records at (907) 564-~,~.~.5. "J-16 "M-28 "Q-04 Prod-F 04/12/91 #1 9560-10610 Camco 5" Gas Entry 04/09/91 #1 9350-9740 Camco 5" PITS 04/15/91 #1 8700-8930 Camco 5" P rod-F 04/14/91 #1 9350-9610 Camco 5" Prod-F 04/12/91 # 1 10200-10516 Camco 5" Gas Lift 04/11/91 #1 3000-13138 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES 1, Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. LOcation of well at surface 1251' SNL, 1451' WEL, SEC,. 21, T11N, R12E, UPM At top of productive interval 2462°SNL, 113'EWL, SEC,. 21, T11N, R12E, UPM At effective depth 2449' SNL, 168' WEL, SEC,. 20, T11N, R12E, UPM At total depth 2448'SNL, 194' WEL, SEC. 20, T11N, R12E, UPM 2. Present well condition summary Total depth: . ""-'~' STATE OF ALASKA ~'~' . r [ AL .... ~A OIL AND GAS CONSERVATION COMMIS~....,N ~ ~ ~ ['~- REPORT OF SUNDRY WELL OPERATIONS Stimulate ~ Plugging Perforate Other Alter casing. Repair well . Type of Well: Development X Exploratory Stratigraphic Service RECEIVED FEB 1 § 1991 Alaska 0il & Gas Cons. C0mmissi01 Anchorage measured true vertical 10620feet Plugs (measured) BKB 9215feet 6. Datum elevation (DF or KB) KBE = 90. 77 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-35 (12-21-I 1-12) PBU 9. Permit number/approval number 88-33/ 10. APl number 50- 029-21799 ~11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 10577feet Junk (measured) BKB 9181feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth · .. 110 20 8 c.y. 147 2623 13 3/8 3844 c.f. 2660 9864 9 5/8 2040 c.f. 9901 .. 967 7 347 c.f, 9653-10620 10312'-10348', I0365'-10375', 10400'- 10420', 10439'- 10437' True vertical depth BKB 147 2660 8642 8454-9215 true vertical subsea 8875'-8980' (four intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9519' with 4 1/2" tailpipe to 9623' Packers and SSSV (type and measured depth) 9 5/8" TIW "HBBP"packer at 9519'; 4 1/2" SSSV at 1983' !3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1¸4, Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1870 6216 1200 0 481 Subsequent to operation 2330 6671 1266 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations. Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ 0-404-~R~ Title Supervisor Peripheral& EOA ~Form 1 538 Service Date SUBMIT IN DUPLICATE WELL W-3g (12-21-11-12] PBU ADDtL. PERFORATION OPERATION We perforated the following intervals on July 7, 1990: -~ 10400' - 10420' MD BKB · 10430' - 10437' MD BKB 9/10/90 mtp STATE OF ALASKA KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate x Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1251' SNL, 1451' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2462'SNL, 113'EWL, SEC. 21, T11N, R12E, UPM At effective depth 2449' SNL, 168' WEL, SEC. 20, T11N, R12E, UPM At total depth 2448' SNL, 194' WEL, SEC. 20, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10620feet true vertical BKB 9215feet 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 90. 77 AMSL feet 7. Unit or Property name Prudhoe Bay Unit Plugs (measured) 8. Well number W-35 (12-21-11-12) PBU 9. Permit number/approval number 88-33 / 90-574 10. APl number 50- 029-21799 Effective depth: measured 10577feet true vertical BKB 9181feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth · .. 110 20 8 c.y. 147 2623 13 3/8 3844 c.f. 2660 9864 9 5/8 2040 c.f. 9901 .. 967 7 347 c.f. 9653-10620 10312'-10348', 10365'-10375', 10400'- 10420', 10439'- 10437' True vertical depth BKB 147 266O 8642 8454-9215 true vertical subsea 8875'-8980' (four intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9519' with 4 1/2" tailpipe to 9623' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. 11. Field/Pool ' Prudhoe Oil Pool 9 5/8" TIW "HBBP"packerat 9519'; 4 1/2" SSSVat 1983' -!'.ii~ .ii': ,i ' ~ ,,. Prior to well operation Subsequent to operation i ' Reoresentative Daily Averaoe Production or Iniection Data' ' :';~:'' ? - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. AttaChments Copies of Logs and Surveys run Daily Report of Well Operations 1870 5416 0 712 268 2170 6089 1650 1093 319 Service 16. Status of well classification as: Oil X Gas Suspended Date SUBMIT IN DUPLICATE 17. I hereby ~tjfy that the f~;~r~oing is true and correct to the best of my knowledge. Signed'~'" "~- ~ ~ ~[/,~t ~, Title Supervisor Peripheral& EOA Form 10-404 Rev 06/15/88 WELL W-35 (12-21-11-12~ PBU ADD'L, PERFORATION OPERATION We perforated the following intervals on July 7, 1990: 10400' - 10420' MD BKB 10430' - 10437' MD BKB 9/10/90 mtp BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anctlorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION D ate: 08/01/90 T#:81370 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLI~ FINALS · Enclosed is your copy of the matedai listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. J'S-27 CET 07/29/90 #1 10378-1" 1214 SCH v'S-27 CBT 07/29/90 #1 10378-11194 SCH ~/W-35 PROD LOG 07/28/90 #1 10200-10545 SCH ~/ X-24 COMPLETION 07/29/90 #1 8768-9227 SCH 5~ 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED AUG 3 0 7990 Alaska Oil & Gas Cons. Commission Anchorage '-;7T -~-'-'~ ~' ' ...... ~-~" STATE OF ALASKA .,KA OIL AND GAS CONSERVATION COMM~o...,.)N APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon ~ Suspend ~ Alter casing ~ Repair well. Change approved program ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Operation Shutdown Re-enter suspended well Plugging .. Time extension ~ Stimulate" 'Pull tubing ~ Variance Perforate x Other 5. Type of Well: 6. Datum elevation (DF or KB) Development X KBE- 90.77 AMSL feet Exploratory ~ Stratigraphic 7. Unit or Property name service__ Prudhoe Bay Unit 10620 feet Plugs (measured) 9215 feet 8. Well number W-35 (12-21-11-12) PBU 9. Permit number 88-33 10. APl number 50- 029-21799 4. Location of well at surface 1251' SNL, 1451' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2462' SNL, 113' EWL, SEC. 21, T11N, R12E, UPM At effective depth 2449' SNL, 168' WEI., SEC. 20, T11N, R12E, UPM At total depth 2448' SNL, 194' WEL, SEC. 20, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured 10577 feet Junk (measured) true Vertical BKB 9181 feet 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Measured depth Structural -- ' True vertical depth BKB Conductor 110 20 8 c.y. 147 Surface 2623 13 3/8 3844 c.f. 2660 Intermediate 9864 9 5/8 2040 c.f. 9901 147 2660 8642 Production Liner 967 7 347 c.f. 9653-10620 8454-9215 Perforation depth: measured 10312'-10348', 10365'-10375' true vertical subsea 8875'-8926' (two intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 9519' with 4 1/2" tailpipe to 9623' Packers and SSSV (type and measured depth) 9 5/8" TIW "HBBP"packer at 9519'; 4 1/2" SSSV at 1983' 13. Attachments Description summary of proposal 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Name of approver C. Chatterton 6/21/90 Date approved Detailed operations program BOP sketch 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~------_.~~ Title Supervisor Peripheral & EOA FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10-/YO ~-./' Original Signed By Approved by order of the Oommission David W. Johri¢~o~ [Approval ,o. ~O" _~F ~ Commissioner Form 10-403 Rev 06/15/88 Approved Copy SUBMIT IN TRIPLICATE WELL W-35 (12-21-11-12~ PBU ADD'L. PERFORATION PROPOSAl, We propose to perforate the following additional interval during July 1990: 10400' - 10420' MD BKB 10430' - 10437' MD BKB A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. Verbal approval from C. Chatterton 6/21/90 mtp FLOW TUBES & PACKOFF BOWEN PA :OFF l-~- HAND GREASE SEAL FLOWTUBE PUMP FLOWLI N E ~ FLOWLINE ~// VALVE GREASE LINE GREASE / MANIFOLD GREASE PUMP RISER ~- GREASE RESERVOIR BOP BP EXPLORATION BP Explorauon (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561~5111 TO: DISTRIBUTION Date :07/16/90 T#:81395 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedai listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~ S-30 CBT 07/11/90 #1 : 11352-12595 Sch 5" S-30 CET 07/11/90 #1 113~2-12626 Sch 5" S-30 PACKER SET 07/10/90 #1 11300-12180 Sch 5" W-35 COMP 07/11/90 #1 9400-10513 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RES~~ ATE OF A ARCHIVES RECEIVED JUL ;Alaska Oil & Cas uo~. Anchorago BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 02/23/90 Transmittal: 80921 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If questions, please contact BP Well Records at (907) 564-4445. G-14 PROD-F 02/14/90 #1 9200-9620 W-35 GAS LIFT 02/12/90 #1 690-10450 X-13 PROD-F 02/13/90 #1 200-10~51 X-19. SPINNER 02/11/90 ffl 9700-9804 .. you have any Camco 5" Camco 5" Camco 5" Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVQ~R--~ FEB ~ 81990 Alaska 011 & Ga9 Cons, Anchomg~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 12/19/89 Transmittal: 80691 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. '-If You questions, please contact BP Well Records at (907) 564-4445. have any W-35 PITS 11/30/89 #1 10175-16550 HRS R Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR .~TATE OF ALASKA DEC281 Standard Alaska /-~, Production Company 900 East Benson Boulevarc~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-35 (12-21-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File nA. Bragg ~ ager Production Engineering <ECEIVED .Oil .& Gas Cons. Commissiu~'~ '~ ~chomge A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1251' SNL, 1451' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2462'SNL, 113'EWL, SEC. 21, T11N, R12E, UPM At effective depth 2449' SNL, 168' WEL, SEC. 20, T11N, R12E, UPM At total depth 2448' SNL, 194' WEL, SEC. 20, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10620feet true vertical BKB 9215feet 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE =, 90. 77 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-35 (12-21-11-12) PBU 9. Permit number/approval number 88-33 / 8-950 10. APl number 50- 029-21799 11. Field/Pool Effective depth: measured 10577feet Junk (measured) true vertical BKB 9181feet Prudhoe Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented · .. 110 20 8 c.y. 2623 13 3/8 3844 c.f. 9864 9 5/8 2040 c.f. .. 967 7 347 c.f. 10312'-10348', 10365'-10375' Measured depth 147 2660 9901 9653-10620 True vertical depth BKB 147 266O 8642 8454-9215 true vertical subsea 8875'-8926' (two intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9519' with 4 1/2" tailpipe to 9623' Packers and SSSV (type and measured depth) 9 5/8" TIW "HBBP"packer at 9519'; 4 1/2" SSSV at 1983' 13. Stimulation or cement squeeze summary 14. see attachment Intervals treated (measured) Treatment description including volumes used and final pressure .:i;~aska 0il & Gas Cons, C0mrnissio~ Representative Daily Average Production or Iniection Data ::,2, finch0rage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1630 1681 12 0 275 Subsequent to operation 3763 3469 26 0 474 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the' best of my knowledge. Si~ned V~,4~ ,~~~~ Title Form 1~4 Rev 06/15,88 ~'~ Manager Production EngineeringSUBMITDateIN DUPLIOATE/' ~;~/' (~¢¢' WELL W-35 (12-21-11-12~ PBU STIMULATION OPERATIONS A mud acid breakdown treatment was performed 12/16/88 on the following perforated intervals in Well W-35. 10312' - 10348' MD BKB 10365' - 10375' MD BKB Prior to the breakdown job a bullheaded HC1/xylene tubing wash was performed. The following fluids was pumped in four stages, omitting the ballsealers from the final stage' a) c) d) 6000 gal. 12% HCI 5000 gal. 7.5%HC1 - 1.5% HF 5000 gal. 5%HCI - 0.8% HF 3600 gal. 5% HCI overflush 750 7/8" 1.1 SG ballsealers The treatment fluids were displaced to within 10 bbls. of the top perforations with 137 bbls. dead crude. The well was surged three times to knock the balls off the perforations, then the well was returned to production and tested. jm 1/25189 Standard Alaska ,~-"x Production Company 900 East Ben~on Boulevard P.O~ Box ~96612 AncJ~orag¢;~, \laska 99519-6612 (907) 561-b 11 STANDARD ALASKA P ODUCTION December 12, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-35 (12-21-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:Jk~4 Enclosures (6) cc: L. Burke (MB12-1) W-35 Well File anager Production Engi-' 'neering - I : A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well__ Plugging ~ Time extension ~ Stimulate X Change approved program __ Pull tubing __ Variance ~ Perforate ~ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Standard Alaska Production Company Development x KBE = 90. 77 AMSL feet Exploratory ~ 3. Address Stratigraphic~ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 service ~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1251' SNL, 1451' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2462'SNL, 113' EWL, SEC. 21, T11N, R12E, UPM At effective depth 2449' SNL, 168' WEL, SEC. 20, T11N, R12E, UPM At total depth 2448' SNL, 194' WEL, SEC. 20, T11N, R12E, UPM W-35 (12-21-11-12) PBU 9. Permit number 88-33 10. APl number 50- 029-21799 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. measured 10620 feet Plugs (measured) BKB 9215 feet 10577 feet Junk (measured) BKB 9181 feet Size Cemented · 20 8 c.y. 13 3/8 3844 c.f. 9 5/8 2040 c.f. 110 2623 9864 .. 967 7 10312'-10348', 10365'-10375' Measured depth True vertical depth BKB 147 147 266O 266O 9901 8642 347 c.f. 9653-10620 8454-9215 true vertical subsea 8875'-8926' (two intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9519' with 4 1/2" tailpipe to 9623' ~ '.'. . Packers and SSSV (type and measured depth) 9 5/8" TIW "HBBP"packer at 9519'; 4 1/2" SSSV at 1983' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved 15. Status of well classification as: Oil X Gas~ Suspended ~ Name of approver Date approved Service 17. I hereby certify that the foregoi% is true and correct to the best of my knowledge. Signed (~~ Title Manager Production Engineering Date/2.7- ' i~ss" ~/~ FOR COMMISSION USE ONLY Cond of approval: Notify Commission So representative may witness I Approval No. (:~.._ Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ~ Su'----bsequent form required 10- ~-© Approved Copy ORIGINAL SIGNED BY Retur. n~d Approved by order of the Commission LONNIE C. SMITH //~-~-~) Commissioner Date /:~Z I ./ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ,.,~' .WELL W-35 ~;TIMIdLATIQN PROPOSAL A mud acid breakdown treatment is proposed for the following perforated intervals in Well W-35. 10312' - 10348' MD BKB 10365' - 10375' MD BKB Prior to the breakdown job a bullheaded HC1/xylene tubing wash will be performed. The following fluids will be pumped in four stages, omitting the ballsealers from the final stage: a) b) c) d) e) 6000 gal. 12% HC1 5000 gal. 7.5%HC1 - 1.5% HF 5000 gal. 5%HC1 - 0.8% HF 3600 gal. 5% HC1 overflush 750 7/8" 1.1 SG ballsealers Displace the treatment to within 10 bbls. of the top perforation with dead crude. The well will be surged three times to knock the balls off the perforations, then the well will be returned to production and tested. jm 12/6/88 Slandard Alaska P~odu¢tlon Compa~t P~O. E,o~ 19661~ Anchoroge. Alosl~o 99519-~:1~ ~907~ 564-5 I 1 I A~CO 5"rANDARD ALASKA PRC)DUCTION EXXON Date: 12/07/8g TO: PHILLIPS 79620 STAT£ OF AK SYSTEM~ '(Transmittai& Tape) ARCHIVES REF~F,: SAPC MAGNETfC LIS TAPES & LISTINGS ~he follc~in9 material is beir~ submitted herewith. Please acknowledge receipt by signin~ a copy of this letter and returning it to this office: W-35 CH/CNL 4 Pass 11/18/88 #I 9850-10573 Sch#7303 1600bpi API#50-029-21799 W-39 CH/CNL-4 Pass,:, 11/18/88 #I 9200-9835 Sch#73031 1600bpi API#50-029-21784 Tape Pos. #06214 Tape Pos. #06216 ARCHVIES ONLY: ~.-_35 ............ CH~:~fi~~pe ...... 11,/18/88 #I Tape Pos #06215 800bpi API~50-029-21799 Sch#73030 W-39 CH field tape !I/~/_88 ........ #I . Tape_ Pos.#06217 Sch#73031 ~: ....... :--.:~'-~':-'- ..... 800bpi .- APi#5'0i-029-21784 * EXXON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. '! ! ~ ~/;~['- Received ~ ~' Date , Jennifer Dietz INMORMAT~ON Well Records LR2-1 Standard Alaska Produclion Compa~ 900 Eas! 8enson Boulevard P,O. BoK 196612 Anchorage, Alas~.o 99519-6612 {907,i 564-51 I I HOUSTON ARCO CHEVRON EXXON TEY~CO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSC iENCES RESERVOIR REFERENCE: ARCHIVES SAPC ~ASED HOLE FINAL LOGS I NDEXE'O STANDARD ALASKA PRODUCTION Date: TI: 11-29-88 79589 The following material Is being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning it to this office: W-35 W-39 F-17 U-13 B-06 CNL/GR (2.5" Tool) 1L-18-88 #1 9850-10573 Sch 5" CNL/GR (2.5" Tool) 11-18-88 #1 9200-9835 Sch 5" PROD 11-18-88 #1 9400-11270 Sch 5" PROD 11-18-88 #2 10000-11342 Sch 5" Completion Record 11-20-88 #1 8890-9317 Sch 5" Received Date ' ' ", ~chorage n A un;! at the or;g;nol Slondord O~l Company Founded in Cleveland. Ohio. ~n 1870. Shirley R. McCurry I NFORMAT I ON CONTROL Wel I Records LR2-1 I NDE×ED HOUSTON A~¢0 STANDARD CHEVRON ALASKA PRODI, JC TION E ~Y~X O N Date: 10-28-88 TEXACO TO: TI: 79476 MOBIL PHILLIPS STATE OF ALASKA , ARCHIVES ' ' REFERENCE: SAPC FINAL'DATA - PRESSURE SURVEY DATA The folio, lng material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: W-38 A-21 B-07 B-23 E-15 E-28 .1-26 K-Ii M-03 M-10 M-il S-15 S-19 W-35 Y-14 Y-24 Y-24 Pressure Buildup 10-09-88 Gearhart Static Gradient 10-17-88 Camco Static Gradient I0-15-88 Camco Static Gradient 10-12-88 Camco Static Gradient 10-14-88 Camco Static' Gradient 10-14-88 Camco Static Gradient 10-12-88 Camco Gradient 10-17-88 Camc~ S tatic Static Gradient '~ 10-16-88 Camc~~' Static Gradient 10-15-88 Camco Static Gradient 10-18-88 Camco Static Gradient 10-18-88 Camco Static Gradient 10-i8-88 Camco Static Gradient 10-19-88 Camco Static Gradient 10-19-88 Camco Static Gradient 10-20-88 Camco Static Gradient i0-14-88 Camco Static Gradient 10-i7-88 Camco Static Gradient 10-20-88 Camco Rece i ved Anchorage Shirley R. McCurry INFORMAT I ON CONTROC Wel I Records LR2-1 INDEXED HOUSTON ~co STANDARD CHEVRON ALASKA PRODUQTION E~XON Date: 08/12/88 TEXACO ¥0: TI: 79195 MOBIL PHILLIPS STATE OF ALASKA ARCHIVES REFERENCE: SA.PC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this le~-ter and returning It to thls office: W-06 Static Gradient 08/04/88 Camco W-35 Pressure Build-Up 07/07/88 Camco Z-O1 Static Gradient 08/04/88 Camco Z-02 Static Gradient 08/02/88 Camco Rece i ved Date a un;I o! lhe o,d 0.1 ComDonY Founded in Cle.elond Oh.o..n 1870 Jennifer Dietz I NFORMAT I ON CONTRCC Wel I Records IR2-1 B-9 C-28 H-14 H-17 M-5 M-19 N-10 S-6 W-35 W-39 X-14 Z-6 Ptoclucllon P.O. Anchozoge. (907} DALLAS INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date:,, 07/20/88 TO: MOBIL 79116 PHILLIPS SZAT~ OF ALAS~ ~ GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES · SAPC CASED HOLE FINAL LOGS Tho following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it to.this office: · Temp 06/29/88 #1 9600-10092 Camco Leak Detection 07/14/88 #1 10-10010 " " " -~.07/14/88 #1 10-9540 " Production Profile 07/05/88 #2 10300-10848 Camco Leak ID/Temp/CCL 07/12/88 #1 Surf-i2590 Camco Leak Detection/Flowing Temp 07/01/88 #1 10-9726 Flowing Temp 07/01/88 #1 10-10550 Camco Step Rate M.I. Injection Profile Production Profile 07/07/88 #1 GR/CCL 07/01/88 #1 GR/Collar ~07/12/88 #1 ~/CCL o7/ol/88 #1. t! ,, I, 5" 5" Camco 5"/2" 07/09/88 #1 9712-10500 10150-10425 Camco 5" 8600-9840 Camco 5" 10500-11541 Camco 5" 9200-10390 Camco 5" 2I' Camco 51! Race I veal Date A u-;! at lhe o,~9~ol Slondo,d el Co--pony Founded ;n Cle~elond. Ok,o. ,n 1870 D orla Aldridge ! NFORHATI ON CONTROL Alaska 0il & Gas Cons. C0mmissi0~ we l ! Records LR2-I A. chorage .. I ND£X£D ~ DALLAS TO: .... ~ ' HOBIL _ STANDARD ALASKA PRODUCTION Date: 05/03/88 TI: 78789 SAPC OPEN HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to thls office: DAL/UNIT/STATE: ~- W-35 DIL/SFL 05/01/88 lEI 9904-10625 Sch 5" / 2" ~- W-35 BHCS 05/01/88 lei 9904-10589 Sch 5"/2" W-35 LDT/CNL poro & raw 05/01/88 tel 7500-10630 Sch 5" A~CO/~.XXON/OEOS ONLY: W-35 SSTVD 05/02/88 Sch 1"/2" STATE ONLY' Magnetic Single Shot Directional Survey GyrOscopic Directional Survey MWD Rece I ved Date irou,-.ded ,n (b,,*.lo.-,d CY,,.,, .~ DIRECTIONAL SURVEYS Date: 4-28-88 Job#: AL488-DlO Date: 5-21-88 Job#' AK-BO-80045 Date: 5-2-88 Job~: 623 Victoria Aldridge I NFOR~T I ON CONTROL Wel I Records LR2-1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of OPerator 7. Permit Number Standard Alaska Production Company 88-33 3. Address 8. APl Number P. 0. Box 196612,. Anchorage, Alaska 99519-6612 50- 029-21799 ~,. Location of well at surface 9. Unit Or Lease Name 1251' SNL, 1451' WEL, SEC 21, T11N, R12E~ Prudhoe Bay Unit At Top Producing Interval ' ~ [(~AT,OI"~ 10. Well Number 2462'SNL, 5166' WEL, SEC21, T11N, R12E : VF'i~IFIED 1 W-35 (12-21-11-12) I1. Field and Pool At Total Depth Prudhoe Bay Fieid/Prudhoe Bay Pool 2448' SNL, 194' WEL, SEC 20, T11N, R12E ~. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. " KBE= 90. 77' I ADL 2 8 2 6 2 14. Date Ct?p, Susp. or Aband. IlS. Water Depth. if oltshore pc. No. of Completior{~ 12.4.10ate3-88Spudd;ed 13.5.2.88Date T.D. Reached ' ~ ¢-:~p--~::~..~. ~,fd,.., I N/A feet MSL I One 17. Total Depth (MD+TVD) 18.' Plug Back Depth (MD+TVD) 19. Directional S'urve"~ ' 120. Depth where SSSV set 121. Thickness of Permafrost 10620'MD 9215'TVD 10577'MD 9181'TVD YES [] NO r-I. I 1982feet MD 12042' . .... 22. ~'yP~ Ei'ectric or Other Logs Run .DIL/SFL, BHCS, LDT/CNL, PoRo and RAW 23. CASING, LINER AND CEMENTING RECORD sE'i'I'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2660' 17-1/2" 3844' cu fl Cold Set II '9-5../,8" ', .. 47# .. L.-8O NSCC Surface 4411' 12-1/4" 1465 cu ft Class G f(~llowed by 9-5/8" 47# L-80 4411' 9899' 12-1/4" 575 cu ft Class G 7" 29# I'J4S 9653' 10618' 8-1/2" 347 cu fl Class G ........ ,, 24. Perforations open to Production (MD+TVD of TOP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET {MD) .... MD 4-1/2"12.6# L-80 9620' MD 9498' MD 10312'-10348' BKB (8875'-8904' TVDss) 10365'- 10375' BKB (8918'-8926' TVDss) 5" at 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH II~TERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" X 9-5/8" Freeze Protect 13-3/8" x 9-5/8" AnnUlu's with 125 bbls Dry Crude 127. PRODUCTION TEST 'Date First Production IMethod of Operation (Flowing, gas lift, etc.) 5-7-88 J .Flowing Date of Test Hours Tested PRODUCTION FOR :31L-BBL GAs-'MCF ~NATER-B'BL CHOKE SiZE IGAS-OIL RATIO TEST PERIOD ~ I Fic~ T'~Jbin'g Casing Pressure CALCULATED DIL-BBL GAS-MCF /VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I,, 28. CORE DATA Briel d~sc~'ipt'i~3n of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEiVEP JUN Alaska 0ii & Gas Cons. Commission Anchorage t WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1,80 CONTINUED ON REVERSE SIDE 29.~ ~ 30. GEOLOGIC MARKERS . .~: ~,-~..,-~IATION TESTS ; , , , .... NAME Include interval tested, pressure data, all fluids recovered and gravity; MEAS. DEPTH TRUE VERT. DEPTH GOR, and time ol each phase. SAG 9905' 8645' Shublik A 9939' 8671' Zone 4 10101' 8797' (Top Ivishak/ Sadlerochit) · . · .. 31. LIST OF ATTA(~HMENTS .... 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signed R~J Dril/ing Engineering Su~)ervisor 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 STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY April 13, 1988 at 0600 hrs Rig: AUDI #3 Well: W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: '" Water Used: -1 1000 Current Opera_tion: Picking up drill collars. Accept rig @ 1730 hours on 4/12/88. Mix spud mud &-nipple up diverter. Mud Typ~!' Sb~ WT: 8.7 VIS:285 PV: 43 YP: 64 FL: 13.8 Solids: 3 Temp: oF . o JUN 2 zt 1988 0il & Gas Cons' C~lmlaaIoa~ Ancherage STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY April 14, 1988 at 0600 hfs Rig: AUDI #3 Well' 'W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth' 1159' Day: 1 24- Hour Ftg: 1159' Water Used: 1000 Current Operation: Drilling. Spud well @ 0600 hours on 4-13-88. Drill 17-1/2" hole to 1159'. Mud Type: Spud WT: 9.4 VIS: 225 PV: 29 YP: 60 FL: 12.4 Solids: 7 Temp: 48 °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35 (12-21-11-12) Daily Drilling Report -- PRUDHOE BAY April 15, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: Current Operation: 0600 Depth: 2685' Day: 2 24- Hour Ftg: 1526' Water Used: 1000 Circulating. Drill surface hole to 2685'. Short trip. Mud Type: Spud WT: I0 VIS: 100 PV: 27 YP: 38 FL: 11.6 Solids: 8 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35 (12-21-11-12) Daily Drilling Report-- PRUDHOE BAY April 18, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 3,500' Day: 5 72- Hour Ftg: Water Used: 2600 Current Operation: Run and cement 13-3/8" casing. NU. Test BOP's. Drill out and perform LOT. Drill and survey 12-1/4" hole to 3,500'. Mud Type: Ligno. WT: 9.7 VIS: 39 PV: 12 YP: 8 FL: 9.2 Solids: 7 Temp: 97 °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDIIOE BAY April 19, 1988 at 0600 hfs Rig: AUDI #3 Well: W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 4,235' Day: 6 24- Hour Ftg: 735' Water Used: 1000 Current Operation: Reaming Motor Run Dynadrilled 12-1/4" hole to 4,235'. LD motor, PU BHA and ream motor run. Mud Type: LS WT: 9.6 VIS: 36 PV: I0 YP: 8 FL: 90 Solids: 7 Temp: 97 °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY April 20, 1988 at 0600 hfs Rig: AUDI #3 Well: W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 5640' Day: 7 24- Hour Ftg: 1405' Water Used: 800 Current Operation: Drilling. Drilling 12-1/4" hole to 5640'. Mud Type: LSND WT: 9.7 VIS:37 PV: 11 YP: 10 FL: 7.4 Solids: 8 Temp: 74 CF STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY April 21, 1988 at 0600 hrs Rig: AUDI #3 Well: W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 6540' Day: 8 24- Hour Ftg: 1900' '° WaterUsed: 1200 Current Operation: POH for Dyna-Drill for fight hand turn. Drill 12-1/4" hole to 6540'. Mud Type: LSND WT: 10.1 VIS:37 PV: 19 YP: 10 FL: 7.6 Solids: 11 Temp: 76 °F STANDARD ALASKA PRODUCTION Rig: AUDI//3 Well: W-35 (12-21-11-12) Daily Drilling Report -- PRUDHOE BAY April 22, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: Current Operation: 0600 Depth: 6875' Day: 9 24- Hour Ftg: 385' Water Used: Drilling 12-1/4" hole. Dyna-Drill 12-1/4" hole to 6654'. LD Dyna-Drill and PU BHA and drill 12-1/4" hole to 6875'. Mud Type: Ligno. WT: 10.0 VIS:36 PV: 14 YP: 10 FL:6.2 Solids: 10 Temp: 71'Y STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDI'I()E I~AY April 25, 1988 at 0600 hrs Rig: AUDI#3 Well' W-35 (12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 8793' Day: 12 72- Hour Ftg: 1918' Water Used' 2200 Current Operation: Drill and survey 12-1/4" hole to 8793'. Mud Type:Dispersed WT: 10.1+ VIS:36 PV: 17 YP:7 FL:4.8 Solids: 12 Temp' 74°F STANDARD ALASKA PRODUCTION Rig: AUDI#3 Well: W-35 (12-21-11-12) Daily Drilling Report -- i)RUI)II()I£ BAY April 26, 1988 :it 0600 hfs Al:E# 120642 AFE Amount: Current Amount' 06()0 Depth: 9290' Day: 13 24- ltour F[g: 497' Water Uscd: I0()0 Current Operation: POOH for bit. Drill and survey 12-1/4" hole to 9290'. Mud Type: Dispersed WT: 10.1 VIS: 35 PV: 14 YP: 6 FL: 4.8 Solids: 12 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI#3 Well: W-35(12-21-11-12) Daily Drilling Report -- I'RUI)II()E April 27, 1988 at 0600 hfs BAY AFE # 120642 AFE Amount: Current Amount: 0600 Depth' 9670' Day: 14 24- Hour Ftg: 380' Water Used: 800 Current Operation' Drilling 12-1/4" hole. Drill and survey to 9670'. Mud Type: Dispersed WT: 10.1 VIS:35 PV: 13 YP: 6 FL: 4.6 Solids: 12 Temp' 100 ~F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDItOE BAY April 28, 1988 at 0600 hrs Rig: AUDI#3 Well: W-35 (12-21-11-12) AFE# 120642 AFE Amount: Current Amount: 0600 Depth: 9904' Day: 15 24- Hour Ftg: 234' Water Used: 1000 Current Operation: POH to run 9-5/8" casing. Drill and survey 12-1/4" hole to 9904'. Short trip. Mud Type: Dispersed WT: 10.1 VIS: 35 PV: 11 YP: 6 FL: 5.0 Solids: 12 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well' W-35 (12-21-11-12) Daily Drilling Report -- PRUDItOE BAY April 29, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 9904' Day' 16 24- Hour Ftg: Water Used: 800 Current Operation: PU 8-1/2" BI-IA. Run and cement 9-5/8" casing. Install and test packoff. NU and test BOPE. Mud Type: Dispersed WT: 10.2 VIS:40 PV: 16 YP: 11 FL: 5.2 Solids: 12 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUI)I[OE BAY May 2, 1988 at 0600 hfs Rig: AUDI #3 Well: W-35(12-21-11-12) AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 10,620' Day: 19 72- Hour Ftg: 716' Water Used: 2000 Current Operation: Running 7" liner. Clean out 9-5/8" to float collar and test to 3000 psi. Drill float equipment and 8-1/2" hole to 10,620'. Short trip. Log. Change rams. Run liner. Mud Type: Dispersed WT: 9.5 VIS: 36 PV: 11 YP: 8 FL: 7 Solids: 7 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35 (12-21-11-12) Daily Drilling Report-- PRUDIIOE BAY May 3, 1588 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 10,620' Day: 20 24- Hour Ftg: Water Used: 500 Current Operation: Pick up 4-3/4" BHA. Run 7" liner and cement. Dress off TOL. Mud Type: Low Lime WT: 9.4+ VIS: 46 PV: 19 YP: 11 FL: 12 Solids: 7 Temp: 84 °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35 (12-21-11-12) Daily Drilling Report -- PRUDItOE BAY May 4, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 10,620' Day: 21 24- Hour Ftg: Water Used: 800 Current Operation: Clean pits and inject mud. Pickup 4-3/4" BHA. TIH, test liner top to 3000 psi - OK. Displace hole to 9.3 brine water. Mud Type: Brine WT: 9.2 VIS: PV: YP: FL: Solids' Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35 (12-21-11-12) Daily Drilling Report-- PRUDHOE BAY May 5, 1988 at 0600 hfs AFE it 120642 AFE Amount: Current Amount: Current Operation: 0600 Depth: 10,520' Day: 22 24- Hour Ftg: Water Used: 1100 Rig up Schlumberger. Inject mud and water. Displace hole to completion fluid. Test casing to 3000 psi - OK. LD DP and DC's. Install 4-1/2" rams. Mud Type: NaCI Brine WT: 9.2+ VIS: PV: YP: FL: Solids: Temp: STANDARD ALASKA PRODUCTION Rig: AUDI#3 Well' W-35(12-21-11-12) Daily Drilling Report -- PRUDHOE [lAY May 6, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: 0600 Depth: 10,620' Day: 23 72- Hour Ftg: Water Used: 300 Current Operation: Running tubing. Run CBT/CET Log. Perforate. Run tubing. Mud Type: NaC1 Brine WT: VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-35(12-21-11-12) Daily Drilling Report -- PRUDIIOE BAY May 9, 1988 at 0600 hfs AFE # 120642 AFE Amount: Current Amount: Current Operation: 0600 Depth: 10,620' Day: 25 48- Hour Ftg: Water Used: 900 Run tubing. ND BOP. Test tree. Set plug in XN nipple and test. Set packer. Displaced annulus to 9.6 brine and tubing to diesel. Close and test sliding sleeve. SSSV. Released rig @ 0800 hours on 5-7-88. Run Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: ~ May 26, 1988 Mr. Michael D. Martin Standard AK Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Our BOSS Gyroscopic Survey Job No. AK-BO-80045 Well: W-35 Prudhoe Bay, Alaska Survey Date: May 21, 1988 Operator: D. Harger Mr. Martin: Please find enclosed the "Original" and sixteen (16) copies of our BOSS Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard Western Area Manager Enclosures NL Sperry. Sun/NL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 RECEIVED SPERRY~-.c_;UN _WELL_SURVEY I NG ._ COMPANY_ ...................................................................................... RAGE ....... 1 ........ ANCHORAGE ALASKA STANDARD AK PRODUCTION CO. DATE OF SURVEY MAY 21, 1:-.788 W-35 ........ COMPUTATION_DATE .......................... BOSS. GYROSCOPIC_SURVEY PRUDHOE BAY MAY 23, 1S.~88 dOB NUMBER AK-BO-80045 ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR-HARGER vERT i CAL SEcT i ON cAL6~iL"~'~E6"-~'L~-~-'~iE~uR--E ............................................................................ TRUE ' MEASURED ' VERT I CAL DEPTH c, LIB-.:,EA VERTICAL 0 100 200 300 400 500 600 700 800 ~00 1000 1100 1200 1300 1400 1500 1600 1700 1800 1~00 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL BEG MIN DEGREES BEG/lO0 NORTH/SOUTH EAST/WEST SECTIF"~ ................. :'00 .................................. ]Z6t ........... -90.77 0 0 N O. 0 E 0.00 0.00 DEPTH DEPTH i 100. 200. 300. 400. 500. 599. 697. 799. 899. 979. 10~. 11~.-9. 12~9. 13~9. 1499. 1599. 1699. 1799. 1899. 1999. 2099. 2199. 2299. 2399. 249~. 2599. 26S.~9. 2799. 28~9. O0 O0 ~.23 00 10~.23 00 20~.23 00 30~.23 O0 40~.23 ~ 507.22 ~ 60~.22 ~ 707.22 ?~ 80~.22 ~8 ~0~.21 0 14 N 63.69 W 0.24 0.0~ N 0.19 W 0.15 0 10 N 59 =' .~,0 W 0.07 0.27 .N 0.51 ..... W 0.41 ......... 0 10 N 57 69 W 0.02 0 43 N 0.78 W 0 /-'-' · · i 0 10 N 36.69 W O. 07 O./--,4 N 1 .01 W O. _,_7'~ 0 7 N 10 80 W 0.09 0 '-'P ............. . . o_, N 1 12 W 082 0 37 N 49..~ W 0.54 1.35 N 1.56 W 1.1I 06 N 66.60 W 0.19 1.91 N 2.4/_', W 1 E:I ..................... 0 ............ 9 .............. N,.81.80 W 0.45 2.14. N 3.08_W '2.34 0 7 N 58.10 E 0.27 .-.~' '-"'--' N :3.12 W ~. o6 0 26 N 53.80 W O. 50 ~':'. 51 N 3. ._q':'._, W .-'-'. 48 98 ........... 1009.21 .............. 0___16 ......... N..46..10 ..E ............... 98 1109.21 0 2 N 71.39 E ~,_~ 1209.21 ' 0 20 N 56.30 W 98 1309.21 .............. 0 ....... 16 S 63.89 W 98 1409.21 ~, 15(]9 21 ~8 ...... 160~.21 97 97 .97 97 97 97 ';'7 97 97 97 93 74 0 8 S 60.80 E 0 14 N 58.80 W ................. 0 ...... 18 ............... S_.,26. IO..W ........... 170.9.20 0 13 S 63.19 E 0.._',8 1809.20 0 7 S 5. 0 W 0...'~'1 1909.20 .............. 0 ....24 ............ S_._i 4.39_. E .. O. 2:3 2009.20 0 4 N 83.89 W O. 47: 210'2.20 0 4 S 12.69 W 0.11 2209.20 ........... 0 ....... 6 ........... N _ 19.80 ... W .........0.17 2:30:-]. 20 0 14 S 31.39 W 0. :31 2409.20 0 6 N 45. 0 E 0.35 ....... 250:9.20 .............. 0 __.21 ............ S ..76.69.__W ............. O. 45 2609.20 0 26 N 88. :::0 W 0.14 2709. 16 2 '2 S 66.30 W 1.65 ..... S 58.89..W 2.96 0.,.6 2 90 N 2.49 .......................................... · .:.. 47... W ............................ .' . ........... 0.25 3.08 N ~.'-' 26 W -.---.'~' 24 0.37 o.~ 26 N 3.47 W ~.9 40 O. 31 '-"' - . ....... 3. · _-,. ?,2. N ........... _',_ W ...................... 2.8'-' 0 37 '-' 16 N 4.03 W 2." 0.3:3 3.2(3 N 4.11 W 3.02 0.41 .................. 3.07 N ...........4.4<:). W .... ~ .................. 3.:~.~ '2.74 N 4.35 W 3.39 · - .~, . .29 ~.._4 N 4.19 W 3 .... 2.0'..;' N ....... 4.11 W ............... 3. q.=; ........ I 76 N 4 10 W '-' 42 . i .~l m I 70 N 4 1c' W :3 52 . . I__I . 1.71 N 4.23 W ..................... 3.56 ..... 1.62 N 4.36 W 3.72 .51 I N 4.41 W :S.79 ................I.P;'._o _N ............ 4.63 ........................... W 4.01 1.44 N 5.7:'2 W 4.68 0.73 N 7. q'-' · _~ W 6.82 2.'---'-:-'.-".:' S 12.67 W ............................... . 12.78 SPERRY-SUN WELL SURVEYING COMPANY ...................................................................... PAGE ...... .r., ANCHORAGE ALASKA STANDARD AK PRODUCTION CO. DATE OF SURVEY MAY .-'~-1, 1'~c~'~.. ~o W-35 .................................................... COMPUTAT I ON_DATE .......................................... BOSS._. AYROSCOP I C ._..SURVEY_ PRLIDHOE BAY .... MAY '--'q ~"-~ ...... ---._ · 1 y/:B8 dOB NUMBER Ak'-BC~-:~c)04S ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR,HARGER VERTICAE SECTION CALCULATED ALONG CLOSURE MEASLIRE[~ DEPTH TRUE ......... SUB-SEA COURSE ............... COURSE DOG-LEG TOTAL ........................................................................... VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEG MIN DEGREES; DEG/1 O0 NORTH/SOUTH EAST/WEST SECT I C" '] 3000 2'P99, 07 '~'-',,'-~' ~C '.':':::. 74 -'-.".,,.,o .:,.} 8 ?, S 57.=¢ '-"-' 32 W ........ --,.} W 3, 12 o.'--' 24 '-'.:, ...-. 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 3097.95 3196.47 3294.49 3391.72 3487. 3583. 3676. 3768. 3859. 3947. 87 04 86 29 46 3007 1~' . ~ 9 6 S 54.50 W 1. 3105.70 .................. 10 ...... 34 ................ S....55.39_W 'I. 3203.72 12 11 S 56.30 W 1. '~'-'C ~ '-" - o~0.~ 14 46 e 56 ~ W ~ i .' '-- ._l . . 3397.10 .......................... 17 ......... 3 ............ S.,...58.37._.W 2. 3492 27 1~' . ~ 40 S 57.30 W 1. ~5~A 09 21 46 S 57.30 W ~' ._67 .... 22 23 ......... 56 8..56,10 W .......... 2. o.=,o.52 26 55 ~, 55.~0 W ~. 3856.69. 29 19 S 54.'~'~0 W 2. 4033.70 ............. 3942.9:3 ....... 31 ..... 27 .......S_56.50...W ................. 2. 4118.40 4027.63 32 45 S 59. 0 W .1. 4201A'~ 4111 05 34 10 S 58.~° W 1 -- .~ ~ ~ ......... - 4284.3~ .... 4193.55 .................. 34 .... ~7 ........ ~ o9.30 W 0 98 96 70 29 .59 .54 .44 .32 .07 .65 .20 .71 _ _ .41 .40 .68 4365. 4446. 4527· 4608· 4688 4768 4848 4928 5008 5087 5167 5246 5326 5406 5486 4275.21 4356.19 4436.~3 4517.52 4597.82 4677.77 4757.67 4837.55 4917.30 . 4996.88 5076.43 g5 51 S 59.10 W 1. 35 59 S 59.50 W O. 36 ..... 19 .............. S_59.50.W ..............O. 36 16 S 59.19 W 0. 36 53 S 59.89 W 0. 36 .... 56 S..60.30.W ........ 0. 36 58 'S 60.60 W O. 36 58 S 60.89 W O. ........... 37 ..... 15 ......... S_.60.80__.W ............... 0. 37 16 S 60.69 W O. 37 19 S 60.69 W 0. 51~5 94 37 19 ~' 60 69 W 0 · --'-- I ............... . ......... ~-. I .......... · 5235.64 36 58 ¢'._. 61. O_ W O. 5315.63 36 46 S 6(}.10 W 0. 5395.91 .......... 36 ..... 25 ........... S.._59.80 W ........... O. 10 16.61 ~' · :, :2:4.69 W 37.99 49 26.42 ':'.., 4,_-,.c-,:, W 54.20' 63 :-:7.49 :=-; 6o. 03 W 73.02 57 50.41 :-:; o4.44 W ~.~,. 31 3:4 65.15 '-' ................. .......................... · :, 107 ._,4 W 121.66 66 :--:1. 4:3 -:,'-' 1:3:2:. 51 W 151 . .-'0'-" 10 100.16 S 162.60 W 184.42 '--"1 121 50 S 1'-=' 05 W ~ ;c_, ........................... ~-'- 1.61 .............. O0 145. f_,~5 o'-' 230 .5/-,_ W 262. 47 ' 172.77 q '-,/v:? · _ . ....1'2 W 7:07.22 40 201.46 ::; :':: 10 77 W .................... '-'=?, '-"" ................ . ....................... . 0._1._ . ~._', ." ...... :--:5 ~_..'-'.'.-'o, 79 S 3.~5_ .71 W 406.40 43 '-'5-' ":'q -' ?._, W 4._,w.87 .-'._ ~. ~.._ ~, 402.'- '-=' =-- 50 2:37. '~= :_-'; 451 4:2: W. ~ 14. A ...... L ..I m .................... 24 :316.80 S 501.00 W 570. L .: 27 346.75 S 551.45 W 627.44 34 .......... 376.70_. S .......... 602.2:-7 W ................... 684...71 ......... 19 406. :--:8 '.-'; 65:3.22 W 742.14 75 437.08 S 704. ~'- .. ._ ~ W 799.99 .,..,.. 467.02 .5: . 756.67 W ......... 858.44 18 496.. 68 S 80:_--:. 98 W 917.04 18 526.07 S 861.46 W 975.73 28 ......... 555.46_S ........... 91.4 16 W ............1034.62 ......... 07 585.05 S 966.99 W 1093.69 05 614.71 S 1019. ,'_=:4 W 115'---2.81 02 .... 644.39 ~--; ..... 1072..73 W .............. 1'211 .':76 ...... 39 67:_--: :--:0 S 11":-'.=; . . ..~.47 W 1270 91 · _ ,:, 70:3. '3 ! :--; 1177.73 W 1:32:.7.41 :2:9 ..... 73:3.17 S ....... 1229.34 W .............1:387.4<:) .............................................................. SPERR¥~SUN_WELL_SURVEyING_COMPANY ............................................................................................. PAGE ....3 ANCHORAGE ALASKA STANDARD AK PRODUCTION CO. DATE OF SURVEY MAY 21. 1.988 W-35 .......... COMPUTATION.DATE .......................... BOSS GYROSCOPIC_SURVEY PRUDHOE BAY MAY 23, 1.988 dOB NUMBER AK-B_I-o~04o ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR-HARGER ................... ...............VERTI_.AL~ oECTI~ '' ON CALCULATED ALONG CLOSURE . MEASURED DEF'TH 6000 6100 6200 6300 6400 6500 6600 6700 6800 6.900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8.900 TRUE . SUB-SEA ............................ COURSE ............. COURSE ............. DOG-LEG .................................. TOTAL VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECTI 5567. ~' - ' : '~ "' ~'- ' '" ¢~ '-' ""'-~ ' '--' ':' .,7 5476.60 OD 58 ~_~ ~,?. 60 W O. 47 76~_.; 7 ._~ I~,~o. 04 W 1444· 7,_, 5648. 5729. 5812. % I_I .. II 5.977. 6060. 6143. 6225. 6307. 63.90. 6474. 6556. 663.9. 6722. 6806. 688.9. 6.972. 7054. 7136. 7217. 72.98. 7377. 7454. 7531. 7608. 7683. 7758. 7830. 7.902. 45 .98 04 62 70 83 21 23 77 .90 01 7.9 80 6466.02 654.9.04 5557 68 35 40 S 5.9 W O. '--°:~ . . ,-qO 7.92 =A'-'~ :~= ~ ~ 60. 0 W 59 .............. 821 ~ · _,c o.. 21 O, , 5721. 27 34 37 S 60 .30 W 0.4.9 o='~'~°..-..9.9 S:~O:~. ~:a5.- 34 1 ~" 60 .39 W O, 61 877 , ~'R"' oo06 ~3 "3 '~" R '~ '~'0 ~05 20 .. - ................. .:.._ ........ o~ .............. ~ ou.o. W 0.47 . 5.970.06 33 5~ S 67.80 W 3 , .91 92.9 .2°. ,~. 60._,~. 44 3~ 4 · - o 70, 60 W 1, .93 94.9. 6134.46 ....................... 34 ...... 41.L. .............. S_71.10 .................. O, 4.3 ......... 968, 15 6217.00 34 2 S 71.3.9 W O. 68 ~86.2.9 '-"' 2~ . 6o00.13 33 S 72,60 W 0,:76 1003 47 - . ................. , ............ S. 73. '~'~ o~._W .............. O..94 .............. 101.9.4.9 34 8 S 73.10 W 0.45 ]'~ 1( ....43 33 37 S 73.8~ W 0.68 1051.26 ...,._.~ (.) · o ,...-.~ W 1501 64 S I ':":'(' .97 W 1 == .9:3 ........ .-..-. J. :J._,7. S 14:7-:0.._4 W 1613 ..6 S 147.9, == · .,.~, W 1668, 48 :, ........... 152:::. 0::,'. W ................. 17~. 7.5 S 1578.0.9 W 1777.5.9 ::"; 1631 07 W 1'"'-' . oo4.11 S 1 ,.: o..,. 11 W 1o..'-"=' 1 ~ 1738. o6 W 1947.66 · _,'--' 17.91 .42 W 2003. . S 1844.67 W --,r,.~,,-, ,_-,.-., S 1 '-""~'-' ~. .. o .. ,=,. 45 W '-." 114. o2 S 1.951..91 W 2170.68 .99 6632.22 ................... :q:~, ....... 47_ ........... S..~74.30 W .............O. 27 ......... 1066.47 31 6715.54 33 21 S 74.69 W 0.48 1081.25 57 67.98.80 33 53 ~.o 75.50 W O. 70 10'~5... _ 4o~, 12 ......... 6881.36 .............. 34 ....... 48 ...... S ...76.80.. W ............. 1.17_.: ........ 1108.99.. 2:3 6~6:3.46 34 48 S 78.19. W O. 80 1121 .34 03 7045.26 35 25 S 79.6.9 W 1.06 11~:~.o6 oo W '-"")'r'A 1:> 20A.:;.... ................ .._ ....=~. S '.~'O5R .=iR W 2281 4 ) ..... _ . ."l_ m '--' '-' I 1 '> 10 !,4 '-"-"~' R'-' · -. .' .t... · -" S ............. 2166._:--:.9 W '--; 2222 61 W 24~(') 1':? · _-- . ...'=' 2279.07 W --,.:;,0'7 ~ .. 37 40 7126.63 03 7207.26 20 7286.43 83 7364.06 73 7440..96 20 7517.43 76 75.92..9.9 08 7667.31 75 7739..98 61 ......... 35 ....... 38 ...... S...81.69 W .............. 1.18 ...... 1141.75 S .. 36 52 q 82.89 W 1.41 1149.66 S 38 26 S ~:~.19 W 1.58 11o7.05 s 39 .... 41 ............ q_.83.60..W .............1.28 - 1164.29 S ........... 39 46 S 84.60 W 0.64 1170.86 S 40 28 S 8~.'-'c _ DJ W 0.83 1176.~'~ S '23:36.41.. W ........... 2565.02 ...... '-"-":'~=' 02 W '-'/-'--'-'--' 45 · " ..D :: ._' · · * _s .,- ...,, · 2518.2.-'6 W ............ 274._%.,.74 ........ '-'=q · :::4 · .- ,_,._ 1 2646.0:3 W 2871.65/ 1 '""-' - .-i .-... S 86.19 W I llR1 38 .--; 2711 '~=- ..... . ................ · (.)o ........ ~ .... _ ..................................... _ . ...... . o._,._ W '-.-,9:q~ 68 · -- :: .~.-,. 42 .36._.c; 86.6.9 W 1 . ~ 11~5. ~. ..-c; 2778. 11 W 3A00. . A5_ -' '-"q~/- 6:--: W 3067 70 44 9 .... S R~.69 W 1 . ~.~.,.=;,=' 11'::'-~,_ .. .47 ~ ...,_-~=,. . 7811 84 ........... 43 56 .......... s 86 19 W 0.41 1193.: 78 S 2916. ')'" ...... -'. to.~W 31'-'=' 45 ............. %,5 ."1 · ...................................................................................... SPERRYcSUN_WELL_SURVEYING._COMPANY ................................................................................ PAGE ..... 4 ANCHORAGE ALASKA STANDARD AK PRODUCTION CO. DATE OF SURVEY MAY 21, 1988 W-35 .................. COMPUTATION_DATE ........................................ BOSS_GYROSCOPIC_SURVEY. PRUDHOE BAY MAY 23, 1988 dOB NUMBER AK-BO-80045 ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR-HARGER .............................................................. VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE .. MEASURED VERTICAL DEPTH DEPTH DEPTH '9000 9100 9200 9300 9400 9500 9600 9700 9800 ?900 10000 10100 10200 10300 10400 10500 10600 10620 oL B-oEA COURSE COURSE DOG-LEG VERTICAL INCLINATION 7974 51 7983.74 44 8046.84 7956.07 43 14 S 87. 8120.08 8029.31 42 34 S 87. 8193.57 8102.80 42 49 S 88. 8267.05 8176.29 42 35 S 88. 8340.46 8249.69 42 56 S 88. 8414.18 8323.41 42 4 S 88. TOTAL DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEG MIN DEGREES DEG/IO0 NGRTH/SOUTH EAST/WEST SECTIO~ 19 W O. 16 1198 .~'-' .~o,-,~. ..... :, S :'~20:--:. 2:S' ~;-,: ..... 44 W _ ._ . 'r, --, _ - 3054.37 W 3270.47 0 W 1.03 1--0~. 4:5 ~: 69 W O. 8-' 1'-' = LO._,. 63 '-' 3122 37 W ._~3c, 6.55 10 W O. 38 1 '--,0'-' - '--'," 0'-' ~¢,. 12 :~ :_--:190.14 W _ c,~ .,~. 21 30 W O. 28 1 '~'10 '-'~ ¢' '-"-'?, 93 . ..:. . -.'._, ._. ,:...'._ 7. W 3467 .80 50 W O. 39 1212 14 S '-"--'~= ":'~":'":' 40 ~..-'..--.-,. 81 W ..................... ._1...._1....1 · o~ W 0·8:.5 121'-"._,. '.'.?7 .--,'-'..:,'-"--"~'-".~ .~ ._,. 36 W._',._'-' ~'-'"" .':'o. 6/_', 8489.11 8398.34 40 51 S 89.60 W 1.45 1215. 8565.07 8474 30 .........: .......... 40......:...16 N '~'~ 50 W 0.~2 1215· 8641.50 8550.73 40 1 N 88.39 W 0.75 1213. 8718.~'a 8627 75 39 13 N 88.39 W 0 80 1~1~. ~ · s '~'~¢'~ 52 8705..75 ...........38 1.3 N 88,.69 W 1,02 <,-~,; ............... 1210. 8875.47 8955.29 9036.33 9118.54 9199.37 9215.16 8784.70 37 29 N 88.19 W 0.80 1208. 8864.52 36 35 N 87.69 W 0.95 1206. 8945.56 ............. 35___7 .......... N._O7..IO_W ................ 1.50 ........... 1'~] 9027.77 34 16 N 86.19 W 0.99 1200. 9108.60 37 50 N 87.89 W 3.70 1197. 9124 c'9 37 50 N 87.8o W 0 10 1197. · ~i 0 .............. .0 ........... . . 13 R '" =" '-' '--' 56 W .=.66.-'-. 44 · _ ..:,4 :_, ~". 08 R ....... 3524..~'~ .W ............... ._.,7,.4.76 ....... 90 S '-'~"-"~ ,:.._.o... 06 W 3786. -.'-"1 12 :~ .--,AM.7., :::2 W 3846 81 -- ..i~,.._ .,- · · ~.-. c. '"-~ ~ ~ '"' W ....... ._'. ~06..30 ....... · - *~...-, ........... ...5 /. .,I. ._1 m..",z_-, e,E¢z.,"' 3776 · 71 W 3'.~64. · 63 7'7.' S 3836. :.-71 W 4021 · 7 07 S '::'-":'/~- ............ ......... ._ o .~ ._,. 42 W .... 4077. 75 S "-:':~.=;,2 '-' ._, ..... .-6 W 4130. '- 7/_-, S 4011,03 W 4186·05 31. S ......... 4023.29. W .............. 41.77,.67 ......... HORIZONTAL DISPLACEMENT = 4197.67 FEET AT SOUTH 73 DEG. 25 MIN. WEST AT MD = 10620 THE C:ALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ..................................................................................... SPERRY,SUN .. WELL_SLIRVEY I NO... COMPANY ..................................................................................................... PAGE ..... 5 ANCHORAGE ALASKA . : '"1 ~L~,-~ STANDARD AK PRODUCTION CO DATE OF oLRVEY MAY 21, 1' '-'-' PRUDHOE BAY MAY 23, 19:~:=°. ~ _~ dOB NUMBER AF.'..-B'_i-o¢. 04._," C ':' ] ' ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR.HARGER INTERPOLATED vALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MB-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST D I FFERENCE CORRECT I ON · 0 O. O0 -.90. 10OO 999 ,z/r, 909 . · . , ~-0 . . , 3000 2999.07 2908. 4000 3947.46 ~'- ~A. 5000 4768.54 4677. 6000 5567.37 5476. 7000 6390.90 6300. 8000 7217.40 7126. 9000 7974.51 7883. 10000 8716.52 ............. 8627.. 10620 921 = ~,. 16 9124. 77 O. O0 O. O0 O. O0 21 ~' ~1 N 3 ~' .~,~, W 0.02 0.02 : 20 2.09 N 4.11 W 0.03 0.01 30 8.24 S 22.~'7' W 0.93 0.90 69 ........................... 172.77..~S ................ 269..12 . W 52.54 51. ~ 77 467.02 S 756.67 W 231.46 178.91 60 762.97 S 1280 34 W 4._~.6o 201 18 1 '~ 1003.47 S 1791 42 W 609.10 176 46 74 1198.38 S 2985.44 W 1025.49 242.89 75 ................. 1212._12 S 3652.82 W ..............1281 ._48 .................... 256.00 39 1197.31 S 4023.29 W 1404.,_4 1~3 36 THE CALCULATION PROCEDURES ARE._BASED.ON.THE_.USE...OE..._THREE DIMENSIONAL..RADIUS OF. CURVATURE. METHOD ........ SPERRY~SUN_WELL_SURVEYING..COMPANY ........................................................................................ PAGE~z~ ....... STANDARD AK PRODUCTION CO. W-35 PRUDHOE BAY ALASKA ANCHORAGE ALASKA DATE OF SURVEY MAY 21, 1788 COMPUTATION DATE MAY 23, 1988 dOB NUMBER AK-BO-80045 KELLY BUSHING ELEV. = ?0.77 FT. .................................................. OPERATOR.HARGER .............................................................. MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE oUB-._,EA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH ............ NORTH/SOUTH .............. EAST/WEST DIFFERENCE CORRECTION 0 90 190 290 3~.~0 490 590 690 790 890 9'.-? 0 1090 11V~O 1290 1390 1490 1590 1690 1790 O. 90. 190. 290. 390. 490. 590. 690. 790. 890. 990. 1090. 1190. 1290. 1390. 1490. 1590. 1690. 1790. O0 -90.77 0.00 0.00 O. 77 0.00 ................. :~ ........................ 0.08 N ......................... O..15...W ................... O. 77 100 O0 O.~= . ~o N 0.4~ W O. 77 200.00 0.41 N 0.75 W O. 77 300.00 0.62 N 0.9'~ W 0. 77 400.00 0.86 N 1.12 W O. 77 500.00 1.28 N 1.48 W 0. 77 600.00 1.87..N 2.37...W ................ O. 77 700.00 2.14 N 3.05 W 0. 77 800.00 2.21N 77 ........900.00 2,46.._N 77 1000.00 2.87 N 77 1100.00 . 3.08 N 77 .... 1200.00 ............. 3..23_N 77 1300.00 3.34 N 77 1400.00 3.17 N 77 ..... 1500,00 3...18_N 77 1600.00 .,~. 12 N 77 1700.00 2.76 N 3.14 W O. 3.27_W ............................ O. 3.50 W O. 3.26 W O. 3.42_ W .................. O. 3.89 W O. 4.05 W O. 4. OZ..W ............ O. 4.38 W O. 4.38 W O. O0 O0 ........ 0.00 .................................................................................. O0 0.00 O0 0.00 O0 0.00 00 0.00 O1 0.00 O1 0.01 01 0.00 O1 0.00 02 ........................... 0.00 ....... 02 0.00 02 0.00 02 .......................... 0.00 ................. .... 02 0.00 ) (~ 0. o0 02 .................0.00... 02 0.00 03 0.00 ~;PERRY-SIlN WELL ~;IlRVEYING COMPANY PAGE ANCHORAGE. ALASKA . '-' ~ ' .. i_-,~, STANDARD AK PRODUCTION CO DATE OF :=,LRVEY MAY 21, 1'~'~-° W-35 . ..... ____ COMPUTAT I ON ~DATE .............. PRLIDHOE B~~ ...... MAY~,,~-' 1.988 dOB NUMBER AK-BO-:::~'~O45 ...... ALASKA KELLY BUSHING ELEV. = .90.77 OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRLIE SLIBisEA MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ~ DEPTH DEPTH DEPTH .........NORTH/SOUTH .......... EAST/WEST ...... DIFFERENCE ............CORRECTION : .......... 1890 1990 2090 2190 2290 2390 2490 2590 2690 2790 2891 2991 3092 3194 _ _ 3296 3399 3503 _ 3608 3714 1890.77 1800. O0 2.56 N 4 ' 19 W 0 . ~:~._-,'-' O. O0 1990.77 1900. O0 20:70.77 2000. O0 1.76 N 4.08 W O. '~'~ ~.._. 0, O0 ~'1:?0 77 2100.00 I 71 N 4.18 W 0 03 0.00 22:?0.77 2200. O0 .............................. 1 ·70. N ......................... 4.22... W O. 03 O. O0 2390.77 2300.00 1.65 N 4.34 W 0.03 0.00 2490.77 2400. O0 1.4'.~ N 4.42 W O. 03 O. 00 25c/0 77 . ._._,00. O0 1.52 N 4.58 W O. 03 O. O0 2690.77 2600.00 1.44 N 5.25 W 0.03 0.00 2790.77 2700. O0 O. 86 N 7.03 W O. 06 O. 03 28.90.77 ............ 2800. O0 ........................... 1.85... S ..................... 12.04... W ...................... O. 23 0.17 2990.77 2.900. O0 7.63 S 21. c. 6 W O. 85 O. 61 30'.70.77 3000 O0 15. '~' . _ . . ..c~ S 33.75 W 1.gA 1 11 3190.77. 3100. O0 ..................... 25.81_S ............ 47.81_W ...................... 3.43 ......................... 1.47 .................................................. 32'.~0.77 3200. O0 37. '= . ~._, S 64.36 W 5.42 1 :?9 ) .... · . -"8 S 84.24 W :_~. 24 2. :-:Z 33.90 77 3300 O0 50.2' - -- · ........... 3490 77 3400. O0 65.61 _._--' .......... 108.30 W .......... 12.26 4.01 3:590.77 3500. O0 82...02 .c_: 135.75 W 17.40 5.14 36:70.77 3600. O0 103.16 S 167.28 W 24.21 6.80 SPERRY~SUN~ WELL_SURVEYING. COMPANY PAGE ....E: ANCHORAGE ALA:,KA :=;TANDARD AK-. PRODUCT IAN CO. : DATE OF SURVEY MAY '-.,1, -- ..:. W-._._, COMPUTATION__DATE ......... ~ PRUDHOE BAY MAY 23, 1°~'° ' - '-'r' .=, :-o~ JOB NUMBER AK-BU-o.)t)4._ ALASKA KELLY BUSHING ELEV. = '..~0.77 FT. OPERATOR.HARGER MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE~,LIB-~,EA~ ~ TOTAL ~ VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ') DEPTH ........... DEF'TH ......... NORTH/SOUTH ........ EAST/WEST DIFFERENCE CORRECTION :. ...... 3823 3935 4049 4167 4286 4407 4530 4654 4778 4902 5027 5152 5278 5403 5529 5655 5780 5905 602~ 3790.77 3700. 3890.77 3800. 3~90.77 3~00. 4090.77 4000. 4190.77 4100. 4290.77 4200. 4390.77 4300. 4490.77 4400. 4590.77 4500. 4690.77 4600. 4790.77 4700. 4890.77 4800. 4~90.77 4~00. 5090.77 5000. 5190.77 5100. 5290.77 5200. 5390.77 5300. 5490.77 5400. 5590.77 5500. O0 127.01S 203._.~'~ W O0 154.70 c. 243 74 W 00 187.01S z ..... O0 220.64 S 340. O0 '~: ...... z ~ 455. O0 '~ O0 '~ 516 O0 ~,[.~-, ,.~.-.: c- ......................... · -~-.~. , - ~.'-' .............. O0 O0 O0 O0 O0 O0 00 O0 O0 O0 O0 ~,~:,. 'P1 W 400. :30 S 642.17 W 437. S.~0 ~ ~' 475.31 S 512. B1 S 549. ]~ - ~.._, b: 'PO2. 5A6.21_S ..... ~69. 623 ~ 1 S 1~]'-'~ 660.78 S 1101. 697.49_S ...........1167. 734.69 S 1231. 771.57 S 1295. 163.41 '-'"' ~._"~.._ . . 187.50 ~4.09 706.01 W 211.95 24.45 771....1 '~._. W ................ 237.04 ..................... 25.0'~ 836, 76 W -."v-~-,-- ...... ~ 68 W 287.50 25.28 06._W ..................... 31.3.15 .......................... 25.65 ................ 5Z W ~J:~:.~:~ z._.73 ~? W 364.61 25.73 60.._W .................... 389.72 ............................ 25..11 ~6 W 414.32 24.60 00 W 438.15 23.83 SPERRY~SLIN... WELL_SURVEYING ... COMF'ANY .................................................................. PAGE ....... 9_. ANCHORAGE ALASKA STANDARD AK F'RODLICTION CO. DATE OF SURVEY MAY..~1,'--' 1.cx:=::~.-~ .... · W-.-,._, COMPUTAT I ON_ DATE PRUDHOE BAY MAY 23, 1°°'-':.~,o JOB NUMBER A}::-BF;-SoA4~ ..... ALASKA KELLY BUSHING ELEV. = 90.77 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SuB-SEA DEPTH MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH ............. NORTH/SOUTH .............. EAST/WEST DIFFERENCE .......... CORRECTION ........ 6152 6274 63?5 6515 6636 6758 6879 7120 7241 7361 7481 7601 7722 7844 7967 8090 8217 8346 5690-77 5790.77 5890.77 5990.77 6090.77 6190.77 6290.77 6390.77 6490.77 6590.77 6690.77 6790.77 6890.77 5600.00 807.73 S 1357.07 W 5700.00 ....................... 842..71 S 1417.79. W 5800.00 876.60 S 1477.29 W 5900.00 909.35 S 1535.67 W 6000.00 ~36.90 S 1596.78 W 6100.00 960.41S 1662.53 W 6200.00 982.63 S 1727.68 W 6300. O0 1(]o3.45 S 179 · ~'"" - F~,r., 07 '"r · .,.~ :--:6 .t....2,-.', ~ (.:, ..' 2: · · 6400. O0 10.-.-.. 64 S 1855.57 W 629.47 .--..~. 40 6500.00 1042.12 S', 1920.50 W 650.29 ...'-'c .~,'- '-~C · -.* 18 6600 00 ....... ~__1060.63 S 1984.._._~ W 670.46 6700.00 1078.55 S 2048.71 W 690.63 20.17 6800.00 1095.6.9 S 2112. ,__,~:~_o W 710· _,~A:~ 20. ~]5. _ 6990.77 6900 00 1111.9.=, .%' 217-'9.51 W 731 94 21 '-'A 7090.77 7000. O0 1126.51 S 2247. ?,2 W 75:3.75 21. :31 7190.77 7100 00 11 '- 99 ':' - 3E:. 2~:17.51 W 776.45 '.--'2 70 m . . ~.i ~. · 7290.77 7200· O0 1148...~9 ._S ........... 2389.61.. W ................. 800.15 ........................ 2:3.70 ................................................. 7:--:9¢'~. 77. 7300. O0 1158.33: S 2466.35 W ._,~o¢'°z. SA_ _ 26.41 7490.77 7400. O0 1167 .._~'~,.. ~" 2547 .92 W o._'-'~.=,._. 95 29. . :;.3:' ' SPERRY~SUN_WELL_.SURVEYING...COMPANY PAGE._10 ...... ANCHORAGE ALASKA STANDARD AK PRODUCTION CO. DATE OF SURVEY MAY 21, 1988 W-35 _ COMPUTATION..DATE ................... PRuDHOE B~ MAY 23, 198m JOB NUMBER AK-BO-80045 ALASKA KELLY BUSHING ELEV. = ?0.77 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE oUB-oEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ') DEPTH . DEF'TH DEPTH .......... NORTH/SOUTH .............. EAST/WEST DIFFERENCE CORRECTION : ...... 8477 7590.77 7500. 8609 7690.77 7600. 8744 7790.77 7700. 8883 7890.77 7800. 9022 7990.77 7900. 9160 8090.77 8000. 9296 8190.77 8100. 9432 8290.77 8200. 9568 8390.77 8300. 9702 8490.77 8400. 9833 8590.77 8500. 9964 8690.77 8600. 10092 8790.77 8700. 10219 8890.77 8800. 10344 8990.77 8900. 10466 9090.77 9000. 10589 9190.77 9100. 10620 9215.16 9124. O0 1175.31 S 2631 21 W o,-, ~-~- %..'i.~ 6 · *~' - . ._-0 37 O0 1181.79 S 2717.51 W 91'-' ?, ..... o ...7 c:Z .= .................... * . · ....................... · O0 1187 '--'= S ..'-oOL~'-'-~'' ~ . ~=,.'--"-' W '-?.=,'-~. 71 '-'= · ~ o~! ...~_.... · , .-", -J 1.-','" 00 1193.02 S 2904.69 W :792.78 39.07 00 ......... 1199 ., 43 ., S 3001 16..,W ............. 1031.87 .................................... 39.10 O0 1204 55 ~; --,.-.o= · ,_ or, 7,.,. 46 W 10Ag... 43 37. ._.=,'= O0 1 O0 .............. 1 O0 1 O0 1 O0 O0 1 O0 1 O0 1 O0 1 O0 O0 39 · ~.-.o 03 S 3187. ..' ~..I ~, · 21.0· 89._S ...... 3279· 213.38 S 3372. 215.14 S 214.89 S 212.75 S 210.64 S 208.51S 205.66 S 54 W 11¢= }._,, 41 3Pl. 72_W ................ 1141.44 36.04 24 W 1177 70 :q/-, '-'/- 3460. '.'?9 W 1';"11. 4:3 ..:,o'-"~'. 72 3546.37_W .......... 1242.92 31., 49 3630.18 W 1273.41 30.49 · '-"~ 50 3710.83 W 1301 91 --'~. 3788.44 W .......... 1328. ,... =' 1 ....................... 26.60 .............................. - ............ 3863.16 W 1 o=..-, ) ..... ....... .:,. 37 24.87 393F: 37 W 1~75 6,2 i."/. ~.._ __ 4004.44 ~, W ................ 1398.39 22.77 40'-'~ 29 W 1404 84 6.45 ~- -'",-~ · · 1202.00 S 1198.02 S 1197.31S THE CALCULATION PROCEDURES USE A.LINEAR_..INTERPOLATION BETWEEN .................................................... THE NEAREST 20 FOOT MD (FROM RADIUS OF CL;RVATURE) POINTS SPERRY -SUN SCALE ;- 1 INCH TO 500,00 / 500.0 PRUDHOE BAT STANDARD AK PRODUCT]SN CO. N-35 HAT 21, 1988 AK-B8-8004S TRUE NSRTH -ss~o. oo -soho. oD -~sbo. oo ,-~obo. ,o. oo --500.00 --1000.00 --1500.00 HO8 !ZONT,qL PROJECTION -.SUN 0.00 2000.00 SCALE :- ! INCH TO 2000.00 / 2000.0 PBUOHOE BAY STANDARD AK PBODUCTION CO. N-35 HAY 21. 1988 RK-B8-80045 4000.00 6000.00 8000.00 ~2ts.~~ ~10620 lOOO0. O01 i ~o~0. oD4ooo. OD6o0o. OD V~RT I CAL. PROJECT m ON ~r TELECO1 Teleco Oilfield Sen ~ of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 May 2, 1988 JOB #623 STANDARD ALASKA PRODUCTION CO. WELL: W-35 EILEEN WEST END RIG: AUD #3 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Standard'AlaSka ProdUction Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures A ,~,,#~'1' COMPANY TELECO OILFIELD SERVICES JOB 623 SURVEY CALCULATIONS Date Page 04/29/88 -~ompany: ~ell: 5ocation: ~ig: STANDARD ALASKA PROD. W-35 EILEEN WEST END A.U.D.I. #3 CO. ~ELECO Job # 623 TAK ~rid Correction: {agnetic Declination: ~otal Correction: ?roposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 254.01 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' TIE IN TO GREATLAND SINGLE SHOT 2665.00 0.5 5.0 N 05 00 E 2664.84 11.31 22.80S 5.27W 23.40 S 13.015W 0.000 TELECO MWD SURVEYS 2928.00 6.2 238.9 S 58 54 W 2927.48 21.63 27.18S 14.71W 30.91 S 28.430W 3.581 3022.00 8.2 236.5 S 56 30 W 3020.73 32.94 33.48S 24.67W 41.59 S 36.390W 2.151 3082.00 9.0 235.1 S 55 06 W 3080.06 41.46 38.52S 32.09W 50.14 S 39.799W 1.378 2833.00 2.8 237.2 S 57 12 W 2832.78 14.47 23.24S 8.39W 24.71 S 19.859W 2.348 2731.00 0.5 269.9 S 89 54 W 2730.83 11.57 22.42S 5.61W 23.11 S 14.062W 1.118 rELECO Job # 623 TAK 04/29/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 3149.00 9.9 236.1 S 56 06 W 3146.15 51.90 44.73S 41.17W 60.80 S 42.623W 1.366 3211.00 10.5 236.1 S 56 06 W 3207.17 62.35 50.85S 50.28W 71.52 S 44.678W 0.968 3270.00 11.9 236.8 S 56 48 W 3265.04 73.27 57.19S 59.83W 82.77 S 46.296W 2.384 3354.00 13.6 237.9 S 57 54 W 3346.97 91.03 67.19S 75.44W 101.03 S 48.312W 2.044 3449.00 15.8 237.5 S 57 30 W 3438.85 114.17 80.07S 95.82W 124.87 S 50.117W 2.318 3540.00 17.8 238.9 S 58 54 W 3525.96 139.47 93.93S 118.17W 150.95 S 51.521W 2.242 3633.00 19.7 238.6 S 58 36 W 3614.02 168.31 109.43S 143.73W 180.65 S 52.714W 2.046 3727.00 22.3 238.2 S 58 12 W 3701.77 200.75 127.08S 172.41W 214.19 S 53.607W 2.770 3822.00 24.9 237.9 S 57 54 W 3788.82 237.32 147.21S 204.68W 252.12 S 54.276W 2.740 3916.00 27.2 236.8 S 56 48 W 3873.27 276.86 169.48S 239.44W 293.35 S 54.709W 2.500 4010.00 29.7 236.1 S 56 06 W 3955.91 319.55 194.22S 276.76W 338.11 S 54.939W 2.683 4107.00 31.6 238.9 S 58 54 W 4039.35 366.96 220.79S 318.46W 387.51 S 55.266W 2.450 4165.00 32.3 241.0 S 61 00 W 4088.57 396.73 236.16S 345.02W 418.11 S 55.609W 2.264 4213.00 33.4 240.7 S 60 42 W 4128.89 422.08 248.84S 367.76W 444.04 S 55.916W 2.317 4310.00 34.1 241.7 S 61 42 W 4209.54 474.63 274.80S 414.99W 497.73 S 56.488W 0.921 4403.00 34.7 241.0 S 61 00 W 4286.28 525.89 299.99S 461.09w 550.10 S 56.951w 0.773 4491.00 35.9 240.7 S 60 42 W 4358.09 575.41 324.76S 505.51W 600.84 S 57.281W 1.378 PELECO Job # 623 TAK 04/29/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 4681.00 36.2 242.4 S 62 24 W 4511.71 684.59 378.03S 603.81W 712.39 S 57.951W 0.550 4867.00 36.6 242.1 S 62 06 W 4661.42 792.64 429.42S 701.49W 822.49 S 58.527W 0.235 5155.00 36.9 242.4 S 62 24 W 4892.18 961.33 509.65S 853.98W 994.50 S 59.172W 0.121 5447.00 37.3 243.1 S 63 06 W 5125.08 1134.07 590.29S 1010.56W 1170.34 S 59.710W 0.199 5632.00 37.2 242.1 S 62 06 W 5809.00 36.9 242.1 S 62 06 W 5999.00 36.0 242.1 S 62 06 W 5272.33 1243.83 641.82S 1109.97W 1282.18 S 59.962W 0.332 5413.60 1348.19 691.69S 1204.25W 1388.76 S 60.128W 0.172 5566.43 1458.66 744.47S 1304.04W 1501.58 S 60.278W 0.474 6281.00 34.7 242.1 S 62 06 W 5796.43 1618.32 820.75S 1448.26W 1664.66 S 60.459W 0.461 5377.00 34.2 242.4 S 62 24 W 5875.59 1671.49 846.04S 1496.32W 1718.94 S 60.516W 0.550 5470.00 33.7 242.4 S 62 24 W 5952.74 1722.37 870.08S 1542.36W 1770.85 S 60.572W 0.538 5584.00 33.9 248.8 S 68 48 W 6047.47 1785.07 896.26S 1600.08W 1834.00 S 60.745W 3.127 5756.00 34.8 253.0 S 73 00 W 6189.48 1881.95 928.01S 1691.77W 1929.58 S 61.253W 1.474 ~946.00 33.8 253.3 S 73 18 W 6346.43 1989.01 959.05S '127.00 34.2 255.4 S 75 24 W 6496.49 2090.22 986.35S 1794.25W 2034.48 1891.70W 2133.41 S 61.875W 0.534 · S 62.462W 0.685 '411.00 33.6 256.9 S 76 54 W 6732.21 2248.51 1024.27S 2045.49W 2287.61 S 63.401W 0.362 ~694.00 34.6 257.9 S 77 54 W 6966.55 2406.89 1058.87S 2200.33W 2441.86 S 64.302W 0.405 ,069.00 36.3 264.6 S 84 36 W 7272.02 2622.52 1091.94S 2415.16W 2650.54 S 65.671W 1.130 TELECO Job # 623 TAK 04/29/88 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 8353.00 39.6 266.0 S 86 00 W 7495.94 2793.76 1106.25S 2589.20W 2815.63 S 66.865W 1.201 8539.00 41.0 267.8 S 87 48 W 7637.79 2911.03 1112.75S 8727.00 43.2 268.5 S 88 30 W 7777.27 3033.24 1116.82S 8915.00 44.2 268.5 S 88 30 W 7913.19 3158.97 1120.14S 9010.00 44.1 268.5 S 88 30 W 7981.35 3223.03 1121.84S 2709.32W 2928.93 2835.29W 3047.32 2965.13W 3169.66 3031.28W 3232.21 S 67.671W 0.979 S 68.500W 1.196 S 69.305W 0.532 S 69.691W 0.118 9104.00 43.5 268.8 S 88 48 W 8049.20 3285.98 1123.37S 3096.32W 3293.81 S 70.059W 0.676 9202.00 43.0 270.2 N 89 48 W 8120.58 3350.69 1123.95S 3163.46W 3357.20 S 70.440W 1.104 9291.00 42.9 270.9 N 89 06 W 8185.72 3408.82 1123.37S 3224.10W 3414.21 S 70.790W 9385.00 42.8 270.6 N 89 24 W 8254.63 3470.03 1122.53S 3288.02W 3474.36 S 71.150W 0.548 0.242 9834.00 40.3 273.4 N 86 36 W 8589.24 3755.59 1115.06S 3587.22W 3756.53 S 72.732W 0.942 9663.00 41.4 271.6 N 88 24 W 8459.89 3649.53 1119.94S 3475.48W 3651.47 S 72.139W 1.341 9567.00 42.5 270.6 N 89 24 W 8388.50 3588.19 1121.17S 3411.32W 3590.84 S 71.806W 0.167 . F- Q... W n ...J .< U TELECO OilFi~ld Smrvicms VERT I CAL PROJECT I ON 0 1000 2000 3000 4000 5000 2000 -"--'--, +--"~-,- = '.----r-q-"LL--F---T'nT-T'-.=;r-./---IJL"J' '.'"' ',,1 .... -~,-' I ~ I ~ ~ ,~, , ' ' ~ .......... . . .... , ............. ~ ..... ~ -~:--~-~ ~._~.,. ~ ~ _ ~ ~" lla e~ ~q. . , ~ ~ : , ' ; i :. -~-~ .......... ?-.-~-~.--~ ..... ,A, LU .... ~ ~ .. ~ , I , ' ~~"- ~ .... ~ ..... , i ' 1 . ~ , ~ ~ ~ ~ :' ' ~ , ~ i ~ P. ~ /' , , ..... t--F .... [' ~--m--~ .... ~'-'~-'~ ....... ~--'-~-e--~ ..... ~---~-~---~--~ ........... ~-~-~- m ~ ~ ...... ~. ' ~ ' · i ' .... ._..~ · ~ ~ ~ ~ , J , , ~ , X · / ,;..: . ,, ~ I H [ l ' t ; : ,. , r j , . .-- ~i ~, ~, ~, ~m.. I t ; . ~,, t L ' -- ' I i '. ' I ' ' , ' L t ' J ..~ t IN I , , ~ I I · ~ i : i / ; ~ :,, = .-~ · ~ f ~ _~ l,,..~ ~ 1 .... ~ ~ ~ , ~ ~ / ~ ' /' 't ! ,x ~-'--i--t-' ~'r~-~ ~~m--~'~---~ ' . 741'~ ~ ~ '. t t ~ ' .... ........ --~ , ' - '"-~-'F--T-'T'~- ~~' ' ....... , ,., ..... -==-.-, ....... 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I,. f..~l II:: F'RUDHOE BAY I... 0 C A T I 0 N A AL488-D10 MWD & SINGLE SHOT 5/02/88 ,,.~ 0 B NI...!I'I t~', E R T Y I::' iii: S U R V E ¥ D N A i'i Iii: T I TI., E ..c..: :1; G N A 'l" U R E 395 FT 9834 FT [) E P "t' H I N T E R V A I... I::' R 0 M T 0 4-13-88 4-28-88 I:) A '1" E S U R V ii!: Y 'i" A l'(lii: N F:' R 0 M 'Ir' 0 THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO ~YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING,I~Z: Client .............. : STANDARD ALASKA PRODUCTION CO. Well ................ : WEST EILEEN WELL N W-35 Closure D~ectton...: S 74.01W Mognett¢ Decltnotlon: 30 deg 8 min E Doto file nome ...... :. B:WW3SD.DAT RECORD OF SURVEY IWe11 ossumed ve~tico] to 5/02/8 Computotlon: RADIUS OF CURVATURE Su=vev dote: 4/14/88 Method ..... : MWD & SINGLE SHOT RKB Height.: 99.? ft 0.0) MEAS DRIFT TRUVERT ~ I mLBSEA SECTION DIRECTION RELATIVE COORDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD 0 0 0 O.O0 -.99.88 0.00 N 0.00 E 0.00 N 395 0 15 3~5.00 295.12 -0.12 S 24.00 E 0.79 S 885 0 30 884.99 785.11 1.62 S 66.00 W 3.48 S 1385 0 45 1384.96 1285.08 6.05 S 16.00 W 7.47 S 1800 0 45 1799.~2 1700.04 9.49 S 31.00 W 12.44 S 0.00 E 0.35 E 0.68 W 4.15 W 6.31 W 2300 0 45 2299.88 2200.00 11.32 S 29.00 E 18.69 S 2665 0 30 2664.86 2564.98 11.25 S S.O0 E 22.47 S 2731 0 30 2730.85 2630.97 11.68 S 89.90 W 22.84 S 2833 2 48 2832. 81 ~==~,~. 93 14 . 58 S 57 . 20 W 23. 66 S 2¢28 6 12 2927.50 2827.62 21.75 S 58.80 W 27.61S 6.42 W S.26 W S.61 W 8.39 W 14.71 W 3022 8 12 3020.75 2~20.87 3082 ? 0 3080.08 2¢80.20 3149 9 54 3146.17 3046.29 3211 10 30 3207.19 3107.31 3270 11 S4 32~5.06 3165.18 33.05 S S6.S0 W 41.57 S SS.lO W S2.01 S S6.10 W 62.45 S S6.10 W 73.38 S 56.80 W 33.92 S 38.96 S 45.17 S S1.30 S 57.63 S 24.66 W 32.08 W 41.16 W S0.27 W S9.82 W 3354 13 36 3346.~? 3247.11 3449 1S 48 3438.87 3338.99 3540 17 48 3525.~8 3426.10 3633 17 42 3614.05 3514.17 3727 22 18 3701.79 3601.91 91.12 S 57.S0 W 114.23 S 57.S0 W 139.54 S 58..90 W 168.38 S 58.60 W 200.82 S 58.20 W 67.69 S 80.64 S 94.50 S 110. O0 ~e 127.65 S 75.39 W 95.72 W 118.08 W 143.63 W 172.32 W 3822 24 S4 3788.84 3688.96 3916 27 12 3873.29 3773.41 4010 29 42 3955.93 3856.05 4107 31 36 4039.37 3939.49 4165 32 18 4088. S? 3988.71 237.38 S 57._90 W 276.93 S S6.80 W 319.62 S 56.10 W 367.02 S S8._90 W 396.7_9 S 61.00 W 147.78 S 170. OS S 194.80 S 221.38 S 236.73 S 204. S9 W 23.9.34 W 276.66 W 318.36 W 344.93 W CLOSURE DISTANCE DG ~ S 0.00 N 0 0 0 E 0.86 S 24 0 0 E 3.55 S 11 6 52 W 8.55 S 29 3 1.9 W 13.95 S 26 S4 2 W 19.76 S 18 57 30 W · 23.07 S 13 11 8 W 23.52 S 13 47 45 W 25.11 S 1_9 30 60 W 31.29 S 28 2 27 W 41.93 S 36 1 _9 W S0.47 S 39 28 6 W 61.11 S 42 20 7 W 71.82 S 44 25 11 W 83.06 S 46 4 3 W 101.32 S 48 4 58 W 125.16 S 49 53 19 W iS1.23 S S1 19 45 W 180._92 S S2 33 7 W 214.45 S S3 28 8 W 252.38 S 54 9 31W 293.60 S S4 36 25 W 338.36 S 54 SI 3 W 387.75 S SS 11 1_9 W 418.35 S SS 32 1S W DOG LE de~/~O 0.00 0.06 O.OS O.OS 0.00 O. 00; O. 06~ 0.01 3.57: 2.12~ I. 1_ 34, o 02, o 31~ ~ 20; 2.04: 2.76' 2.73' 2.45~ 2. 2. 1. S8~. WEST E ILEEN WELL ff W-3S 5/02/88 RECORD OF SURVEY MEAS DEPTH DRIFT TRUVERT SUBSEA SECTION DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 4213 33 24 4128.91 4029.03 4310 34 6 4209.56 4109.68 4403 34 42 4286.30 4186.42 449I 35 S4 4358.12 4258.24 4681 36 12 4511.73 4411.85 422.14 S 60.70 474.69 S 61.70 S25.96 S 61.00 S75.47 S 60.70 684.65 S 62.40 249.41S 367.66 W 275.37 S 414.89 W 300.56 S 461.00 W 325.33 S S05.41W 378.60 S 603.71 W 4867 36 36 4661.44 4561.56 792.71 S 62.10 W S1SS 36 S4 4892.20 4792.32 961.41 S 62.40 W S447 37 18 S12S.IO S025.22 1134.15 S 63.10 W S632 37 12 S272.36 S172.48 1243.92 S 62.10 W 5809 36 S4 S413.62 5313.74 1348.26 S 62.10 W 429.99 S S10.22 S S90.87 S 642.40 S 692.31 S 701.39 W 853.87 W 1010.48 W 1109.90 W 1204.14 W S999 6281 6470 36 0 5566.45 S466.57 34 42 5796.46 5696.58 33 42 S952.77 S852.89 33 54 6047.50 5947.62 34 48 6189.51 6089.63 1458.72 S 62.10 W 1618.36 S 62.10 W 1722:36 S 62.40 W 1785.06 S 68.80 W 1881.95 S 73.00 W 745.13 S 1303.91 821.47 S 1448.09 870.93 S 1548.11 897.18 S 1599.83 928.87 S 1691.52 6946 33 48 6346.46 6246.58 1989.00 S 73.30 W 959.90 S 1793.99 W 7127 34 12 6496.52 6396.64 2090.21 S 75.40 W 987.21 S 1891.45 W 7411 33 36 6732.24 6632.36 2248.49 S 76.90 W 1025.12 S 2045.24 W 7694 34 36 6966.58 6866.70 2406.87 S 77.90 W 1059.73 S 2200.07 W 8069 36 18 7272.05 7172.17 2622.51 S 84.60 W 1092.80 S 2414.91 W 8353 39 36 7495.97 7396.09 2793.75 S 86.00 W 1107.11 S 2588.94 W 8539 41 0 7637.82 7537.94 2911.01 S 87.80 W 1113.61 S 2709.06 W 8727 43 12 7777.30 7677.42 3033.23 S 88.50 W 1117.68 S 2835.03 W 8915 44 12 7913.22 7813.34 3158.98 S 88.S0 W 1121.08 S 2964.87 W 9010 44 6 7981.38 7881.S0 3223.05 S 88.50 W 1122.81 S 3031.02 W 9104 43 30 8049.23 7949.35 3286.00 S 88.80 W 1124.35 S 3096.06 W 9202 43 0 8120.61 8020.73 3350.70 N 89.80 W 1124.93 S 3163.20 W 9291 42 S4 8185.75 8085.87 3408.83 N 89.10 W 1124.35 S 3223.84 W 9385 42 48 8254.67 8154.79 3470.05 N 89.40 W 1123.S1 S 3287.76 W 9567 42 30 8388.53 8288.65 3588.23 N 89.40 W 1122.22 S 3411.06 W CLOSURE DISTANCE E~ MN S 444.28 S SS SO 54 W 497.96 S.56 25 36 W 550.32 S S6 S3 46 W 601.06 S S7 13 49 W 718.61 S 57 54 27 W 822.71 S S8 29 22 W 994.72 S 59 8 26 W 1170.56 S S9 40 60 W 1282.40 S S? 56 16 W 1388.97 S 60 6 14 W · 1501.79 S 60 1S 14 W 1664.87 S 60 26 S W 1771. OS S 60 32 37 W 1834.20 S 60 43 S W 1929.77 S 61 13 39 W 2034.65 S 61 S1 1 W 2133.58 S 62 26 19 W 2287.76 S 63 22 44 W 2442.00 S 64 16 S1 W 2650.66 S 65 39 8 W 2815.73 S 66 SO 49 W 2929.02 S 67 39 14 W 3047.39 S 68 2_9 1 W 3169.74 S 69 17 14 W 3232.30 S 69 40 24 W 3293.89 S 70 2 29 W 3357.28 S 70 25 23 W 3414.28 S 70 46 24 W 3474.43 S 71 8 0 W 3590.92 S 71 47 21W E. DG LE deq/lO 2.2.~ O. 7~ O. 35 O. 22 0.11 O. 16 0.20 O. 16 0.47 0.46 O. S3 1.75 O. 95 0.'S2 0.26 O. 37 0.77 I. 17: O_ 86 1.18 O. S3 0.10 O. 65, O. 83 O. 38 O. la O. 16: ~EST EILEEN ~ELL ~ S/02/88 RECORD OF SURVEY NEAS DRIFT TRUVERT SUBSEA SECTIC~ DIRECTION RELATIVE COORDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD ~&~3 ~1 24 8~S~.~3 83~0.0S 3~.57 N 88.~0 W 1120.~ S 3~75.22 W ~83~ 40 18 8S8~.27 8~8~.3~ 3755.~3 N 8~.~0 W 111~.11 S 358~.~ W CLOSURE DISTANCE DG ~ S 3~S1.SS S 72 ? 1~ W 37S~.S? S. 72 42 S8 W DOG LEC 1~23: 0.78( WEST EILEEN WELL N W-3S ' DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH S/02/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 100 100 0 0 0 200 200 100 0 0 300 300 200 0 0 400 400 300 0 0 SO0 SO0 400 0 0 600 600 500 0 0 700 700 600 0 0 800 800 700 0 0 900 900 800 0 0 1000 1000 ~00 0 0 1100 1100 1000 0 0 1200 1200 1100 0 0 1300 1300 1200 0 0 1400 1400 1300 0 0 1SO0 1SO0 1400 0 0 1600 1600 1SO0 0 0 1700 1700 1600 0 0 1800 1800 1700 0 0 1.~00 1900 1800 0 0 2000 2000 1900 0 0 2100 2100 2000 0 0 2200 2200 2100 0 0 2300 2300 2200 0 0 2400 2400 2300 0 0 2500 2500 2400 0 0 2600 2600 2500 2700 2700 2600 2800 2800 2700 2900 2~00 2800 3001 3000 2900 RELATIVE COORDINATES FROM WELL-HEAD 0.04 N 0.04 W 0.04 N 0.22 W 0.24 S 0.44 W 0.81 S 0.36 E 1.21 S 0.~3 E 1.57 S 1.07 E 1.82 S 1.67 E 1.91 S 2.39 E 3.54 S 0.80 W 4.01 S 1.60 W 4.66 S 2.38 W 5.49 S 3.10 W 6.49 S 3.72 W 7.66 S 4.20 W 8.93 S 4.51 W 10.22 S 4.74 W 11.52 S 4.8? W 12.83 S 4.9S W 13.62 S 6.86 W 14.B.~ S 7.16 W 16.20 S 7.18 W 17.48 S 6.93 W 18.69 S 6.42 W 19.74 S S.75 W 20.62 S 5.04 W 21.31 S 4.30 W 22.72 S S.11 W 23.14 S 7.11 W 26.25 S 12.31 W 32.32 S 22.21 W WEST EILEEN WELL ~ W-3S ' DATA INTERPOLATED FOR EVEN 100 FEET OF SLIBSEA DEPTH S/02/88 NEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3102 3100 3000 2 1 3204 3200 3100 4 2 3306 3300 3200 6 2 340.9 3400 3300 .9 3 3513 3500 3400 13 4 3618 3600 3500 18 S 3725 3700 3600 25 7 3834 3800 3700 34 .9 3.946 3.900 3800 46 12 4061 4000 3.900 61 1S 4178 4100 4000 78 17 42.98 4200 4100 .98 20 4420 4300 4200 120 22 4S43 4400 4300 143 23 4~66 4S00 4400 1~6 23 47.91 4600 4S00 1.91 2S 4.91S 4700 4600 21S 24 S040 4800 4700 240 2S S 165 4.900 4800 265 25 S2.90 SO00 4.900 2.90 2S S4iS SIO0 SO00 315 25 SS41 S200 S 100 341 26 S666 S300 S200 366 25 S7.92 S400 S300 3.92 26 S.916 SS 00 S400 416 24 8040 S600 SSO0 440 24 6163 S700 S600 4G3 23 6285 S800 S700 485 22 ~406 S.900 S800 S06 21 6S27 6000 S.900 S27 21 RELATIVE COORDINATES FROM WELL-HEAD 40.7.9 S 34.6.9 W SO.SS S 4.9.15 W 61.80 S 6~.15 W 74.~1 S 86.73 W ~0.4.9 S 110..90 W 107.40 S 139.36 W 127.25 S 171.66 W 1SO.SS S 208.9.9 W 177.7S S 2S1.06 W 20.9.40 S 2.97.81 W 240.23 S 351.23 W 272..91 S 408.7.9 W 305.17 S 46.9.30 W 340.28 S 531.7.9 W 377.04 S S.94.67 W 408.74 S 661.1S W 443.3.9 S 726.68 W 478.44 S 792.SS W 512..90 S 85.9.01 W S48.06 S .925.78 W S83.71 S 616.84 S 652. IS S 687.47 S 722.2d S .9.92. ~2 W 1061.11 W 1128.31 W 11.9S. O0 W 1260.71 W 7S6.37 S 78.9.71 S 822.57 S 8S4.61 S 886.2.9 S 132S. IS W 1388.11 W 14S0.18 W 1SIO. 42 W 1S6.9.60 W WEST EILEEN WELL ~ W-35 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 6/02/88 NEAS. TRU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH DEPTH DIFF. CORRECT 8647 6769 6890 70~0 7131 7252 7372 7493 7613 7735 7858 7980 8104 8231 8358 8489 8623 8758 88~7 9036 9174 9310 9446 9582 9716 6100 6000 547 20 6200 6100 569 22 6300 6200 S90 21 6400 6300 610 20 6500 6400 631 21 6600 6500 652 21 6700 6600 672 20 6800 6700 693 21 6900 6800 713 20 7000 6900 735 22 7100 7000 758 23 7200 7100 780 22 7300 7200 804 24 7400 7300 831 27 7500 7400 858 27 7800 7500 889 31 7700 7600 923 34 7800 7700 958 35 7900 7800 997 39 8000 7900 1036 39 8100 8000 1074 38 8200 8100 1110 36 8300 8200 1146 36 8400 8300 1182 36 8500 8400 1216 34 RELATIVE COORDINATES FRC~ WELL-HEAD 910.42 S 930.96 S 951.10 S 970.45 S 987.78 S 1632.79 W 1698.37 W 1763.75 W 1828.32 W 1893.65 W 1005.18 S 1023.18 S 1035.52 S 1051.44 S 1064.75 S 1958.85 W 2023.43 W 2089.40 W 2155.21 W 2222.79 W 1081.72 S llOl. SSS 1094.81S 1102.71S 1107.34 S 2291.24 W 2359.93 W 2435.81 W 2512. S2 W 2592.21 W 1114.24 S 1115.89 S 1118.24 S 1120.74 S 1123.29 S 2676.44 W 2764.43 W 2856.43 W 2952.02 W 3048.82 W 1125.76 S 1124.1S S 1123.08 S 1122.13 S 1120.19 S 3143.75 W 3236.95 W 3329.49 W 3421.36 W 3510.03 W WEST EILEEN WELL ~ W-35 ' DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH S/02/88 NEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 6000 5567 S4S7 74S.40 S 1304.42 W 7000 6391 6291 968.71 S 1822.76 W BO00 7216 7116 1104.98 S 2370.91 W 9000 7974 7874 1122.63 S 3024.06 W 1000 1000 900 4.01S 1.60 W 2000 2000 1900 14.89 S 7.16 W 3000 2999 2899 32.25 S 22.11 W 4000 3947 3847 192.0S S 272.S6 W SO00 4758 4668 467.24 S 771.S4 W 50O tO00 t500 2000 2500 3000 35OO T 4000 V 4500 D. 5000 5500 6000 6500 7000 7500 SO00 8500 9O00 -500 VERTICAL SECTION tSTANDARD ALASKA PRODUCTION CO. WEST EILEEN WELL # W-35 SECTION AT S 74.0i ~ TVD SCALE: i inch = lO00 feet DEP SCALE: i inch = lO00 feet DRAI~N :5/02/88 Marker Identtftcatton MD TVD DEPRT SURFACEJ A 0 0 o TO} B 9834 8589 3756 0 500 tO00 i500 ~000 2500 3000 I 3500 4000 4500 5000 5500 Harker Identification ~ TVD DEPRT SURF~C£J ~ 0 0 0 TDJ B g834 8589 3756 · HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. NEST EILEEN NELL # W-35 CLOSURE: 3757 ft S 72.7 N DECLINATION: 30.t3 deg E SCALE: t inch = 700 feet DRANN: 5/02/88 350 35O 700 tO50 t400 t750 2tO0 245O 2800 3t50 3500 3B50 4200 4550 3850 3500 3t50 2800 2450 2tO0 t750 t400 tO50 700 350 0 350 Standard Alaska Production Company 900 East Benson Boulevara P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION May 26, 1988 Mr. C.V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mike Minder Re: W-35 (12-21-11-12), Application for Sundry Approval Attached is an Application for Sundry Approval for the above-referenced well. W-35 was drilled from a surface location approximately 35' away (one conductor over) than was approved in the Permit to Drill. Once this error was discovered, Mike Minder of your office was notified. SAPC regrets any inconvenience this has caused. Please direct additional questions to Jim Welch at 564-5840. TO S/J LW/I m Attachment Sincerely, T.O. Stagg PBU Drilling Engineering Supervisor A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Time extension L.~ Change approved program ~i~' Plugging [] Stimulate [] 2. Name of Operator Standard Alaska Production Company 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface (Corrected) 1251' FNL, 1451' FEL, SEC 21, T11N, R12E, UPM At top of productive interval At effective depth At total depth Effective depth: 1. Present well condition summary Total depth: measured true vertical measured Re-enter suspended well [] Alter casing [] Pull tubing r'! Amend order I-I Perforate [] Other [] 5. Datum elevation (DF or KB) KBE= 90.77 feet S. Unit or Property name Prudhoe Bay Unit 7. Well number W-35(12-21-11-12) 8. Permit number 88-33 9. APl number 5 0 - 029-21799 10. Pool Prudhoe Oil Pool true vertical Casing Length Structural Conductor 73' Surface 2625' I nte rm ed i ate 9864' Production Liner 967' Perforation depth: 10620 feet Plugs (measured) feet 10577 feet Junk (measured) feet Size Cemented Measured depth BKB 20" 110' 13-3/8" 2662' 9-5/8" 9901' 7" 9653'- 10620' measured (Subsea) 10312'- 10348' 10365'- 10375' true vertical (Subsea) 8927'- 8968' 8983'- 8898' Tubing (size, grade and measured depth) 4-1/2", 12.6#, L-80 with 4-1/2" tailpipe to 9623'. Packers and SSSV (type and measured depth) 9-5/8" Permanent Packer at 9498'; 4-1/2"SSSV@ 1983 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation N/A 4. If proposal was verbally approved Name of approver S,._,_hSequeat Work :Re~ Da No, Dated....J~.-- Date approved 1~5. I hereby certify t,l~a~t the foregoing is true and correct to the best of my knowledge Signed . -'~'~.,~--e Title PBU Drilling Engineer Supervisor ~ ~ /' // Commission Use Only Conditions of approval Approved by Notify commission so representative may witness IApproval No. [] Plug integrity [] BOP Test [] Location clearance I True Vertical depth BKB ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned ~'-,.,~-~zd' by order of ............. the commission ~,,,~%,/I I II I~OIV1 I~;;I Date Submit in triplicatu DAlLaS INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date: 05/12/88 TO: MOBIL 'ri: 78832 PHILLIPS ,, GEOSCIENCES ARCHIVES -, REFERENCE: SAPC CASED HOLE FINAL LOGS -. The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to thls offlce: A-17 B-5 B-9 B-12 B-29 C-35 C-38 F-10. G-16 G~19 M-7 N-11A R-16 R-27 Collar 04/22/88 HP Statics 05/04/88 Packer Setting Service 05/03/88 Collar CNL/GR C~/G~ c~/¢~ Collar Production CNL/C~ PFC c~/c~ Production CNL/GR Perf. Record CET CBT CWL/C~ 04/28/88 05/08/88 05/05/88 0-5/05/88 04/26/88 05/06/88 05/03/88 04/27/88 05/04/88 05/07/88 05/04/88 05/05/88 05/05/88 05/05/88 05/08/88 :. #1 9350-10206 Atlas 5" #1 11452-11864 Sch 5" #1 8900-9928 Sch 5" #1 9000-9423 Atlas 5" #1 8800-9438 Sch 5" #1 8750-9585 Sch 5" #~ 10300-11136 Sch 5" #1 9600-9989 Atlas 5" #1 9850-10093 Sch 5" #1 10550-11517 Sch 5" #1 8200-9932 Atlas 5" 1 9850-10608 Sch 5" #I 11200-11600 Sch 5" #1 9000-9791 Sch 5" #1 9500-10530 Sch 5" #1 9442-10582 Sch 5" #1 9442-10561 Sch 5" #1 9480-10167 Sch 5" Rece i ved Fou,~ded ;n (le-elond. C~,o. ,n 1870 · J Victoria ge INFOF~4ATION CONTROL Well Records LR2-1 Slandard Ales~a P~oclu¢6on Compony 900 Eos~ Ben,on 8oulevo~d P.O. Bo,~ 196612 Ancho~oge. Alosl, a 99.519-6612 1907} .564-51 I I ARCO EXXON PHILLIPS IO: PDBY Systems (Transmittal Only) ST.~ND~RD ALASKA, PRODUCTION Date: 05/05/88 78800 SYSTEMS (Transmittal & Tape) ARCHIVES SAPC MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a ccpy of this letter and returning it to this office: W-35 OH Final tape 05/01/88 #1 Sch #72720 Tape Pos. #05727 7494.5-10663.5 1600bpi (DIL/BHC/LDT/CNL/MSFL/CASING CNL * EXXON: An Asterisk/~) next to a l~g above me~ould have received the Tapes7 and L~stin~ ' ' service compan~j~~ .thi~ Received ./~~ ~' ~~TI~ Victoria Aldridge ~h A u~,t of the ori~tondo,d ~1 Co--pony Founded in Cle~elond. ~;o. ;n 1870 INDEXED DAL [,iX S ARCO CHEVRON EXXON TO: TE~&CO 2.b\RATttON HOBIL PHILLIPS ATE OF ALASK%- GEOSC I ENC ES REFERENCE: S'TANDARD Al ASKA PP.O[_')/J( T ION Date: 05/03/88 T#: 78789 SAPC OPEN HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by slgning a copy of thls letter and returning it to this office: D~ /~T~!T/STATE: W-35 DIL/SFL 05/01/88 fJl 9904-10625 Sch 5"/2" W-35 BHCS 05/01/88 fJl 9904-10589 Sch 5"/2" W-35 LDT/CNL poro & raw 05/01/88 tJl 7500-10630 Sch 5" Rece i ved Date I)IRECTI ONAL SURVEYS J o b ;(;: .J o bt,. ' ~Victor±a Aldridge .. :,,,, INFORMATION CONTROL Well Records LR2-1 ~.-~M'EMORAN DL, M State uf Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith f)/i~p Commzs s loner ~ ~ z~ THRU: Michael T Minder ~-~~z~. Sr Petroleum Engineer Petroleum Inspector DATE: May 2, 1988 FILE NO: D.ADA. 66 TELEPHONE NO: SUBJECT: BOP Test SAPC PBU W-35 Permit No. 88-14 Prudhoe Oil Pool Saturda_~~ 16 1988: I traveled this date from Standard Alaska produldtion Compa~PBU E pad to W pad to witness the BOP test on AUDI Rig No. 3 at W-35 well. The test commenced at 4:00 p.m. and was concluded at 7:15 p.m. There were no failures, and I filled out an AOGCC BOP test report which is attached. In~ summary, I witnessed the successful BOP test at SAPC W-35 well on AUDI Rig No. 3. Attachment 02-001A (Rev. 8/85) O&G-~4" - 5~84 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Location: Sec fi ' T l.]~ R t~.,~ M [~, ~., D~!.lling Contractor r~-~'. ~ ~ RJ Location, General ~- Well Sign ~,. General Housekeeping /Rig ~ Visual Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves~-~ Check Valve .... 1,~ Test Pressure Representative Permit ~! ~ f~/~Casing Set @ Z~;~5 ft. 8 .¢! ~ Representative ~' ~o~_~]-~iz' ACCUMULATOR SYSTEM Full Charge Pressure ,~P~PCP psig /....--~ Pressure After Closure l~ ~ psig .... ~ Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master / Remote p'/ min~s ec. min I Z. sec. Blinds switch cover "~.~ ,. ~Kelly and Floor Safety Valves Upper Kelly ,,~'[, Test Pressure. , Lower Kelly~ .... Test Pressure Ball Type ~ I,,. Test Pressure Inside BOP ~' ~ Test Pressure Choke Manifold 1 · , Test Pressure ~ No. Valves 1,, I / No. flanges ~ ~' Adjustable Chokes ~-- / ~ydrauically. operated choke Test Time ~> hrs. Test Results: Failures b~ ~_ Repair or Replacement of failed equipment~to be made within days and Inspector/ Commission office notified. Remarks: Distribution orig. - A0&GCC cc - Operator cc - SUpervisor April 7, 1988 Mr. Ted Stagg Endicott Drilling Engineering Supervisor Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit W-35 Standard Alaska Production Company Permit No. 88-33 Sur. Loc. 1286'SNL, 1452'~EL, Sec. 21, TllN, R12E, UM. Btmhole Loc. 2405'S~L, 78'WEL, Sec. 20, TllN, R12E, UM. Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commenczng equipment installation so that the Commission may witness testing before drilling below-the shoe of the conductor pipe. /~~ tru]ly~~~ ~ ~ C. V. Chatterton'* Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF I~HE COloRvIISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work Drill [] RedrillFlllb. Type of well. Exploratoryr-I Stratigraphic TestF! Development OilE] Re-Entry [] Deepen[]1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company KB=92 fee t Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 28262 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1286' SNL, 1452' WEL, SEC 21, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2351' SNL, 5168' WEL, SEC 21, T11N, R12E W-35 (12-21-11-12) KOO683449-G-14 At total depth 9. Approximate spud date Amount 2405' SNL, 78' WEL, SEC 20, T11N, R12E ,~988 /vl~l}l ~' $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28263 78 feet W-39 140 feet 2240 10430MD;9193'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickott depth 2800 feet Maximum hole angle 35.4 o Maximum surface 3330 psig At total depth (TVD) 8800 4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. 80' Surface 110' 110' 8 cu yds concrete 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3720 cu ft Permafrost 12-1/4" 9-5/8" 47# L-80 NCSS 4643 Surface 4673 4500 12-1/4" 9-5/8" 47# L-80 Butt 5067 4673 4500' 9740 8630' 2041cu ft Class G 8 -1/2" 7" 26# L-80 Butt 940 9490' 8427 10430 9193 281 cuft Class G 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 S,r,o,,,ra, R E C E I Conductor Surface Intermediate ~,,P ~:~ Production Liner ~aska 0il & Perforation depth' measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements I-1 21.1 hereby certify/,)th~t thee,, ~,.,....-~ foregoing is true and correct to the best of my knowledge Signed C~~//~/ Title PBU Drilling Engineering Supervisor Date Commission Use Only Permit Number IAPI number IApproval date See cover letter ~'-:¢3 ' 15o- o~'-,~17'2~ I 0Z~/07/88 for other requirements Conditions of approval Samples required [] Yes ~No Mud log required []Yes ,~ No Hydrogen sulfide mea~sures [] Yes ~,~.Ng_ Direct~ona~l survey required ~ Yes [] No Required worki~q/13~ress~re. "~//f°r'lBOP~'~- .l~J~qVI;)1-13,~';L~~J~5M; i-I1 OM; I-I15M; ~/~/~ Other: /"~ by order of Approved by ' ,, Commissioner me commission Date Form 10-401 Rev.~r'2-1-~/5 / Submit iplicate PROPOSEED DRILLING AND COMPLETION PROGRAM W-35 [12-21-11-12] PBU Install and cement 80' of 20" conductor to surface. Install diverter. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-10.1 ppg water base mud in the 12-1/4" hole and a 9.5 ppg water base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2700' and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600'TVDss and an oil column to 8800' TVDss. Directionally drill 12-1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9-5/8", 474/, L-80 Buttress/NSCC casing to within 5' of 12-1/4" TD and cement in two stages, the first stage using Class G cement around the 9-5/8" shoe. The second stage to be downsqueezed in the 13-3/8" x 9-5/8" annulus followed by nonfreezing fluid. Directionally drill 8-1/2" hole to TD. Run 7" liner from TD to 250' inside 9-5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaC1 completion fluid. Test casing and lap to 3000 psi. Perforate well with wireline conveyed tools. Run 9-5/8" production packer on tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be paced 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Tubing Size: 4-1/2", 12.6#,L-80, A/B Mod, Butt, with 8 GLM's. Tailpipe: 4-1/2", 12.6#, L-80, Butt JLW: 4-4-88 PROPOSED DOWNHOLE DIAGRAM WELL W-35 [12-21-11-12] PBU/EWE PROPOSED DEPTH BKB 20" Conductor Ball Valve 110' 2092' 13-3/8" Casing Shoe 17-1/2" Open Hole 2680' 2700' 4-1/2" 12.6# L-80 A/B Mod. Buttress IPC Tubing with 8 GLM's 9-5/8" Packer 9440' 7" Tieback Assembly 9490' 9-5/8" Shoe 12-1/4" Open Hole 7" 26# L-80 IJ4S Liner 9740' 9745' 7" PBTD 7" Liner Shoe 8-1/2" Open Hole 10310' 10430' 10430' PROPOSED DCWNHOLE DIAGRAM WF_~L W-35 [ 12-21-11-12 ] PROPOSED DEPTH BKB PBU 20" Conductor 110 Ball Valve 2092 13 3/8" Casing Shoe 17 1/2" Open Hole 2680 ' 2700 4 1/2", 12.6~, L-80, A/B Mod, BUTT, IPC, with 8 GLM's 5 1/2", 17# , L-80 A/B Mod BUTT, IPC, above 2500' 9 5/8" Packer 7" Tieback Assembly 9648 9698 9 5/8" Casing Shoe 12 1/4" Hole 9948 9953 7" PBTD 10676 7" Liner Shoe 10716 8 1/2" Open Hole 10716 DAW:14-NOV-87 B.O.P. STACK CONFIGURATION 13-5/6 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER 2 IN. KILL LINE GATE GATE I I I ! I I PIPE RAMS I 1 i I BLIND RAMS I I DRILLING SPOOL I PIPE RAMS I ! 4 IN. CHOKE LINE JGATE GATE FLOWLINE GROUND LEVEL 10 3/4" H~ulic operated__x ( ~o" 12" M&X. DRILLING RISER L t 1 20" 2000 PSI WP ANNULAR PREVE~OR DRILLING SPOOL 20" CONDUCTOR PIPE DIVERTER SYSTEM DETAIL DRILL. DEPT. April 1982 NOTE: DIVERTER ~INE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM ~ 10 3/4" manual t~0tterfly valves ~ 10 3/4" 55=~ Buttress 10-3/4" Hydraulic operated Butterfly valve CELLAR ~ 20" D~v?rter S?col w/10 3/4" Side Out] et. Two lines venting 90° apart in directions that insure safe down wind venting, and extending to a point at least 100' (feet) from any potential source of ignition. NOTES 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 2. Manual 10-3/4" butterfly valves, mechanically connected to insure that one valve is fail- safe open at all times. 3. Ail turns are 90° (degrees) and targeted. __$ ISDUAIO: [DRANO23]W35_CLOSAP_SHORT7. LIS; 6 Search Radius= 3000 7 DEGREE LEAD LINE For proposed well' W-35 [12-21-i1-12] Location = ~W-E S-N TVD(SBS) Top 611789.00 59589&7.00 -92.00 Bottom 608187.46 5957377.89 8978.00 · Note' All depths in Feet Below Kellg Bushing 4-APR-l~88 12-40 --- Closest Approach Analgsis --- Date' 4-APR-88 Time' 12'39'53 Page Closest Appeoach WELL I DENT /PROPOSED\ /NEARBY~ CLOSEST ' TVD DEPART TVD DEPART DISTANCE A029-2000800 ½UPST1 A029-2052400 MP1511 W-T A0~9-~177600 W-40 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 6353. 0 2005. 4 9135. ~ 6808. 0 5138. 0 Vertical /PROPOSED\ TVD DEPART 7594.8 2888.0 7497.8 3166.5 459.4 7467.8 2797.7 3379. 9 74. 8 3380. 1 14. I 173. 3 Intersection /NEARBY\ TVD DEPART VERTICAL DISTANCE 6200.1 2683.6 -1260.1 SUMMARY The well which comes closest to the proposed A029-2177600 W-40 well is' Closest approach distance = KICK OFF For this run = 173.3 Feet 2800.0 Feet _$1$DUAIO: [DRANO23]W35_~LOSAP_SHORT7. LIS; 6 4-APR-1988 12:40 --- Closest Approach Analgsis --- Date: 4-APR-88 Time' 12' 39' 53 Search Radius= 3000 7 DEGREE LEAD LINE For proposed well' W-35 [12-2I-i1-12] Location = fW-E S-N TVD (SOS) Top 611789. O0 5958967. O0 -92. O0 Bottom 608187. 46 5957377.89 8978. O0 Note- All depths in ~eet Below Kellg Bushing (BKB) Page 1 WELL IDENT A029-2000800 KUP ST I A029-~052400 MP1511 A029-2103300 W-T A029--'~ 177600 W-40 Closest Approach /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE NO cooRDiNATE 'POINTS WITHIN SPECIFIED SEARCH WINDOW 6353.0 2005.4 9135.9 6808.0 5138.0. 7594.8 2888.0 7497.8 3166.5 459.4 3 79, 9 74 "s 3 so. 1 14. 1 173. 3 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART 7467.8 2797,7 6200. I 2683.6 VERTICAL DISTANCE -1260.1 SUMMARY The well which comes closest to the proposed well is: A029-2177600 W-40 Closest approach distance = KICK OFF ~or this run = 173.3 ~eet 2800.0 ~eet RIG 3 MUD SYSTEM /. HOPPER ALASKA UNITED DRILLING INC. RIG 3 MUD SYSTEM D~WN. BY DAT[ APf~RO~ED : October 1987 I~.tE Ic"'c"ED t .... .o NTS ~-~2 · ~-~l · ~-~0 · W2~ · W-2~ · W-27 · W-2~ · ~-2~ · NORTH LIN[ 0~r SECTION 21 .~ SUMP · W-24 · W-23 · W,22 · W-20 · W-19 · W-t8 · W-I6 · W-15 · W-14 · W-I~ · W- I · W-2 · · W-~ · · W-7 · W-8 · · W-lO · W-Il · W-12 1452' NE CORN. OF SECT. i MORT N WELL PAD'W' i SHEET 2 OF 2 IELL N® l-~ AI'IUILT LDCATED I~ II~ROTRACTED I~:CT. 11 , T. I1 I. , I. E Ir., Ll.M. IURYEYED FOR : ALASKA P'R-ODCKET~CX, CO IIREPARED IY ; [UUKPIK - PI Ug)H OE I&¥ OFFICE: CHKD. t NORTH WELL N" W' :55 LIJ SURFACE LOCATION LAT. = 70° 17' 48.671" LONG. " 149° 05' 41.087" ~ Y · 5, 958,967. 0:5 i X · 611 ,788.97 i A.S. R ZONE 4 1286' 1452' FROM N. LINE SECT. 21 FROM E. LINE SECT. 21 CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I ,AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS Pt. AT REPRESENTS A LOCATION SURVEY MADE IY ME OR UNDER MY IUPERVISION, AN~ THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. SURVEYOR DATE: .WELL PAD'W' I WELL N° W-35 AS-BUILT LOCATED PROTRACTED SECT. Z! , T. II N** , R. IZ E., U.M. SURVEYED FOR : ~1"]1~111~ ALASKA I~ODUCTION ,20 PREPARED. BY ; KUUKPIK - TECHNICAL SERV. INC. PRUDHOE lAY OFFICE II I DATE * NOV, mS, 86 BRAWN BY: B.T. I CHKD. BY; R-iH.- ] ITEM APPROVE DATE (2 thru 8) CHECK LIST FOR NEW WELL PERMITS Company .~/-~P~O Lease & Well No. ,,~/~(~j~ YES NO 1. Is the permit fee attached .......................................... '~ .... (8) (3) Admin ~ (9 thru 13) (10 and 13) (14 thru 22) (5) BOPE '~g.~,~. ~/--~-'Z~ (23 thru 28) (29 thru 31) 2. Is well to be located in a defined pool ............................. ~ .... 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~ , . 5. Is sufficient undedicated acreage available in this pool ............ ~ .... 6. Is well to be deviated and is wellbore plat included ................ ~ .,, 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... 2~_ ....... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~__ Is administrative approval needed ................................... 68 Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ........................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ,~ Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. ~ , ., Does BOPE have sufficient pressure rating - Test to ~OOO psig .. ,~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ............... ,.. 30. Are seismic analysis data presented on shallow gas zone~ ......... ~..~ 31 If an offshore loc., are survey results of seabed conditions pre~ed 32. Additional requirements ............................................. Geo logy: Eng$~,.~,erin$: re~: 02/17/88 11 INITIAL GEO. ' UNiT 0N/OFF POOL CLASS STATUS AREA NO. SHORE ,,, tqm 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. , * AbASKA COMPUTZNG CENTER COMPANY NA~E WEbLDNA~E~, FIEL NAM: STATE BOROUGH AP1 N[J~ER REFERENCE NO PRODUCTION CO, A6A~KA NORTH S60PB 50',0209-21"/99 7303 ,IS ?ape Veri. f **** REEL HEADER D T~ : COMMENT : LIS TAPE, **** TAPE HEADER $~R¥ICE NA~E t EDIT D. ATF : 88/12/ 5 0 T CONTINUATION ~ ~ ~ PREVIOUS TAPE COMPENT ~ bis TAPE, F~ NA~E ~ EDZT ,001 SERVICE : F~iC ERSlON ~ 00~A02 ~T~ ~ 88t12/ 5 ~X AEC S~ZE ~ ~09r6 FIL~ TYPE ~ LO ~AST FILE t W~25, W-25, 5-DEC-i988 15:12 ~P! #50'029'21799 API #50'029-2i799 COMPANY NAME: wFLL: F)ELD) BOROUGH: STATE: AVl NUMBER: STANDARD AbASKA PRODUCTION CO, W'35 (12-21-11-12) PRUDHOE BAY NORTH SbOPF 50-029-21799 LOCATION: 1251' SNL & ~451' WEL SEC?ION: 21 TOWNSHIPt llN RANGE: PERMANENT DATU~ ~Sb EbEVATION) 0 LOG MEASURED FROM KB 90,69 ABOVE PERHA~ENT OATUM DiT,~ LOGGED{ 18,'NOV,,,,88 5/8" 47 bB ~ DRILLER D~PTH OF 9901 BIT SIZ~ 1: 12.25 B..~T SIZE 2i TYPE FLUID IN HOLE: CRUD~ TIME LOGGER ON BOTTOM: 11.20 TOOL NUMBERS{cNC,DR.IOt CAb~UB-]81 4615 JOHNSON ~ HARTZ ATC-CB'I485 TIeD INTO CB? DA?~D ~/~ D~T~ JOB STARTED: 2-DEC-88 dOB R~FERENCE NO: 73030 LDP/ANA: R, SINES THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERbAY$ FIELD PRINTS SCHLUMBERGER bOGS INCLUDED WITH THIS FILE <~DIT,O01>{ FIRST TO bAST R~ADING, 10574' ~~50{) COMPENSAT£D NEUTRON LOG - PAS8 {2 (.PS2) FIRST TO bAST READINGI ~0574' TO 9{5~' COMPENSATED NEUTRON LOG - PASS #3 ~ PS FIRST TO bAST READING~ 10574' TO ~50~) :atlon hist(nE rqer Alaska Computing Center 5-DEC 1988 15=!2 NPH! - HODGES-LEHM. AN AVERAGED ('HLA) FIRST TO 'bAST READING{ 10.574' TO 9850' PAGEI 3 T iBLE TYPE I CONS TUN! VALU DE',~)! DM:CTION CO Company Name Fie:id Name I~1' SNG & 1451' WEb ~tate pt Province count~ D n e APIN .50-029-21799 API. Serial Number.~ TABLE TYPE : CURV DEFY DEPT DEPTH CHANNEl,., N ME TENS NPHT RNR~ FCNL NCNL N~AT CCL GR TFNS ~P~! FCNL NCNL NRAT Tension NEUTRON POROSITY Raw Neutron Ratio (Near/Far) Far CNL OetectorrC~Unts ~ear CNL Detecto punts Neutron Ratio (ND/rD) CC5 ~mplttude Gamma Ray ?ens~on NEUTRON POROSITY Raw ~eutron Ratio (Near/Far) Far CNL Detector Counts Near CN6 Detector Counts Neutron Ratio (ND/rD) CCL l~litude Gamma ay Tension Tape Verificet~on [,istinq chlumherger Alaska C:omPutinO Center 5-DEC-1988 15:12 DEFI R~R~ : Raw Neutro9 Ratlo (Meal/Far) FCNL rat C'NbDetector COUnt NCNL. Near C~b Detector Counts AT Neutron Ratio(ND/FO) N:PH! FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ~* TYPE REPR CODE V'ABUE 66 0 66 0 3 73 136 4 66 1 5 66 6 73 7 65 9 65 11 66 8 12 68 1] 66 0 14 65 FT 15 66 6B 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DFPT FT 349933 00 000 00 0 I ! I 4 68 0000000000 TENS PSi LB 349933 00 000 00 0 { 1 I 4 68 0000000000 ~P~! PSi PU 349933 00 000 O0 0 I 1 ! 4 68 0000000000 5-DEC'198B 15=t2 PAGEI 5 D ORDER # ~..~ ~ ooooo ooo o 0000 O0 0 O0 800 O0 O0 O0 O0 ooooo oo O0000 O0 ~.~.~ ooooo oo NCN~ P$~ O0 000 O0 ooooo oo O0000 O0 ~., .~]~.~ ~.~ ooooo oo ~ ~ ~ oo ooo .~ ~ oo~oo O0 O0 0 FCNL PS 000 0 NCNb ~S] CPS OO O0 CPS O0 000 O0 0 NRAT PS3 3499 0.00 O0 CCh P$3 34991] O0 0 O0 000 O0 0 ~~ ~ ~~ ooooo ooo NR P$4 49933 O0 000 O0 0 1 F~NL P$4 CP& 349933 OO 000 00 O NCNL P$4 CPS 349933 O0 00'0 O0 0 N~AT PS4 349933 00 000 O0 0 CCL P$4 34993.3 00 000 O0 0 GP P$4 GAPI 349933 O0 000 O0 0 NDHT HbA PU 349933 O0 000 O0 0 68 00000000000 68 000000000 I 0000000000 I 0000000000 1 OO00000000 1 0000000000 4 4 ** DATR ** D~P? FCNL:PS! GR,PS1 PCNL,PS~ GP,P$ FCN[? PS~ FCNL,P$4 G~,PS4 DFPT. Fc~ ~ Ps 1 FCNL,PS2 10620 000 -999 250 -909 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS NCNb TENS NCNb TENS NCNb TEN8 NCNb NPHI PS1 "999 PS1 -999 PS2 "999 P82 "999 PS3 "999 PS3 "999 PS4 '999 PS4 -999 HLA 0 10600,000 TENS,PS1 -999 -999.250 NCNb,PSI -999 -999.250 TENS,PS2 -999 -999,250 NCNb,PS2 -999 -9q9,250 TENS,PS3 -999 250 50 ]~o 250 250 25O 250 O0 250 25O ~o 50 5O NPHI NRAT P81 NPHI PS2 NRAT PS NPHI NRA?'P83 NPMIeP$4 NRATeP84 NPHI,P81 NRAT,P6 NPHI,P$~ NRRT,P$ NPHI,PS~ -999.250 RNRA,PSl -999,250 CC5,PS1 -999.250 RNRA,PS2 -999.250 CCL,PS2 -999,250 RNRA,PS3 -999.250 CCh,PS3 -999,250 RNRA.P$4 '999,250 CCh"PS4 -999.250 RNRA.PS1 -Egg,250 CC5.PS1 -999,250 RNRA,P$2 -999.~50 CCb.P&2 -999, 50 RNRA,P$3 "999,250 :999,250 .999~250 ;999,2:50 999'250 "999, '999e2'50 -999 250 -999 250 '999 "999 FCN b. PS 3 FCNL. P84 G~ ~ PSi P~l GP P$4 GR PS4 D~PT FCNL PSI GR PS FCNI, PSi FC~L, PS GR P$3 F~L P~4 G~ PS4 FCCl, .... PS2 G~P$3 FC~,.PS4 GR,PS4 D~PT G~ PSi FCN!, P$2 G~.P$~ FCNL.P$3 GR P$3 FCNL:PS4 GR.PS4 -999 ~250 -'999 50 000 000 19 906 740 500 484 ooo ~6 6S6 10400 000 1042 000 i5 609 1080 000 16 484 11t6 000 ooo ° 15~219 10300 000 1398 000 1,4~4ooo344 13~g 969 000 21 328 ~404 000 27 031, 10200 000 t618 000 24 125 ~537 000 23 891 1564 000 24 156 1548 000 24 391 ,? U .ooo ,000 86,563 1649,000 82.125 !461,000 lo0 063 1447:ooo 130,875 nq Center NCNb 3 TENS NCNb NPNl HbA TENS PS I NCNb PS I NC'Nb TENS PS4 NCNb P84 ~PI.{ l HLA TEN PS! NCN~ TENS PS NCNb TENS, PS NCNb.~$1 TENS,PS4 NCNL,P~4 NP~I,HEA TEN$,PSl NCNb,PS1 TENS P82 NCNb P$2 TENS P83 NCNb PS3 TENS P$4 ~CNb PS4 NPHI HLA TENS P$1 NCNb PS. TENS PSi NCNb P82 TENS P83 NCNb PS3 TENS,PS4 NPHI.HbA TENS, TEN PS2 NCN~iP$2 TEN P83 NCNb~P$3 TENSP84 NCNb PS4 NPHI,HLA 5-DEC-1988 15112 ,,999 ,, 999 -999 0 NRAT,PS3 NR.AT t0 3016 10 2900 25 00.0 NPH: ooo NAA'~ 10 21516 19 000 NPHI PSi 000 NRAT 873 10 5060 23 o0o 0o0 ooo o0o 000 000 000 000 438 NP', NRA~ NPH! NRAT PS PS4 10 5468 10 5412 i0 5576 10 5552 21. 000 000 000 000 000 000 000 000 77'/ NR P81 NPN!PSps~ NRAT NPH! PS NRAT PSi NPM! PS4 NRAT P84 1OO00 5404 000 I0 lO o0o 4900 000 10 000 5160 000 20 166 NPHI,P81 NRAT,PS1 NPHI,PS2 PS NRATip$i NPHI, NRAT,PS3 NPH]eP$4 NRAT,P$4 PAGEr -999. -999, 19, , i: 4 4 4 .. 6'7 8 C C~ 696 .NR:A. PS4 475 082 RNRA., RNR:A ~ RNEA,P8) C<b.P83 RNRA,P84 CCLoPS4 751 RNRA PSi 986 CCh PS 3 2 A PS CCL PS 003 RNRA PS3 885 COb PS3 0?4 RNRA,P$4 031 ECL,PS4 0 O0 3 $86 0 000 920 CCh,PS! 2~.993 RNRA.PS2 885 COb,PS2 6 8 RNRAePS3 7~1 CCh,PS3 929 RNEA,PS4 24~012 COb,PS4 3,361 0,000 3,4~4 0,0 0 ~,564 0.000 PAGEI G~ GR FCNL G~ F~NL G~ P$1, PS4 PS1 P.$4 06~ 000 SO 0 86 ~75 464 67 750 468 000 67 750 000 :'PSI "' 250 ~PS~ ~9 ,PS .. $0 P$3 999 ~06 P$4 446 PS4 49 906 NDH! HLA EN$ ~CNL N:PHI.HLA TEN$, PSi NCNb, ~CNL. TENSi NCNb, P$3 TENS, P84 NCNb PS4 NPH! HbA ~0 26 8 -9 '9 '999 750 250 ;4 - - 99~ RNRA END OF DATA FILE NAME ~ EDIT ,001 SERVICE : FbiC VERSION I O01A02 DATE I 88/12/ 5 MAX AEC S~Z~ ~ 1096 FTLF TYPE : bO LAST FILE ~ **** TAPE TRAILER **** SERVICE NAME ~ EDIT DATE I 88/12/ 5 ORIGIN : FLIC TAPE NAME : 73030 CONTINUATION ~ P~EvIOUS TAPE COMMENT : LIS TAPE, S.A.P.C. W-T5, API #50-029-21799 v'eriflcation 5-DEC'1988 15:12 **** REEL CO'M~ENT TRAILER **** 5 : LIS TAPE, ~.AoP.C. W'25, API #:50-029"21799 ~IS T~PE VCPlFIC~TIDN bISTiMG LVP OIO,H. O2 VERIFICATION b I $ T I N G PAGE ** : EDIT OR:XGIM : REEL ~!A~4E :72720 CO~TI~UATIOM ~ TAPE' ~"35, ~* T~PK HEADER TAPE CONTINUATION Pi~EVI~U$ TAPE :p. · COMMENTS Ibis TA:E., $,A,P,C ~-35, EOF AP1 50'029'21799 hPI 50-029-21799 PATE ~AXI~U~ LENGTH FILE TYP~ PRKVIOUS FILE ,001 1024 INFORMATION RECORDS ** NNEN CONTENTS FN : TOWN: SECT: COUN: STAT: ** CO~E STANDARD ALASKA PRODUCTION CO, W-35 (12-21-!1-12) PRUDHOE BAY NORTH SLOPE ALASKA ~TS ** TYPE 000 000 000 000 000 000 000 000 CATE 000 000 000 000 000 000 000 000 SIZE 030 018 Or2 OO4 0O4 0O2 012 OO6 CODE O65 O65 O65 O65 O65 O65 O65 LVP OIO,H02 VERIFICATIO!~ LISTING PAGE 2 ********************************************************************************* * SCHLLJ~4BERG~i . * ALASKA COmPUTiNG CENT£R * ********************************************************************************* COMP;%,NY STANDARD ALASKA PROOUCTION = PRL)DHOE BAY = NORTH 8bOPE PH tu' L, U 1 D L 0 S S 9.625" O9904'(LO(;GER) - BIT SIZE = 8,5" TO DISPERSED ~7.O S RIfF = 3 . 66 DE ~0,0 R~,~C = 2 52 ~ 71 DF 7,6 C~ RM AT BHT = ~,, 09 ~ 189 EVEN FIN 8TA~,iDOF'F8 A~I.) 2" ~Ubg FI~[)ER USED O:q OI[~; CAbS CURVE I8 CAblPER FROM SFL TOOL: TE~S,DIL CURVE 1,8 FRON MSFL RU'~ ;) LDT/MSFL/CNb/GR~ SEE BHC SONIC LOG FOR TENSION OF DIL/BMC/GR DESCENT; 8GhIC [)O~HOLE GAIN = /1, LVP O~O,,H02 V~IFICaTION LISTING PAGE 3 ~ATRI× DE~SIIY = ,5A~.~D (2 ~) . L, UID DENSITY = ~.0 G/C3,. HDL~; CORRECTION,= ; CN~/GR LOGGED THRU R PAD ORIE~ATIO;~ f'~NSURE PROPE . . · .,.. f CASING TO 7500 - 2' ~A~.MA RAY IS PRESENTED ON DUAL I~DUCCI..]N FIEI~D PRINT, TOOt, TYPt~:S/~,tU~BE:R$ (.DIL/Bt~'~C/GR DESCEt',tT): DIS'1131 DIC 417 SDS 2001 TOOL TYPES/NU~ERS (bDT/C~L/HSf"L/GR ' ' '"':' R~; 4908 ~C o~ N'C ]]~ s~c 13 447 THiS DAtA }~A6 NOT BEEN DEPTH SHIf'TED ' OVERLAYS FIE~D PRINTS SCHLtJ~BE~GE~ LOG,.. INCL, i)DED ~ITH TH~S FILE (EDI ,001)= <SES,~ FlbE EDIT.D02 FOR 2 SAMPLED ~SFb DATA. DUAL INDUCTION 8PHERICADbY FOCUSED bOG (,DIb) FIRST TO LAST READIMG: 10625' TO 9904' MICRD-SPHERICAbLY FOCUSED LOG (,DbT) FIRST TO LAST~READ~NGI i062~ TO 9904' BOREHOLE COMPENSATED SONIC LOG FIRS¥ TO LAST READING: 1)589 LVP OIO.H02 YKRIFICAT!ON LI,ST!NG PAGE 4 * FIRST TO LAS? READING: 1_630 TO 9904 * CO~PENSATED .,~EJTRO~ bOG (~C~L.) * FIRST TO bAST READING: 10592' TO 9904' * C[]~'~PMN6ATED ~qEUTR. O~(~ CASED HOLE bOG & GR (.CHh) * FIRST TO LAST R~ADtNG: 9904' T0"7495" , DATA FORMAT RECORD ** ENTRYB..LOCKS TYPE SIZE REPR CODE: ENTRY 2 I 66 0 4 ! ~b 8 4 73 60 15 I 66 DAI{J~ ~,PEC~VICATIf,iN BbLCK$ ~.NE~ SERVI E SER ICE'V "* UNI]7 APl APl AP1 AP1 Flhg SIZE SPb RE.PR ID ORDER ~ hOG TYPE CbASS MOD DEPT FT O0 000 O0 0 0 4 IENS [>IL LB O0 635 21 0 0 4 FLU DIL OHM~ O0 220 Ol 0 0 4 lhD DID OHg~ O0 120 46 0 0 4 L~ DIL OHab O0 120 44 0 0 4 SP D!L ~¥ O0 OlO O1 0 0 4 GR DIL GAPI O0 ]lO 01 0 0 4 TENS D[,T Lt~ O0 635 21 0 0 4 CAL.S DLT IN O0 000 00 0 0 4 GR DLT GAPI 00 310 O1 0 0 4 TENs BMC LB O0 635 21 0 0 4 T 5HC US/F O0 520 80 0 0 4 R BHC GAPI O0 ]10 O1 0 0 4 TENS LDR LB 00 ~35 2~ 0 0 4 DP~I LOT PU 00 890 O0 0 0 4 DRHO L, DT G/C3 O0 356 Ol 0 0 4 RHOB LDT G/C~ O0 ]50 02 0 0 4 PEF LOT O0 358 O! 0 0 4 OhS LDT O0 000 O0 0 0 4 PROCE6$ CODE (CI'Ab)0 I 68 0000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 O0000OOOOO0000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 LVP OiO,H02 VERIFICATIO,,, LISTING PAGE 5 OSS LOI' O0 000 CPS O0 354 CPS O0 354 O0 ] 54 O0 354 ~o~. ~Ps OD ooo b:~i! ct~s OD ooo ~8HV ~D~' v O0 o00 S.v LDI" v oo ooo REs LDT OH~. O0 NT~ LDT DEGF O0 ~60 H:TEN LDT ~ O0 000 NpH~ C~L PU O0 BqO TNB " C~L oo 420 C N b 00 000 CNL CP~ O0 000 CNL CPS O0 000 CNL CPS O0 000 CNL CPS O0 000 . TE~ CNL [) ~G F O0 660 HTE~ CNL LB 00 000 GR CNb GAPI O0 310 TENS CNL BB O0 635 N p ~ I C ~ L P U 00 890 TN~A C~L O0 420 RTNR CHL O0 000 RCFT C~L C~8 O0 000 RCNT CHh CPS O0 000 CFT~ CHi, CPS O0 000 CNTC C~L CPS O0 000 ~TEM C~L DEGF O0 660 ~ T E N C H L L B 00 000 G~ CPL GAPI O0 O0 0 0 0 O 0 0 4 Oi 0 0 4 O0 0 0 4 O0 0 0 4 o 0 4 0 1 50 (0) 0 4 50 0 0 0 0 0 00 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 00 0 0 4 5o 0 0 4 50 0 0 4 O0 0 0 4 Ol 0 0 4 21 0 0 4 O0 0 0 4 Oi 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 50 0 0 4 O0 0 0 4 Ol 0 0 4 CAL$ 881 CALI GR RTNR CNTC GR RTNR 10663 5000 TENS -999 2500 SP -999 2500 GR -999 2500 TENS -999 2500 PEF -999 2500 LS -999 2500 SS2 -999i2500 MRE$ -999 250() TENS -999 2500 RCFT -999:25()0 ~RF$ -999.2500 TENS -999,2500 RCfT -999 250o SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 GR 2500 TENS 2500 DPHI 50o ODS 500 bU 2500 LSHV 25O0 MTEM 2500 NPHI 2500 RCNT 2500 NTEN -999 2500 NPHI -999,2500 RCNT 4 I 68 00000000000000 1 1 68 00000000000000 I 68 00000000000000 1 I 1 68 00000000000000 i 68 00000000000000 I b8 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I ~8 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 :999,2500 999,2500 TENS -999 2500 DT -999 2500 DRHO -999 2500 -999 2500 LITH -999 2500 SSHV -999 2500 HTEN -999 2500 TNRA -999:2500 CFTC -999.2500 HTEN -999,2500 -999,2500 CFTC -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -264 0000 -999 2500 '999 2500 '264 0000 -999 2500 -999 2500 LVP C~C DEPT CNTC ~EPT GR C~TC GR ~T~ CNTC DEPT CAbS RHOB Lb CALI GR CNTC RTNR C~TC FPT CALS GR RHOB LL ()t0,H)2 VERIFICAIION -999,2500 MTE~ 1O6OO 9 -999 0000 ' "' ' TENS 703 GR " 2 23 8 RCFT 688 MRES CFT 2500 '~,~T E ~ 10500 2 22 161 '208 34 2 4486 34 -999 -999 o000 TENS 3937 SP 375U Ga 0313 TENS 3899 PEF 3750 LS 3'159 882 5078 aRES 4688 TENS 4167 RCFT 3896 ~RES 4688 TENS 2500 RCFT 2500 MTES 10400,0000 12,7066 8,5625 22,1562 2,3955 163,7500 220.0000 8,6875 22,B594 1.9644 4431,5674 22.B594 '999.2500 '999.2500 TENS SP OR TENS PEF LS S~2 TEh$ ~RES TENS RCFT ~TE~ 10300 OOUO 17i9274 8 6953 27.9062 2.4102 153,0000 204,3750 5P TENS PEF L5 552 LISTING -999 6188 0 53 618~ ' 7 27. 3OO 618~ 17.'3A -999 -999 -999 5484 -83 34 5484 2 303 54~4 1759 0 -999 -999 -999 5820 -74 22 5820 2 0 5820 ~118 0 -999 -999 -999 5412 -35 27 5412 2 289 297 ,2500 0000 499 875~ 0000 7422 2500 5000 oo 7410 8955 500 500 2 o 0 (. 0000 0000 4688 0000 6367 7500 2500 8853 0000 5654 8853 2500 250o 2500 0000 7500 8594 0000 2695 75OO 7500 8818 0000 5649 8818 250o 2500 25o0 0000 0000 8437 0000 7793 0000 2500 SF5U DPHI QLS CNT NPH RCN; TEN GR TEaS DPHI Ol,S DU LSHV MTEM ~PH! RCNT MTEM NPMI RCNT HTEN GR TENS OPHI QLS LU LSH¥ MTE~ NPHI RCNT MTEM RCNT HTEN SFLU GR TENS OLS LU LSHV -999.2500 2.975I iLD 73,1875 TENS 6740.0000 DT 10 4688 '0 0044 1 i9, 3881 i94 -999 750 HTEN 857 TNRA 2500 GR 2~,~38'9 ' 313 6520,0000 15.7627 0,0098 284;5000 1467,0000 195.3750 24,g571 4634, 693 195 ~750 -9,99:500 -999,25o0 -999,2500 II.D TENS DT DRHO QSS blTH SSHV HTEN TNRA CFTC HTEN TNRA CFTC GR 15,9994 22,1562 6488.0000 15.4236 '0,0083 294,0000 1468,0000 195,3750 19.1565 4513.1973 195, 750 -999,2500 -999.2500 -999.2500 TENS DT DRHO oas blTH SSHV TNRA CFTC HTEN TNRA CFTC GR 23 7723 27: 9o6 6380,0000 14,5318 0,0098 272.0000 1470.0o00 TENS DT DRHO blTH SSHV PAGE -999.2500 2 6823 6188 000g 83 3112 0 0 0000 0oo0 ~2500 ,2500 -999 2500 2,1040 5484,0000 84 0 102 1345,0000 1193,0000 2,3437 1905,2446 11 0000 99~2500 99,2500 -999 ~ 2500 13 5791 5820 0000 81,5000 0 0170 0 0288 104 8125 I346 0000 1359 0000 2 0317 2268 1416 1359 0000 -999 2500 -999 2500 -999 2500 15,5401 5412,0000 76,5000 '0,0069 -0 0010 85:5625 1346,0000 bVP OlO,H02 VER'IFICAT!UN LISTING PAGE 7 o , C:.A~ I ~R C.NTC S GR ~_HOB GR RTN~ CNTC bb $$I CALl GR CNTC RTNR CNTC DEPT iL~ CALl GR CNTC GR C~TC DEPT 434~ 2500 2500 10200 26 2 4174 26 -999 -999 0000 250 5OO 250o OR DS ~RES TENS RCB, MR:ES TENS RCFT MTEn 10100 6 8 114 2 133 2O6 8 139 1 3802 1~9 -999 -999 0000 TENS 5478 SF 6719 GR 8125 TENS 4944 PEF 6250 bS 2500 682 6406 MRES 0000 TENS 945~ RCFT 1265 MRES 00o0 TENS ~500 RCFT 2500 ~TEH 10000,0000 TENS 4 8105 SP 9.5469 GR 120.1875 TENS 2.6389 PEF 105 3125 LS 204:3750 882 9,5391 MRE$ 131.3750 TENS 3,1944 RCFT 2982.7524 NRE$ 131.3750 TENS -999.2500 RCFT -999.2500 ~TEM 9900,0000 TE~$ 0 0 -999 5484 0000 26 548~ 0000 507~ 312 0000 299 2500 0 898~ 5484 0000 181~ 4248 8989 -999 2500 '999 2500 -999 2500 oooo "62 5313 5139 00o0 648 0000 3 O938 256 O000 286 2500 0 9058 5648 000o 2023 2834 0 9058 -999 2500 -999 2500 -999 2500 5480 0000 0 7495 131 3750 5480 0000 4 1875 206 1250 278 7500 0 9287 5480 0000 961 5507 0 9287 -999 -999 2500 -9g9 2500 5488.0000 MTE~, P~I CNT ~TE~ NPHI HTE~ GR TENS PHI bS ~TE~ NPHI RCNT MTEN NPHI RCNT MT~N SFLU GR TENS DPHI OhS LU LSHV MTEM NPHI RCNT ~TE~ NPHI RCNT HTEN SFbU GR TENS DPHI QLS bU LSHV NTEM RCNT STEM NPH! RC~T HTEN SFLU 194.~500 HTEN 248,6240: C~]TC 194,2500 999~2500 -999.2500 ~FTC '99912500 GR 18,,:2704 1406 0000 419] 19 -999 1706 DR 0 0:005 QS~ TNRA CFTC 2500 GR 9,4722 114,8i25 648~,0000 .4329 1470,0000 190,8750 428 902 19 8750 -99~ 2500 -999 ~500 -999 500 ILD TENS DT DRHO LITH SSHV HTEN TNRA CFTC HTEN TNRA CFTC GR 4,6326 ILD 120 1250 TENS 6520:0000 DT 0,6734 DRHO 0,0034 OSS 201,6250 [,ITH 1472,0000 SSHV 188,5000 HTEN 31'0784 TNRA 2669,9697 CFTC ss. ooo 2~99,2500 T"RA 99,2500 CFTC -999.2500 GR 2000,0000 1229,0000 1229 .999i 15~ 4888 5484 -0 0 -999 ~999 -999 2500 7 4241 5648 0000 78 5000 0 0045 0 0220 75 0625 134b 0000 ~383 0000 1991 23 1383,0000 '999,2500 -999,2500 -999.2500 4,6098 5480,0000 83,0625 0,0182 0 0142 49 3750 1346 0000 1462 7188 2 8964 1052 2480 1462 7188 -999 2500 -999 2500 -999 2500 !~,7q16 bVP 910,H02 VERIFICATIUN 5ISTING .PAGE 8 CNTC CNTC G CALl GR RTNR CNTC GR CNTC DEPT CAL$ GR $51 CALl GR ~TN~ 2000, 0000 ~, 7o0 GR TENS PEF ~RES TENS RCFT MRE$ TENS 9800 -999 4 1559 0000 TENS 0000 TENS 2500 PEF L$ SS2 TENS 2500 RCFT 2500 ~RES TENS RCFT 7503 ~TE~ .2500 :999 2500 999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 0000 1533 3821 TENS SP GR TENS PEF LS SS2 TENS RCFT ~RES TENS RCFT 9600.0000 TENS -999,2500 ~P -999;2500 GR :999.2500 TENS 999.2500 P~iF -999'2500 LS -999'2500 SS2 -999.2500 '4~ES -999,2500 TENS -999.2500 RCFT -116 96 5488 35 548~ 41 8~ ~999 -999 -999 -999 -999 182 -999 -999 999 -999 -999 -999 -999 -999 -999 -999 5224 3O4 180 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 7500 2500 0000 7188 3125 5.,25 9409 000 517 9409 oooo 07~0 6250 2500 250O 2500 2500 2500 250O 2500 2500 2500 2500 0000 4208 7500 2500 250O 25OO 2500 250O 2500 500 5OO 2500 250O 250O 0000 8898 6250 25OO 25OO 25OO 2500 2500 250O 25O0 2500 2500 2500 GR TENS DPH! OLS ~TEM NPH~ ~CN c~ MTEN GR TENS DPH1 hU ~TEN NPHI RCNT ~TER NPHI RCNT HTEN SFLU GR TENS DPHI bU [.SHV MTE~ NPHI RCNT MTE~ NPHI RCNI HTEN SFLU GR TENS DPHI LU bSHV NPHI RCNT 88,9375 TENS 6172 1471 186 -999.25:00 2500 TENS :oooo ,2500 DRHO .2500 QSS :~500 500 ss~v 1504~ 6746 8813 1210~ 0000 CFTC HTEN TNRA CFTC GR 999 2 8 -999 2500 -999 2500 oo -999 25O0 -999 2500 -999,2500 -999,2500 -999.2500 50.7923 1556.5615 1221.5000 ILD TENS DT DRHO OSS SSHV HTEN TNRA CFTC HTEN TNRA CFTC '999,2500 '999,2500 '999.2500 '999,2500 '999'2500 -999,2500 '999.2500 '999.2500 '999.2500 -999.2500 ILD TENS DT DRHO LIT~ SSHV HTEN TNRA CFTC 5488 0000 000 75O 463 '99:9 2500 -999 5:4: -999 -999 4,~727 ]97, 484 80,2500 -999,2500 -999,250O -999 2500 -999 2500 -999 2500 :999 2500 999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 1888 371 5436 76 ~250 -999 2500 -999~2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 bVP OlO,M02 'VERIFICATIOf'~ LISTING PA~E 9 C~TC '999,~ . ( GR '999 250.) TENS ,6i90 RCFT C.~TC 1526,4712 DE]PT OB CNTC ~T~ C~TC 4 t. 7:49 0000 T~N5 2500 $ P TENS PEF L5 MRES T E N S 25 O 0 ~ REo ~' c, 2500 TENS ~2 DEPT CALI C~TC ¢~TC 9400 -999 -.999 999 -999 1754 OO00 TENS 25OO SP 2500 GR 2500 IED$ 2500 PEF 25OO 5S 2500 SS2 2500 ~RF$ 2500 ,.~r rE:~S 250o RCFT 2500 m~ES TKho 500 '~ 000 RCFT 20~7 ~TE~ EPT C~LS RHOB LL CALl ~TNR C~TC G~ RT~ CN?C 9300 -999 -999 -999 -999 -999 -999 -999, -999, ~999, -999 -999: 4, 1697. 000() TENS 2500 SP 2500 G~ 2500 TENS 2500 PEF 250O LS 2500 $$2 2500 ~RES 2500 TENS 2500 ~CFT 2500 2500 TENS 4583 RCF~ 9414 DEPT IL~ CALS ~R ~200,0000 TENS 999.2500 5P -999.2500 GR -99~.2500 TE~S -999,2500 5132,000() 385~4208 17816250 ~250(, ,2500 250{) 2500 2500 250o -999 -999 -999 2500 -999 250(.) -999 2500 5028 0000 466 ~760 174 750 -999 250O -999 250O -999 2500 -999 ~500 -999 500 -999 ~500 -999 500 -999 ~500 5O -999 0 -999 2500 -999 2500 502~ 0000 50 4116 171 6250 -999 2500 -999 2500 -999 2500 -999 250O -999 250O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4992 0000 466 07~0 !68 7500 i9992500 999:2500 999.2500 -999,2500 ~TE~ PHi. C~T I'{TEN SFLU DPHi 055 LSHV HTE~ NPMI RCNT ~TE~ NPHI RCNT HTEN $FLU GR DPMI MTE~ RCNT ~TEg NPHI RCNT HTEN SFLU GR TENS DPHI LU LSHV MTEM NPHI RCNT MTE~ NPHI ~CNT HTEN SFLU GR TENS DPHI -999.2500 HTEN 99, 2500 DT 2500 DRHO 500 500 -999,2500 HTEN 38,8679 TNRA 1688,X58 CFTC I179.437:~ GR 2500 -999. ....(' -999,250) -999.2500 -999 2500 -999 2500 500 500 -9 ]500 3 4864 177~ 5554 12o] 7500 TENS DT DRHO HTEN TNRA CFTC HTEN TNRA CFTC GR '999,2500 '999.2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999:2500 '999,2500 '999,2500 42,0599 1574 7610 1171~2500 ILD TENS DT DRHO USS SSHV HTEN TNRA CFTC HTEN TNRA CFTC GR -999,2500 ILD '999,2500 TENS -999,2500 DT -999,2500 ORHO -99'9. 2500 368; i23,! 78~9375 :999 999 -999 -999 9500 347 501 58 -999 2500 -999 2500 -999 2500 :999 2500 999 2500 -999 2500 -999 2500 :999 2500 999 2500 -999 2500 -999 2500 3.~95 559, 89 45.781~ -999 2500 '999 2500 '999 2500 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 7098 462,9810 53.0000 -999.2500 -999 2500 -999:2500 =999,2500 . '0" " F ~' PAGE I0 · LVP 010 H 2 VER1 ICATIOM LISTING RTNR C~TC RHO8 bb GR .NTC C~TC DEPT CAL$ GR RHOB CALl GR RTNR CNTC GR RT~R C~TC DEPT IbM CALS RHOB SS1 CALI RTNR CNTC ~TNR -999 2500 PEF :999 999 :999 999, ~99~ 2139 E8 RC~T TENS RCFT -999 '999 -999 -999 000TENS 500 se 500 PEF 882 500500 RCFT 2500 TENS ,6000 RCFT ,9490 ~TEM 9000 -999 -999 -999 "999 '999 -999 -999 -999 -999 -999 -999 1606 0000 TENS 2500 SP 2500 GR 5 00 TENS 500 PEF 250 ) LS 2500 862 2500 ~RE8 2500 TENS 2500 mCaT 2500 MRES 2500 TENS 8400 RCFT ,0142 ~TE.~. 8900 oooo -99922500 '999,2500 GR -999.2500 TENS -999,2500 PEF -999.2500 LS -999 2500 SS2 -999:2500 MRE$ :999.2500 TENS 999.2500 ~CFI -999,~500 -999.2500 TENS 3,5!85 RCF'r -999 2999 999 -999 -999 4964 314 166 -99~ -999 -999 -999 °999 -999 -999 -999 -999 -999 4944 337 163 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4848 364 160 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4724 417 25O0 00 500 5OO 2500 250O 0000 9993 1250 25O0 2500 500 500 2500 2500 2500 2500 2500 2500 50o 000 0873 2500 2500 2500 2500 500 ~500 2500 2500 2500 2500 2500 2500 0000 9102 3750 2500 2500 2500 2500 250O 2500 2500 25O0 2500 2500 2500 0000 6680 ~:TE~: ~TEN H T E N SFLU GR LU LSHV MTES NPHI RCNT MTEE NPHI RC~T ~TEN SFhU TENS b$ LU LSHV ~?E~ ~CN? MTE~ NPH! RCNT HTEN GR TENS DPHI OLS bU LSHV ~PHI RCNT ~TE~ NPHI RCNT -999 2500 OSS :999 2500 LIIH soo s:s.v :999 9199 -999 -999 1172 ,2500 ,2500 -999 2500 '999 2500 -999 51 1359 7161 1169 7500 -999.2500 999,250o :999,2500 -999 ~500 -999 500 '999,2500 '999,2500 46,4636 1557,7837 1170,2500 -999,2500 -999,2500 -999 2500 -999i2500 -999 2500 -999,2500 '999,2500 '999,2500 -9 9: 5oo =999 500 '999,2500 37,9534 1725,2227 DT DRMO SSHV HTEN TNRA CFTC HTE~ TNRA CFTC GR TENS OT DRHO LITB SSHV HTEN TNRA CFTC HTEN TNRA CFTC ILD TENS DT ORHO OSS LIT~ SSHV HTEN CFTC HTEN TNRA CFTC -999 2500 -999 2500 -999 2500 4 354 64 5625 -999 -999 :999 999 ~99~ -99~ -999 2500 4 2O89 347 7774 61 2187 -999 2500 -999 2500 -999 2500 -999 2500 ~99 -99~ 2500 2500 -999 2500 -999 2500 -999~2500 -999 2500 -999 2500 403 69 59 0000 -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 ~846 481 7415 hV OlO,HO,2 VERIFICATION LISTING PAGE 11 CNTC ~ 613,6506 8800 GR RHOB RTNR CNTC RTNR CNTC -999 '999 1811 OOOO TENS 250o 2500 2500 TE~S 25O0 2500 500 TENS 250~ TENS 545 RCFT 9041 ~TE~ ~'EPT GR RHOB Lb CAbI GR R?NR GR TC ~700.00o0 999 2500 2500 2500 -999 2500 -999 2500 ~500 2500 2999 2~00 999 2500 3 8571 1649 2532 TELLS SP GR PEF MRES T~NS RCFT ~RES TENS ~CFT ~TEM EPT C L~- ALS SS~ CA~I GR RT~R CNTC GR RTNR C~TC 8600 -999 -999 -999 -999 -999 -999 -999 -999 -999 '999 '999 4 1376 0000 2500 2500 2500 2500 2500 25OO 25OO 2500 ~500 2500 2500 6316 356O TEN5 SP GR TENS PEF b6 SS2 ~RES TENS RCFT MRES TEN5 RCFT DEPT IL~ CALM GR RHO8 Lb $81 ~500 -999 -999 -999 -999 -999 -999 0000 ,2500 ,2500 ,2500 ,2500 ,2500 ,2500 SP TENS PEr' bS 552 158.7500 -999 2500 2500 2500 250() 2500 -999 2500 -gg9 2500 -999 5 0 -9'99 500 oooo 5696 156 8750 -999,2500 -999,2500 -999 ~500 -999 500 2999~2500 99912500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4752 0000 448 12 -999 2500 -999 250O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4728 0000 342 2058 153 7500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 HTEN SFLU TENS DPHI QLS ~S H'V ~TE~ NPHI RCNT MTE~ NPHI RCNT HTEN SFLU GR TENS DPHI GU NPHI RCNT ~TE~ NPHI RCNT HTEN SFEU GR TENS DPHI OhS LSHV MTEM NPHI RCNT MTE~ NPHI RCN? HTEN 8FLU TENS DPHI QLS LU bSHV 1180,1875 GR -999 2500 iLD -999 -999 33 8014 TNRA 1847: 0632 CFTC 1159,7500 GR TENS O0 DRMO -999 ~500 -:999 500 ~999,2500 SS~V 999,2500 HTEN 999 2uO CFTC -999,2500 HTEN ]6,7434 TNRA 17!0,7549 CFTC 1176,4375 GR '999,2500 -999,2500 TENS -999~2500 DT -999,2500 DRHO -999;2500 1999,2500 LITH 999.2500 -999 2500 HTEN -999:2500 -999,2500 CFTC -999,2500 HTEN 50 945] TNRA 1359:7161 CFTC 1197,0000 GR -999,2500 I60 -999,2500 TENS -999,2500 DT -999,2500 DRMO -999,2500 QSS '999'2500 LITH "999,2500 SSHV 47,4688 -999 2500 -999 f~O0 '999 500 37 2500 -999 "999 -999. -999 -999 -999 -999 -992500 -999 2500 3 4182 ~83~'794 39,~93B -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 -999 2500 -999 250O -999 2500 -999 2500 -~99 250O 4,1972 331,6195 60,3438 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 bVP OIO,H02 YE.,IFICATiOt~. LISTING C~TC ~T~ CNTC ,,999 2500 99 2500 TENS 2~oo ~.~ 2500 RCNT -999 2500 MTE~ 4684 0000 NPMI 98 3729 RCN¥ 53 1250 HTEN DEPT ~TNR CNTC GR CNTC 8400 0000 TENS GR -99 ~RE.o '99 TENS RCFT MRE8 -999 2500 T 4 0000 CFI 1420 4038 -999 2500 SFbU -999 -999 -999 -999 -999 -999 -999 -999 46 152 2500 GR 2500 TENS 2500 aP.HI 2500 LU bSHV 250O MT~M 2500 NPHI ~500 RCNT 2500 ~E~ gO00 ~PhI 873 RC~.,T 0000 HTEN DEPT RMO6 Lb CAb! RTNR C~TC G~ RTN~ CNTC 8300 o000 TENS -999 250(..) SP 500 GR 500 TENS -999 2500 -999 2500 LS -999 2500 582 -999 2500 ~RE8 -999 2500 TENS -999 2500 RCFT -999 ~500 -999 ~500 TENS 4 2500 RCFT 1396 4221 ~TE~ -999 2500 SFLU -999 2500 GR :999 999 -999 -999 -999 -999 -999 -999 -999 4612 337 %5O 25 TENS 2500 2500 ~00 hSHV Oo 2500 NPHI 2500 RCNT ~500 0000 NPH! 0873 RCNT 5000 BTEN DEPT I L~ CAbS GR RHOB SSI CALl GR RTNR CNTC RT~R CqTC 8200 0000 TENS -999 2500 SP -999 2500 GR -999 2500 TENS -999 2500 PEF -999 2500 -999 2500 882 -999 2500 TENS -999 2500 RCFf -999,2500 -999,2500 TENS 3,6400 RCFT !.488,7222 -999 2500 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4544 3~4 148 2500 GR 2500 TENS 2500 DPHI 25O0 OLS 2500 LU 2500 LSHV 2500 ~TE~ 2500 NPHI 250o RCNT 250O ~TEM 0000 NPHI 999] RCNT 8750 HTEN DKPT 8 1 00,0000 T£!~,S -999,250o SFLU "O H'~ N '999,250,. ~E. -999,2500 -999,2500 CFTC -999,2500 HTEN 50,4409 TNRA 1354,4380 CFTC 119917500 GR -999 2500 ILD 9 9 blTH ~' ~ ' O "999,250 '999,2500 TNRA -999,2500 CFTC -999'25010 MTEN 47,6]0~ TNRA 1489~9236 CFTC 1185,1250 GR -999 -999 -999~ -999~ :999 999 -999 -999 -999 '999 -999 5O 1422 1182 IhD TENS 500 OT 500 DRHO 500 OSS 500 LITH 2500 SSHv 2500 HTEN 2500 TNRA 2500 CFTC 2500 HTEN 3624 TNRA 1418 CFTC 2500 GR -999 2500 ILD -999:2500 TENS -999,2500 DT -999,~500 DRH(') -999, 500 OS$ i999,2500 LITH 999,2500 SSHV 999.2500 HT~N :999,2500 TNRA 999.2500 CFTC ~999,2500 HTEN 45.2938 TNRA 1523,7083 CFTC 1179,0000 GR -999.2500 ILD PAGE 12 -999 2500 320 6,2 -999 2500 -999 -999 -999 -999 '99'9 -999 2509 58 9062 -999 1500 '999 500 2500 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 1652 334 1483 59 5938 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250O -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 8872 379 6799 67 7500 '999,2500 bVP 010.H02 VERIFICATI[)N hISTING PAGE 13 CALS G~ ~HOB R~ C~TC -999 2500 SP 999 2500 ~999 2500 P~F 500 882 500 MRES 25O0 TENS 2500 ~CFT 2500 2500 TENS 0873 RCFT 9.199 ~TEg -999 2500 GR 250C. 2500 DPH! -999 -999 -999 -999 367 147 QLS ~500 I.,8HV 2500 MTE~ 2500 ~TE~ 0000 NPMI ~C~T GR R~O~ RT~R C~TC RT~R CNTC 8000 0000 TENS -999 -999 -999 -999 -999 -999 -999 -999 -99~ 1478 500 aP 5OO Ga 250() TL~8 2500 P g F 500 bS 500 582 500 ~RE8 500 TENS 500 RCFT 500 ?<aRES 2500 TENS ~429 RCFT 8623 MTE~.'~ -999 2500 SFbU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 445i 3O 146 2500 TENS 2500 DPHI 2500 Ob$ 2500 LU 2500 bSHV 50o MTE~ 500 NPHI 500 RC~T 500 MTEM 000o NPHI 8898 RCNT 5000 HTEN CALS GR RHOB ssi CALl GR ~TNR C~)TC PTNR C~TC 7900,0000 -999.2500 8P -999 250O GR -999 2500 TENS -999 2500 PEF -999 2500 LS -999 250(3 -999 2500 -999 2500 TENS -999 2500 RCFT -999 2500 MRES -999,2500 TENS 4,5556 RCFT 1364.]557 ~TEM -999 2500 SFbU -999 2500 GR -999 -999 -999 -999 -999 -999 -999 -999 -999 4460 145 2500 TENS 2500 DPHI 2500 OhS 2500 LU 2500 bSHV 2500 gTEM 500 NPHI 500 RCNT 2500 ~TE~ 0000 NPHI 9993 RCNT 3750 HTEN DEPT CALS GR R~OB bb SSI CALl GR RTNR 7800 0000 TENS -999 2500 -999 2500 -999 2500 TENS -999 2500 PEF -999 2500 -999 ~500 999,250U NRES 999.2500 999,2500 RCF -999 2500 SFbU -999 -999 -999 -999 -999 -999 -999 -999 -9~9 2500 GR 2500 TENS 2500 DPHI 25O0 OhS 250o LU 2500 bSHV 2500 NTE~ 2500 NPHI 2500 RCNT -999 2500 TENS -999 ~500 ~500 pT -999 500 DaSO -999 ,25oo ,2500 NTEN ~ e " 0 ~ ' ,2500 CFTC -999,250] 42~6149 TNRA 1507,288] ~FTC 11910,6250 GR '999 2500 ILD 500 TENS 500 DT -999 OReO -999 QMS -999 ~500 hlTH -999 500 SSH~ -999 ~500 HTEN '999 2500 TNRA -999 2500 -999 2500 49, 2337 TNRA 1489~9236 CFTC 1!86,5000 GR -999 -999 -999 -999 ~999, 999~ -999 -999 -999 -999 -999 500 IhD 500 TENS ,2500 DT ,2500 DRHO 2500 OSS 2500 LITH 2500 SSHV 2500 HTEN 2500 TNRA 2500 CFTC 2500 HTEN 48.502] TNRA 1359'7161 CFTC 1224.7500 GR -999 2500 -999:2500 TENS -999 2500 VT '999 2500 DRMO -999 2500 -999 2500 LITH -999 2500 -999 2500 HTEN -999 2500 TNRA -999.2500 CFTC 500 5OO -999 -999 -999 2500 -999 -999 - 99 500 5OO -999 2500 -999 2500 60 0625 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 0632 344 7939 61 ~750 -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ZLO0 -999 2500 -999 2500 "'R F .. S bVP 010,H02 V~,, ,I. ICA. TI[){'~ bi TING PIGE 14 CNTC ~.'C -999 500 ~RES -99~ iO0 TEN~ )00 RCFT 1423 0344 i~'rE,,,'~' DEPT CAbS G'R C~iTC RTNR C~TC 7700 -999 -999 -9:99 -999 -999~ 5 I396 0000 2500 SP $$2 ~RE8 TENS ~CFT 2~00 ~;S 2500 T~]NS RCFT 76O0 -999 -999 '999 '999 '999 -999 -999 -999 -999 -999 1,411 O000 TE~S 50{) 500 Ga 2500 2500 PEF 25O 250~ LS 2500 ~RES 2500 TEN8 ~500 ~CFT 2500 2500 TENS 8636 RCFT 209~ DEPT CAbS GR SSI CALl RT~R CNTC GR RTNR CNTC !50~, 0000 TEN5 99 .2500 SP 999,250o :999.2500 -999,2500 PEF -999,2500 -999.2500 SS2 -999.2500 RCFT -999.2500 -999.2500 TENS 4.7647 RCFT 1400.1487 DEPT CALS 494. 5000 TENS 999,2500 SIP 999,2500 G,. '999.2500 'ii'El N $ -999 4388 143 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4348 317 142 -999 -999 -999 -999 -999 -999 -'999 -999 -999 -999 -999 432~ 4[ 1.41 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 308 ~39 -999 -999 -999 -999 ,2500 ., 0000 .205~ ,6250 ,2,500 2500 2500 2500 500 5OO ~5oo 2500 250O 2500 250 t) 0000 750~ 2500 25OO 25OO 2500 250O 250o 2500 2500 25OO 500 5OO 0000 8785 0000 2500 2500 2500 250O 25OO 2500 2500 2500 2500 2500 2500 0000 6039 6250 2500 2500 2500 250o STEM NPHI RCNT HTEN TENS DPH1 hSHV MTE~ ~PHl RCNT ~TE~ NP~I RCNT MTEN SFLU TENS DPHI LSHV MTE~ NPHI RCNT ~TEM NPHI RCNT HTEN GR TENS DPHI OhS bO bSHV STEM NPHI RCNT STEM NPHI ~CNT HTEN S F b U GR TENS PPPl -999 2500 MTEN 1222,0000 GR -999 -999 -999 2500 58 3104 149~ 733 120 ~000 -999 2500 -999 2500 -999 2500 -999.2500 -999,2500 2500 2500 -999 2500 -999 2500 -999 ~500 -999 500 4~ 9134 I4~4 1392 1206 0000 -999 2500 -999 2500 -999 500 -999 ~500 -999 2500 -999 2500 '999 2500 '999 25OO '999.2500 '999,2500 '999.2500 53,9065 382,9204 1999,2500 HT~;N TNRA CFTC GR TENS DT DRHO ITH HTEN TNRA CFTC MTEN TNRA CFTC GR IbD TENS DT DRHO SSHV HTEN TNRA CFTC MTEN TNRA CFTC GR -999 2500 IbD -999:2500 TENS -999.2500 lIT -999.2500 DRHO '999.2500 34~'211~ ,706 66,5625 -999 -999 -999 -999 2500 2500 -999 -999 -999 4 330 62 250 -999.2500 -999 -999 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 :999 2500 999 2500 3 70!8 389 8056 57 0625 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999,2500 '999,2500 -999,2500 4,3597 330.2026 127,5625 '999,2500 '999,2500 '999.2500 -999.2500 LVP 010,H02 VE ,IFICATION LISTING CALl GR CNTC 1345 -999 25OO PEF TEN S C~',[ : 33 RCFT 3369 ~aTEa -999 -999 4264 259 1.39 -999~2500 2500 250O 25oo 2500 NPHI 2500 RCNT 2500 ~TEM 0000 NPMI 2643 RCNT 750O HTE~ ** FILE TRAIt, ER ** ~ILE NA~}E : EO I ~.~ ,0Oi SER¥ICE NAME . ~AXI~U~ LENGTH : 102,i F i b ~ T Y'PE NEXT FILE ~AN~ : EOF ~999,~500 blTH 9991 500 S:$MV 2500 HTEN 2500 TNRA ~s(,,o C~TC -999 250O GR PAGE 15 999 250 -999 -999 105 0625 ** FILE ~EAt)E~"' '"R ** 1'~ A ~.E :Et)IT ,002 ICE NA~ : VERSI?N ~ D~T~ . PREVIOUS FILE ** CO~ENTS ** ******************************************************************************* ***** THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINT~ ***** ******************************************************************************* ****************************** , * SCH[.~U~BE~G~R LOGS INCb0[)ED WITH THIS FILE (EDIT,002): * * <SEE FILE EDIT,O01 FOR 6" SAMPLED DATA> , * ~ICRO-$PHERICALL¥ FOCUSED LOG (,DLT) * FIRST TO bAST READING: 10625' TO 9904' R ....... PAGE 16 I~VP 010,H02 VE. I~IC~TIOf~ LISTING ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 8 4 73 20 9 4 65 ,lin 16 1 66 0 ! 66 0 ~ATU~ SPECIFICATION BhOCKS I.D ORDER ~ hOG TYPE CLASS MOD NO. CODE ~.>~:~ FT OO 00o O0 0 0 4 ~ 6~ 00000000000000 ~SF;; ~ DLT DH~ O0 270 04 0 0 .4 I fO 00000000000000 DATA ** DEPT 10663,0078 ~SFb 5,8437 DEPT 10600.1738 ~SYL 3,8594 DEPT 10500,1738 ~SFG 15,5938 DEPT 10400,1738 MSFG 25,1562 DEPT 10300,1'138 ~SFL 21,39g4 DEPT 10200.1738 ~SFL 21,5142 DEPT I0100,1.738 ~SEL 23,9375 DEPT 10000,173B ~SFb 8,6392 DEPT 9900,1738 ~SFL 0,4617 DEPT 9875,!738 USFL 0,7192 ** Elbe TRAILER ** FILE NA~!E :EDIT ,002 SERVICE NA~E : VERSIOk ~ : DATE I bVP OiO.H02 V~;RIFICATI.O~N LISTI{.G PAGE 17 ~AXIMU~ LEN~T~, 1024 ~EXT FILE NAME : ** iPE ~RAILE ~ER CE NA~E .E[lr AT ~B/OS/ 4 ORIGIN TAPE NA~E COMMENTS :[,Is TAPE~ $,A,P,C, ~-35, API 50-029-21799 ** REEL TRAIbE~ ** ORIGIN : REEL ~I~ ~,E :72720 ~ONT~N~ATION ~ EXT R~ ~A~E : CO~ENTS :LIS'"IAPE, $.A.P.C, ~-35, AP1 50-029-21799 EOF EOF PRUDHOE BAY I I Run 1' CN/OR Ca.~l Hol~ RECEIVED JUN 1 5 1995 Alaska 011 & Gas Cons. Commission Anchorage ~RN ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 W - 35 500292179900 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 08-JUN-95 6251.02 J. DAHL P. COLLINS 21 liN 12E 1251 1451 90.90 90.90 53.30 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) IST STRING 2ND STRING 9.625 9901.0 3RD STRING 7.000 10620.0 PRODUCTION STRING 4.500 9623.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 13 -APR- 88 SWS BASELINE DEPTH 9850.0 9880.5 9900.0 9901.0 9916.0 9916.5 9917.0 9918.0 9932.5 9933.0 9935.5 9936.0 9954.5 GRCH 9850.0 9881.0 9901.0 9901.5 9916.5 9917.5 9918.0 9918.5 9933.0 9934.0 9936.5 9937.5 9956.0 EQUIVALENT UNSHIFTED DEPTH - 47.00 26.00 12.60 9966.5 9968.0 9971.0 9980.5 9993.5 9994.0 9999.0 10002.0 10018.5 10019.0 10028.5 10029.5 10042.0 10045.0 10074.0 10075.0 10086.5 10091.0 10106.5 10107.5 10118.5 10122.0 10134.0 10134.5 10141.5 10143.0 10145.5 10147.5 10150.0 10151.5 10158.0 10163.5 10166.0 10169.0 10170.0 10185.5 10191.5 10195.0 10195.5 10251.0 10258.5 10281.5 10282.5 10290.5 10291.0 10295.0 10297.0 10311.0 10315.5 10330.0 10343.0 10348.5 10355.0 10358.0 10359.5 10360.0 10365.5 10366.0 10366.5 $ 9968.5 9970.0 9973.0 9982.0 9995.0 9996.0 10001.0 10003.5 10020.0 10021.0 10030.5 10031.0 10043.5 10046.5 10075.5 10076.0 10087.5 10091.5 10107.0 10107.5 10119.0 10122.0 10134.0 10135.0 10142.0 10144.0 10146.0 10147.5 10150.0 10151.5 10158.5 10164.0 10166.0 10169.0 10169.5 10185.0 10190.5 10194.5 10195.5 10251.0 10259.0 10282.0 10282.5 10290.5 10291.5 10295.5 10297.0 10311.0 10315.5 10330.5 10343.0 10349.0 10355.5 10358.0 10359.5 10360.5 10366.0 10367.0 10367.5 REMARKS: CN/GR Cased Hole. TIE IN LOG: BHCS (01-MAY-88/SWS). WELL TEST SUMMARY: TEST DATE ELAPSED TIME GROSS FLUID RATE NET OIL RATE NET WATER RATE FORMATION GAS RATE LIFT GAS RATE CASING PRESSURE TGOR TGLR CHOKE OPENING MANIFOLD PRESSURE MANIFOLD TEMPERATURE WATER CUT (CALC) 24-MAY-95 HOURS 4.0 MBPD 0.25 MBOPD 0.12 MBWPD 0.13 MMSCF/STB 0.71 SCF/STB 5851 MMSCFD 3.04 PSIG 1012 SCF/STB 30967 SCF/STB 14809 136 PSIG 260 DEGF 85 PCNT 52.2 PUMPED 50 BBLS SEAWATER + 2 BBLS METHANOL AFTER PASS ONE. PUMPED 30 BBLS SEAWATER + 2 BBLS METHANOL AFTER PASS TWO. PUMPED 30 BBLS SEAWATER + 2 BBLS METHANOL AFTER PASS THREE. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY o 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ??MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9850.0 10396.0 9850.0 10405.0 BASELINE DEPTH 9880.5 9900.0 9901.0 9907.0 9911.0 9916.0 9918.0 9932.5 9933.0 9935.5 9936.0 9940.0 9954.5 9966.0 9967.5 9969.5 9971.0 9980.5 9991.0 9995..0 9999.0 10002.5 10018.5 10019.0 10024.5 10028.5 10029.5 10047.5 10056.5 10070.5 10074.0 10075.0 10082.0 10086.5 10091.0 10106.5 10107.5 10122.0 10124.5 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH NPHI 9881.0 9901.0 9901.5 9907.0 9910.5 9916.5 9918.5 9933.0 9934.0 9936.5 9937.5 9940.5 9956.0 9967.0 9969.0 9971.5 9973.0 9982.0 9991.0 9996.0 10000.5 10003.0 10020.0 10021.0 10025.5 10030.5 10031.0 10047.5 10058.0 10071.5 10075.5 10076.0' 10082.5 10087.5 10091.5 10107.0 10107.5 10122.0 10125.0 10134.0 10134.5 10141.5 10143.0 10145.5 10147.5 10150.0 10151.5 10158.0 10166.0 10169.0 10170.0 10185.5 10191.5 10195.5 10237.0 10245.5 10251.0 10258.5 10281.5 10282.5 10290.5 10291.0 10295.0 10297.0 10303.5 10308.0 10311.0 10315.5 10330.0 10343.0 10354.0 10357.0 10360.0 10365.5 10396.0 $ REMARKS: 10134.0 10135.0 10142.0 10144.0 10146.0 10147.5 10150.0 10151.5 10158.5 10166.0 10169.0 10169.5 10185.0 10191.5 10195.5 10236.0 10245.0 10251.0 10259.0 10282.0 10282.5 10290.5 10291.5 10295.5 10297.0 10304.0 10308.0 10311.0 10315.5 10331.0 10343.0 10353.0 10357.5 10360.5 10366.0 10396.0 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. /??MATCH1B.OUT $ CN : BP EXPLORATION WN : W - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F (ALASKA) 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 4 4 42 995 99 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 10425.000000 Tape File End Depth = 9835.000000 Tape File Level Spacing = 0.500000 Tape File DePth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5906 datums Tape Subfile: 2 297 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9850.0 2418 9850.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 for each run in separate files. STOP DEPTH 10396.0 10405.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH NPHI 9854.0 9854.0 9900.5 9900.0 9907.5 9907.0 9908.5 9907.5 9913.5 9912.5 9914.0 9913.5 9914.5 9914.5 9917.0 9917.0 9917.5 9919.5 9919.5 9919.5 9920.0 9922.0 9921.0 9922.0 9924.0 9925.0 9928.0 9928.5 9929.0 9929.0 9931.5 9932.5 9931.5 9932.0 9932.5 9934.5 9935.0 9935.5 9935.5 9948.0 9948.0 9949.5 9950.0 9950.0 9951.0 9955.5 9956.5 9957.5 9958.5 9958.5 9959.0 9962.0 9965.5 9966.0 9960.5 9961.5 9962.0 9964.0 9964.5 9965.0 9966.5 9967.0 9977.0 9982.5 9985.5 9988.0 9986.5 9962.0 9963.0 9965.5 9967.5 9968.5 9979.0 9983.5 9988.5 9992.0 9997.5 9998.5 10012.0 10012.5 10018.0 10019.0 10019.5 10022.5 10024.5 10027.0 10033.5 10034.5 10035.5 10039.5 10040.5 10043.0 10045.0 10052.0 10O55.O 10061.5 10062.5 10074.0 10075.0 10077.0 10078.0 10086.0 10092.5 10096.0 10099.5 10105.0 10105.5 10106.0 10113.5 10122.0 10123.0 10127.0 10127.5 10128.0 10128.5 10131.5 10132.0 10133.0 10135.5 10136.0 10138.5 10142.0 10147.0 10148.0 10151.0 10152.0 10156.5 10157.0 10157.5 10164.0 10166.0 10166.5 10167.5 10169.0 10170.0 9993.5 9999.0 9999.5 10020.0 10021.0 10035.0 10035.5 10040.5 10041.0 10043.5 10046.0 10075.0 10075.5 10086.5 10092.5 10122.0 10122.5 10126.5 10127.0 10127.5 10135.5 10138.5 10142.0 10150.5 10151.5 10156.5 10164.0 10165.5 10012.5 10013.5 10019.0 10023.5 10025.5 10028.0 10034.0 10035.5 10052.0 10056.0 10062.5 10063.0 10077.5 10078.0 10096.0 10099.0 10104.5 10105.5 10106.0 10113.0 10127.5 10128.5 10131.5 10132.0 10132.5 10135.0 10138.5 10147.0 10147.5 10156.5 10157.5 10166.5 10167.0 10168.5 10169.0 10175. 10176. 10177. 10178. 10178. 10180. 10181. 10183. 10186. 10187. 10196. 10206. 10212. 10237. 10238. 10238. 10239. 10241. 10249. 10250. 10250. 10252. 10257. 10259. 10260. 10271. 10272. 10279. 10280. 10291. 10292. 10292. 10293. 10297. 10302. 10305. 10308. 10313. 10315. 10320. 10322. 10324. 10325. 10333. 10335. 10335. 10336. 10337. 10338. 10339. 10340. 10340. 10341. 10343. 10346. 10348. 10355. 10356. 10357. 10357. 5 5 0 0 5 0 0 5 5 5 0 5 0 0 0 5 5 0 5 0 5 5 5 5 5 5 5 5 5 5 0 5 5 5 0 0 0 5 5 5 0 5 5 0 0 5 5 0 5 5 0 5 0 0 0 0 0 5 0 5 10176.5 10177.0 10178.0 10179.5 10180.0 10195.0 10239.5 10257.5 10260.0 10280.0 10280.5 10291.5 10292.5 10293.0 10293.5 10305.0 10307.5 10315.0 10323.0 10325.5 10326.0 10333.5 10337.0 10338.5 10339.0 10340.0 10341.0 10342.5 10348.0 10355.0 10358.0 10174.5 10176.0 10179.5 10180.0 10183.0 10186.0 10186.5 10195.0 10206.0 10210.5 10235.5 10236.0 10236.5 10240.0 10248.5 10249.5 10250.0 10252.5 10260.5 10272.0 10273.0 10298.5 10303.0 10312.5 10319.5 10336.0 10336.5 10337.0 10340.5 10345.5 10356.0 10357.0 10361.0 10365.5 10366.0 10370.5 10395.0 10399.0 10399.5 $ REMARKS: 10366.0 10367.0 10361.0 10365.5 10370.5 10395.0 10399.0 10400.0 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH2A. OUT /??MATCH2B. OUT $ : BP EXPLORATION (ALASKA) : W- 35 : 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 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 10425.000000 Tape File End Depth = 9835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5906 datums Tape Subfile: 3 222 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9850.0 10396.0 9850.0 10405.0 BASELINE DEPTH GRCH 9854.0 9854.0 9868.0 9867.5 9899.5 9900.0 9901.0 9901.5 9905.5 9905.5 9909.5 9911.5 9913.5 9914.0 9914.5 9915.5 9916.5 9917.0 9918.5 9918.5 9919.0 9919.5 9920.0 9920.5 9920.5 9921.0 9924.5 9928.0 9930.5 9931.0 9931.5 9933.0 9932.5 9934.0 9933.5 9934.5 9946.0 9947.0 9947.5 9949.0 9949.5 9954.5 9955.5 9958.0 9959.0 9959.5 9960.0 9962.0 9963.5 9965.5 9967.0 files. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9854.0 9900.5 9909.0 9910.5 9912.5, 9913.5 9914.5 9915.5 9916.0 9917.0 9920.5 9921.5 9925.0 9928.0 9930.5 9931.5 9946.5 9947.0 9948.0 9949.5 9950.5 9959.0 9959.5, 9961.0 9967. 9969. 9975. 9977. 9980. 9982. 9983. 9985. 9987. 9991. 9995. 9999. 10001. 10002. 10005. 10005. 10007. 10008. 10009. 10010. 10013. 10013. 10021. 10022. 10024. 10030. 10033. 10034. 10038. 10039. 10041. 10042. 10042. 10043. 10047. 10048. 10049. 10049. 10051. 10052. 10053. 10055. 10064. 10065. 10070. 10077. 10077. 10078. 10078. 10086. 10087. 10088. 10092. 10094. 10095. 10096. 10096. 10102. 10102. 10103. 5 0 5 5 0 0 0 0 5 0 0 0 5 5 0 5 5 5 5 0 0 5 5 0 5 0 5 5 0 0 0 0 5 0 5 5 0 5 5 5 5 0 5 5 0 0 5 0 5 5 5 0 5 5 5 0 5 0 5 0 9983.0 9984.0 9992.5 9996.0 10003.0 10003.5 10014.0 10015.0 10039.5 10040.0 10042.0 10042.5 10043.0 10044.0 10048.5 10050.0 10053.0 10054.5 10078.5 10079.0 10087.0 10092.5 10102.0 10103.0 9969.5 9971.0 9977.5 9979.5 9981.0 9986.0 9988.0 9999.5 10005.5 10006.5 10008.5 10009.0 10010.0 10011.0 10022.5 10023.5 10026.0 10031.0 10034.5 10035.0 10042.5 10043.0 10049.0 10050.0 10053.0 10056.0 10065.5 10066.0 10071.0 10077.5 10078.0 10087.5 10088.5 10095.0 10095.5 10096.0 10097.0 10102.5 10103.0 10103.5 10104.5 10106.5 10107.5 10108.5 10109.0 10111.0 10114.0 10114.5 10117.5 10122.5 10123.0 10126.5 10127.0 10127.5 10128.5 10129.5 10132.0 10133.0 10134.5 10136.0 10137.5 10142.0 10147.0 10147.5 10148.0 10152.0 10156.0 10157.0 10159.0 10159.5 10160.0 10162.0 10163.0 10164.0 10166.0 10169.5 10170.5 10171.0 10175.5 10176.0 10176.5 10177.0 10177.5 10178.5 10179.0 10179.5 10180.5 10181.5 10185.0 10186.0 10187.5 10188.0 10190.0 10191.0 10196.5 10208.0 10210.0 10211.0 10213.0 10104.0 10104.5 10107.5 10108.0 10108.5 10117.5 10128.5 10129.0 10135.5 10142.0 10147.0 10147.5 10148.0 10159.0 10160.0 10164.5 10166.0 10176.0 10176.5 10178.0 10179.0 10179.5 10180.0 10184.5 10185.0 10186.5 10187.5 10196.0 10106.5 10110.5 10113.5 10114.5 10122.5 10123.5 10127.0 10127.5 10128.0 10132.5 10133.0 10134.5 10138.0 10142.5 10147.0 10152.0 10155.0 10155.5 10157.5 10159.5 10160.5 10162.5 10163.0 10169.5 10170.0 10170.5 10175.5 10176.0 10177.0 10178.0 10178.5 10180.5 10181.0 10189.5 10190.0 10207.5 10209.5 10210.0 10212.0 10218 10232 10235 10239 10241 10251 10251 10253 10253 10254 10258 10259 10259 10260 10271 10277 10299 10302 10303 10304 10307 10310 10314 10315 10316 10317 10322 10323 10324 10332 10333 10335 10335 10336 10337 10338 10340 10344 10345 10348 10349 10353 10356 10361 10361 10365 10366 10367 10372 10373 10379 10380 10383 10384 10385 10386 10390 10399 $ .5 .5 .5 .5 .0 .0 .5 .0 .5 .0 .0 .0 .5 .0 .5 .5 .0 .0 .0 .5 .5 .0 .0 .5 .5 .0 .0 .0 .0 .5 .0 .0 .5 .0 .0 .0 .0 .5 .0 .5 .0 .0 .0 .0 .5 .5 .5 .5 .5 .5 .0 .0 .5 .5 .5 .0 .0 .5 10239.5 10251.5 10260.5 10302.5 10303.0 10315.5 10317.0 10323.5 10324.0 10336.0 10337.5 10338.0 10344.5 10345.5 10361.5 10362.5 10366.5 10367.0 10368.0 10387.0 10387.5 10391.0 10218.0 10231.0 10234.0 10240.5 10250.5 10253.0 10253.5 10254.5 10258.5 10259.0 10259.5 10273.0 10279.0 10299.5 10305.0 10308.0 10310.0 10313.5 10316.0 10317.0 10322.0 10334.5 10335.0 10335.5 10336.0 10340.0 10347,5 10348.5 10352.5 10356.0 10361.0 10362.0 10373.0 10374.5 10380.0 10380.5 10384.0 10384.5 10400.0 REMARKS: PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH3A. OUT / ? ?MATCH3 B. OUT $ : BP EXPLORATION (ALASKA) : W- 35 : 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 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 10425.000000 Tape File End Depth = 9835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11812 datums Tape Subfile: 4 273 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted'and clipped curves for each run in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9850.0 10396.0 9850.0 10405.0 BASELINE DEPTH GRCH 9854.0 9854.0 9880.0 9880.0 9895.0 9896.0 9897.0 9898.0 9899.5 9900.0 9900.0 9900.5 9901.0 9901.0 9907.0 9907.5 9908.0 9909.0 9914.0 9914.5 9917.5 9917.5 9918.5 9918.0 9919.0 9918.5 9921.0 9921.5 9922.5 9923.5 9924.0 9924.5 9931.5 9933.0 9933.5 9934.5 9938.0 9939.0 9944.5 9945.0 9946.5 9948.0 9947.0 9947.5 9948.5 9949.5 9950.5 9961.0 9963.0 9964.5 9965.0 9966.0 9968.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9854.0 9900.5 9906.5 9907.5 9908.0 9908.5 9913.5 9914.5 9917.5 9921.5 9922.0 9922.5 9923.5 9924.5 9925.5 9934.5 9935.0 9938.5 9939.0 9944.5 9945.5 9947.5 9948.5 9965.5 9966.5 9979.0 9980.0 9981.5 9983.0 9985.5 9988.0 9991.0 9991.5 9997.0 9998.0 9999.0 10002.0 10007.0 10012.0 10012.5 10027.0 10027.5 10029.0 10030.5 10032.5 10033.5 10037.0 10038.0 10046.0 10047.5 10052.0 10054.5 10057.5 10058.5 10059.0 10061.5 10062.5 10063.5 10076.0 10077.0 10086.5 10092.5 10095.5 10100.5 10101.5 10102.5 10107.0 10111.5 10119.5 10120.0 10128.0 10128.5 10129.0 10130.0 10132.0 10132.5 10133.0 10133.5 10135.0 10143.5 10148.0 10151.5 10152.0 10155.0 10155.5 9982.5 9984.0 9993.5 9999.0 9999.5 10028.5 10029.5 10031.0 10032.0 10038.5 10047.5 10049.0 10063.0 10064.5 10087.5 10093.0 10133.0 10133.5 10135.0 10144.5 10148.5 10152.0 10152.5 10156.0 9980.5 9981.0 9986.5 9988.5 9991.5 9992.5 10000.5 10003.0 10007.5 10013.0 10014.0 10034.0 10034.5 10038.0 10038.5 10052.5 10056.0 10059.0 10059.5 10060.5 10063.0 10063.5 10077.0 10077.5 10096.0 10101.5 10102.5 10103.0 10107.5 10111.5 10119.5 10120.5 10128.5 10129.5 10130.0 10130.5 10132.5 10133.0 10133.5 10155.5 10156.0 10157.0 10157.5 10158.0 10161.0 10161.5 10162.5 10163.5 10168.5 10169.0 10170.0 10171.0 10171.5 10176.0 10176.5 10177.0 10178.0 10179.0 10179.5 10183.5 10184.0 10185.0 10186.0 10192.5 10193.0 10193.5 10195.0 10196.0 10209.0 10211.5 10212.5 10213.0 10231.5 10237.5 10239.5 10241.0 10250.5 10251.5 10253.5 10260.5 10263.5 10281.5 10282.5 10285.0 10285.5 10287.5 10291.0 10295.0 10297.0 10297.5 10298.5 10301.5 10308.0 10309.0 10314.5 10315.5 10322.5 10325.0 10326.0 10329.0 10158.0 10159.0 10164.5 10169.0 10184.0 10192.5 10193.0 10194.0 10195.5 10196.0 10240.0 10252.0 10264.5 10282.5 10283.0 10285.5 10286.5 10296.0 10297.5 10308.5 10309.0 10314.5 10323.5 10326.0 10326.5 10329.5 10156.0 10157.0 10158.0 10161.5 10162.5 10163.5 10164.0 10169.0 10170.0 10170.5 10171.5 10176.0 10177.0 10177.5 10178.0 10179.0 10180.0 10184.0 10185.0 10186.0 10186.5 10209.5 10211.5 10212.0 10212.5 10230.5 10236.5 10241.0 10250.5 10254.0 10261.0 10288.5 10292.0 10298.5 10299.0 10299.5 10302.5 10316.0 10323.0 10329.5 10331.0 10332.0 10337.0 10345.0 10346.5 10350.0 10350.5 10353.0 10353.5 10354.0 10355.0 10356.0 10357.5 10358.5 10359.0 10360.0 10361.0 10363.0 10366.0 10367.0 10368.0 10371.5 10390.0 10392.5 10393.0 10394.0 $ REMARKS: 10330.5 10332.5 10350.5 10351.5 10354.0 10354.5 10355.5 10359.0 10360.5 10361.0 10367.0 10367.5 10368.5 10391.0 10317.0 10333.5 10338.0 10344.5 10346.0 10354.5 10356.5 10359.0 10361.5 10363.5 10372.0 10393.5 10394.0 10394.5 PASS 4. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH4A . OUT / ??MATCH4B. OUT $ CN : BP EXPLORATION WN : W - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 cUrves: Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 1 CPS (ALASKA) Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 24 1006 BYTES * Tape File Start Depth = 10425.000000 Tape File End Depth = 9835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11812 datums Tape Subfile: 5 242 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes 16 Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3, 4 1, 2, 3, 4 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 4 PASSES. $ : BP EXPLORATION (ALASKA) : W- 35 : 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 CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 10425.000000 Tape File End Depth = 9835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17718 datums Tape Subfile: 6 47 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPT~{ INCREMENT: 0.2500 FILE S~Y VENDOR TOOL CODE START DEPTH GR 9846.0 2418 9846.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10409.5 10419.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAY-95 FSYS REV. J001 VER. 1.1 1107 28-MAY-95 10410.0 10407.0 9850.0 10405.0 900.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 10620.0 0.0 PRODUCED FLUID/WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 4 FAR COUNT RATE HIGH SCALE (CPS): 404 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : W- 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) Total Data Records: 83 1014 BYTES * Tape File Start Depth = 10422.000000 Tape File End Depth = 9846.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32558 datums Tape Subfile: 7 158 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log heade~ data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9844.0 2418 9844.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10409.5 10419.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAY-95 FSYS REV. J001 VER. 1.1 1224 28-MAY-95 10410.0 10407.0 9850.0 10405.0 900.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 10620.0 0.0 PRODUCED FLUID/WATER 0.0O 0.0 0.0 0 0.0 0.000 O.O00 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 4 FAR COUNT RATE HIGH SCALE (CPS'): 404 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS) : 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : W- 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 10422.000000 Tape File End Depth = 9838.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38752 datums Tape Subfile: 8 159 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9845.0 2418 9845.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10409.5 10419.0 28-MAY-95 FSYS REV. J001 VER. 1.1 1332 28-MAY-95 10410.0 10407.0 9850.0 10405.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10620.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUID/WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 4 FAR COUNT RATE HIGH SCALE (CPS): 404 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TooL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : W- 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 10422.000000 Tape File End Depth = 9838.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53592 datums Tape Subfile: 9 159 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9845.0 2418 9845.0 $ LOG HEADER DATA STOP DEPTH 10409.5 10419.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAY-95 FSYS REV. J001 VER. 1.1 1436 28-MAY-95 10410.0 10407.0 9850.0 10405.0 900.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323XA 0.000 10620.0 0.0 PRODUCED FLUID/WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 4 FAR COUNT RATE HIGH SCALE (CPS) : 404 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) :W-35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 10422.000000 Tape File End Depth = 9838.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59786 datums Tape Subfile: 10 159 records... Minimum record length: Maximum record length: 62' bytes 1014 bytes Tape Subfile 11 is type: LIS 95/ 6/ 8 01 **** REEL TRAILER **** 95/ 6/ 9 01 Tape Subfile: 11 Minimum record length: Maximum record length: End of execution: Fri 2 records... 132 bytes 132 bytes 9 JUN 95 8:15a Elapsed execution time = 12.53 seconds. SYSTEM RETURN CODE = 0
