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195-150
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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: END 1-03 (PTD# 195-150) IA Pressure Exceed MOASP Date:Tuesday, September 20, 2022 9:39:19 AM Attachments:image001.png image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, September 16, 2022 1:34 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: END 1-03 (PTD# 195-150) IA Pressure Exceed MOASP Mr. Regg, Producer END 1-03 (PTD# 195-150) IA exceeded MOASP after being shut in due to a facility shutdown. Passing packoff tests were conducted followed by a gas lift valve change out. The well was POP’d and a passing warm TIFL was conducted. The passing TIFL demonstrates the competency of the primary barrier to formation. The well is now classified as OPERABLE. Please respond if you have any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Friday, September 9, 2022 11:53 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: END 1-03 (PTD# 195-150) IA Pressure Exceed MOASP Mr. Regg, Producer END 1-03 (PTD# 195-150) was recently shut in as a result of a facility shutdown. After being shut in, the inner annulus pressure climbed and exceeded MOASP to 2800 psi. Currently the well is shut in and will remain shut in until the facility is online. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. PPPOT-T/IC 2. Change out gas lift valves 3. POP Well 4. Warm TIFL 5. Engineer to evaluate additional diagnostics as required Please respond if there any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 anydissemination, 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 acceptedby 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: END 1-03 (PTD# 195-150) IA Pressure Exceed MOASP Date:Friday, September 9, 2022 12:06:35 PM Attachments:image001.png image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, September 9, 2022 11:53 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: END 1-03 (PTD# 195-150) IA Pressure Exceed MOASP Mr. Regg, Producer END 1-03 (PTD# 195-150) was recently shut in as a result of a facility shutdown. After being shut in, the inner annulus pressure climbed and exceeded MOASP to 2800 psi. Currently the well is shut in and will remain shut in until the facility is online. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. PPPOT-T/IC 2. Change out gas lift valves 3. POP Well 4. Warm TIFL 5. Engineer to evaluate additional diagnostics as required Please respond if there any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 anydissemination, 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 acceptedby 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: Wednesday, May 20, 2020 p� IP.I. Supervisor —7� qty 2�� SUBJECT: Mechanical Integrity Tests 11 Hilcorp Alaska, LLC 1-03 FROM: Bob Noble DUCK IS UNIT MPI I-03 Petroleum Inspector See: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-03 Insp Num: mitRCN200518163558 Rel Insp Num: API Well Number 50-029-22601-00-00 Inspector Name: Bob Noble Permit Number: 195-150-0 Inspection Date: 5/17/2020 — Pretest Initial 15 Min 30 Min d5 Min 60 Min o O�o o � o n o 0 800 1100 11- 1024 1007 Wednesday, May 20, 2020 Page I of I Packer Depth Well 1 03 Type Inj 1 N 'TVD F 9950 Tubing PTD 1911500 Type Test sPTTest psi 1000 IA BBL Pumped: 01 ' !BBL Returned: 03 OA Interval OTHER IP/F 1' Notes: Casing repair pressure test to 1000 psi as per sundry H 320-185. ✓ Pretest Initial 15 Min 30 Min d5 Min 60 Min o O�o o � o n o 0 800 1100 11- 1024 1007 Wednesday, May 20, 2020 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission S I Za��iw TO: Jim Regg 1,�,Q� DATE: 5/09/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Casing Repair Petroleum Inspector Duck Island Unit MPI 1-03 Hilcorp Alaska LLC PTD 1951500; Sundry 320-185 5/09/2020: 1 arrived on location and met with Cory Norris (Hilcorp Alaska LLC). We spoke about the well and what had been done up to this point. The casing had been exposed and cleaned up to locate the leak. The pup -joint on the casing hanger had obvious corrosion on the upper half of the pipe. Mr. Norris pointed out to me the leak. I photo documented the hanger's corrosion and the general location. I instructed Mr. Norris to notify 24 hours before they would like us to witness the repair and we would come out to inspect and witness both the repair and the required MITOA. The needed supplies are scheduled to be on location this Monday the 11'h and the operation will continue forward. Attachments: Photos (5) 2020-0509_Surface_Csg_Repair_DIU_MPI_ 1-03_gc. docx Page I of 4 � 4) ��•< � - it �. _ { ), 2 )h VON a max. L`r •, �1 1 ILI, . �r .R s 1 { l I tI �� V ^� O h O O N O N 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Surface Casing Repair Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,450 feet 10,472 feet true vertical 10,123 feet N/A feet Effective Depth measured 10,472 feet 10,187 feet true vertical 10,082 feet 9,950 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / NSCT / 13Cr-80 10,187' 9,950' Packers and SSSV (type, measured and true vertical depth)4-1/2" HES HXO SSSV See Above 1,5114MD/ 1,503TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 24,844 Water-Bbl MD 88' 4,456' 10,608' TVD 88' 7-5/8" x 4-1/2" TIW SS Horiz. Oil-Bbl measured true vertical Packer 4-1/2" 10,538' 11,450' 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 175 Representative Daily Average Production or Injection Data 50511,304 8,583 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-150 50-029-22601-00-00 Plugs ADL0034633 5. Permit to Drill Number: Endicott / Endicott Oil 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-185 592 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 777-8333 2,050 Duck Island Unit MPI 1-03 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 251 Gas-Mcf 1,550 Casing Pressure Tubing Pressure 9,041 Junk Liner Slotted Liner Casing Conductor Size Surface Intermediate N/A measured 377' 912' measured 4,400' 10,101' 10,094' 7,830psi Length 88' 4,414' 10,568' N/A 5,210psi 9,690psi 8,430psi 7,500psi 30" 10-3/4" 7-5/8" 4-1/2" 8,430psi 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,470psi 10,123' 7,500psi Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations For C. Helgeson By Samantha Carlisle at 4:42 pm, Jun 05, 2020 Digitally signed by David Haakinson DN: cn=David Haakinson, ou=Users Date: 2020.06.05 12:22:14 -08'00' David Haakinson Surface Casing Repair SFD 6/10/2020gls 6/9/20 RBDMS HEW 6/10/2020 Oil DSR-6/9/2020 END1-03CasingRepair 4/26/2020 Identified surface CSG failure. 5/1/2020 Slickline set a plug in the X-nipple at 10,118’ MD. 5/3/2020 Set BPV in TBG hanger, ND Tree, RU the WSS 5/4/2020 – 5/6/2020 Removed the Cellar, Install Shoring Sleeve, hydrovac the sleeve down 8’, cut and removed the Conductor. RU the WSS well support crane. 5/8/2020 – 5/9/2020 Clean and inspect the 10-3/4” CSG corrosion. AOGCC representative witnessed the CSG corrosion prior to the external patch install. 5/10/2020 - 5/11/2020 Wait on CSG patch Material 5/12/2020 – 5/15/2020 Weld on the external CSG patch. 5/17/2020 – 5/21/2020 Pressure tested the OA to 1000 psi (passed). AOGCC representative witnessed the OA pressure test and final CSG patch. Remove the WSS, install the tree, weld back the 30” conductor, Slickline pulled the downhole plug. Returned the well to production. Weld on the external CSG patch. Well Name Rig API Number Well Permit Number Start Date End Date END 1-03 Support Structure 50-029-22601-00-00 195-150 5/4/2020 5/21/2020 Welded on lower CSG patch band, start the 24 hr cooling period. AOGCC inspector inspected the 10-3/4" CSG damage. 5/9/2020 - Saturday No work, waiting on CSG patch material. 5/12/2020 - Tuesday 5/10/2020 - Sunday No work, waiting on CSG patch material. 5/11/2020 - Monday 5/8/2020 - Friday Cleaned off the CSG, Completed the Creaform inspection and UT inspections. 5/6/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Fully Removed the Conductor. 5/7/2020 - Thursday Inspected the 10-3/4" CSG, identified the hole in the CSG below the fluted mandrel. Well Name Rig API Number Well Permit Number Start Date End Date END 1-03 Support Structure 50-029-22601-00-00 195-150 5/4/2020 5/21/2020 5/15/2020 - Friday Complete welding the CSG patch. 5/13/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary 24 hr cool down on welded band. 5/14/2020 - Thursday Welded on CSG patch. Fit/Weld back in 30" Conductor. 24 hr patch cool down, complete weld inspections. 5/16/2020 - Saturday Wellhead - Removed WSW change out S-seals on hanger neck and SBMS seal for new, Nipple up adapter and tree. Tested adapter to 500 / 5000 psi for 10 mins all tests good. Pull 4" H BPV with dry rod and close master valve. RDMO. 5/19/2020 - Tuesday 5/17/2020 - Sunday Pressure test the CSG to 1,000 psi witnessed. Passed. 5/18/2020 - Monday Pressure test the CSG to 1,000 psi witnessed. Passed. Well Name Rig API Number Well Permit Number Start Date End Date END 1-03 Support Structure 50-029-22601-00-00 195-150 5/4/2020 5/21/2020 No operations to report. No operations to report. 5/23/2020 - Saturday No operations to report. 5/26/2020 - Tuesday 5/24/2020 - Sunday No operations to report. 5/25/2020 - Monday 5/22/2020 - Friday No operations to report. 5/20/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, NOTIFY PAD-OP, FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 300L/3100H. JUMPER GAS FROM END1-05 TO PRESSURE UP TBG ABOVE PLUG TO 3,100psi. RUN 3.80" CENT, 4-1/2" GS CORE, 4-1/2" EQ PRONG TO DRIFT TBG & S/D ON XX-PLUG @10,095' SLM, EQUALIZE PLUG. 5/21/2020 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 300L/3,100H. PULL 4-1/2" XX- PLUG FROM X-NIPPLE @ 10,088' SLM / 10,118' MD, HAVE TO WORK THROUGH SVLN, RECOVER ALL PKG & NUBBINS. RUN INTO TIGHT SPOT @ -6' SLM WHILE TRYING TO RUN SSSV, PUMP METH AND PUT HEATER ON TREE. RUN 3.84" CENT, 4-1/2" BLB, 3.80" GAUGE RING AND WORK THROUGH TREE TILL RUNS FREELY TO 25' SLM SET 4-1/2" BBE SSSV (SER #: HNBB-53, STEEL SEC LOCK DOWN, OAL=60") IN HXO SSSV NIPPLE @ 1,481' SLM / 1,514' MD. PAD OP PERFORM CLOSURE TEST, INITIAL T/IA/OA = 2,600/0/0, BLEED TBG DOWN TO 2,200psi, WATCH FOR 15min, OPEN SSSV GOOD TEST. JOB COMPLETE, PAD-OP NOTIFIED LEAVE WELL S/I ON UPON DEPARTURE. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Surface Casing Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 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 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,450'N/A Casing Collapse Conductor N/A Surface 2,470psi Intermediate 7,830psi Liner 7,500psi Slotted Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date:4/29/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 195-150 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22601-00-00 Hilcorp Alaska LLC Length Size 10,123' 10,472' 10,082' 3,991 10,472' 88' 88' 12.6 / NSCT / 13Cr-80 TVD Burst 10,187' 8,430psi MD N/A 8,430psi 5,210psi 9,690psi 4,400' 10,101' 10,094' 4,456' 10,608' 88' 30" 10-3/4" 7-5/8" 4,414' 4-1/2"377' 10,568' 10,123' Authorized Signature: 5/4/2020 4-1/2" Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" Perforation Depth TVD (ft): Tubing Size: Duck Island Unit MPI 1-03 C.O. 462.007 Endicott / Endicott Oil 7-5/8" x 4-1/2" TIW SS Horizontal and 4-1/2" HES HXO SSSV 10,187 MD / 9,950 TVD and 1,514 MD / 1,503 TVD Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 11,450' 10,538' 912' No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.04.30 12:43:36 -05'00' By Samantha Carlisle at 10:03 am, Apr 30, 2020 320-185 DSR--4/30/2020 10-404 Surface Casing Repair Well Support Structure (WSS) required for repair.+ + Photo document repair + AOGCC to witness surface casing damage and welded patch. gls 4/30/20 DLB 04/30/2020 X Comm 5/1/2020 dts 5/1/2020 JLC 5/1/2020 Surface Casing Leak Repair Well: END 1-03 PTD: 195150 API: 50-029-22601-00-00 Well Name:END 1-03 API Number: 50-029-22601-00-00 Current Status:SI Producer Rig:NA Estimated Start Date:May 4, 2020 Estimated Duration:10 Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:195150 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Wyatt Rivard (907) 777-8847 (O) (509) 670-8001 (M) AFE Number: Well EZ Inputs Required:Yes Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent SI Surface Pressure: 3,991 psi @ 10,000’ TVD 3,991 psi @ 10,000’ TVD 2,991 psi 1,800 psi (Based on END 2-14 SBHPS on 3/31/19) (Based on END 2-14 SBHPS on 3/31/19) (Max BHP-(0.1 psi/ft x 10,000 TVD) (Taken on 10/18/18) Brief Well Summary: END 1-03 is a natural flow Endicott producer. The well was SI on 4/26/20 following a confirmed leak from the conductor with WHPs of T/I/O = 500/1550/0. The OA maintained a steady 150 psi until identified the pressure had dropped to 0 on 4/26/2020. Fluids were observed in the bottom of the cellar. Attempted to pressure up the OA to test for a leak. The OA would not pressure up and communication was observed out of the conductor. Objective: Remove conductor and weld a casing patch to restore OA integrity. Notes On Wellbore Condition: x The well had a passing MIT-IA to 1,200 psi on 4/10/2013 and has had no indications of TxIA or IAxOA communication since. x Surface casing leak is estimated ~55” below the OA valve. Well Cellar floor is ~58” below OA valve. x Surface casing was hung with a fluted mandrel hanger that sits above the landing ring. x Estimate Load on the WH ~150 Klbs Procedure: Pre-Sundry Work Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 3,100 psi high. 3. RIH and pull 4.5” BBE from 1,514’ MD 4. MU plug toolstring and set a 4-1/2” (3.813”) XN plug @ 10,244’ md.(Contingency: If unable to set a plug in the XN Nipple, set a plug in the SSSV profile at 1,514’ MD.) a. Bleed down the tubing pressure to confirm set. 5. RDMO Prep Work 6. Disconnect flowline and instrumentation. 7. Close downhole valve and verify tubing, IA and OA pressures have been bled to 0psi. 8. Sniff cellar and adjacent area with multi-gas meter for LEL, CO, H 2S and 02. Ensure confined space, egress and ventilation is adequate for operations Contact AOGCC if bottom plug does not hold pressure. (verify fluid level in IA ) Surface casing leak is estimated ~55” below the OA valve. Surface Casing Leak Repair Well: END 1-03 PTD: 195150 API: 50-029-22601-00-00 9. Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons. Cut cellar floor and vac out additional 3-4’ of fill to provide more space for conductor removal. 10. Install fire blankets around the conductor landing ring to protect surface casing holes from hot machining debris. Sundry Work (Approval required to proceed) Surface Casing Repair 11. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 12. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H 2S and 02. Ensure confined space, egress and ventilation is adequate for operations 13. Install BPV and nipple down tree at the tubing head adapter to makeup Wellhead Support Structure adapter flange. 14. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual. 15. Pull 50,000 lbs gradually building up load in 1000 lb increments. (Theoretical WH load – 150 klbs, neutral weight) a. Monitor the wellhead for any signs of movement and discontinue increasing tension if movement observed. 16. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H 2S and 02. Ensure confined space, egress and ventilation is adequate for operations 17. Drill holes (cold cutting drill bit) in the conductor roughly 2 ft and 5 ft below the landing ring. 18. Flush conductor with water from the conductor starting head valve and bull plug while taking fluid returns from the cement return line bull plug. Flush until clean returns are observed. 19. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined on site, prior to proceeding, with accurate gas readings and fluid returns observed. b. Prior to cutting conductor, install continuous gas monitoring for LEL’s from the conductor. 20. Cut and remove conductor from above the 5 ft inspection holes. a. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. b. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. Alternately, if there is not sufficient room to drop the landing ring below the patch area, the vertical cut may be carried all the way up and through the landing ring. 21. Remove cement as needed to confirm weldable, uncorroded surface casing at hole depth. Chip away excess cement from the surface casing. Buff and prepare surface casing for inspection and welding. 22. Inspection department to use the Creaform tool to inspect the Surface CSG then UT the surface casing where we plan to weld. b. Inspect for any additional holes below landing ring. c. Areas to patch to be identified marked and inspected on a grid to ensure competency for welds 23. Evaluate surface CSG inspection results with Operations Engineer. Based on the inspection results/CSG condition the decision on CSG patch will be made. a.Option 1 – Confirm final Well Support Structure load with OE prior to welding the patch. Cut out corroded section of 10-3/4” 45.5# surface CSG. i. Monitor load on the Well Support Structure in addition to wellhead vertical displacement during cutting/heating operations. WSS Photo damage replace casing option 1 cutout & Option 1 – C Notify inspector to witness Surface Casing Leak Repair Well: END 1-03 PTD: 195150 API: 50-029-22601-00-00 ii. Cut out a window in the 10-3/4” surface CSG to check location of 7-5/8” Production CSG. Cut rest of 10-3/4” surface CSG out carefully ensuring to not cut the 7-5/8” CSG. iii. install new section of 10-3/4” 45.5# L-80 CSG. Circumferentially weld to the surface casing for the upper and lower patch areas. b.Option 2 – Confirm final Well Support Structure load with OE prior to welding patch. Weld External Clam Shell around the corroded section of surface CSG. i. Note that there is a pup joint with collared connection below the starting head that may need to be straddled to weld to good metal above and below leak. ii. Circumferentially weld band/spacer rings to the surface casing for the upper and lower patch areas iii. Band material: A516-70, ID=10.75” thickness=.75”. iv. Once neutrally loaded, begin preheating as per welding procedure for clamshell patch v. Monitor load on Well Support Structure in addition to wellhead vertical displacement during heating operations. vi. Maintain constant vertical displacement in the event that surface casing integrity impacted during heating. vii. Install clamshell patch and weld circumferentially to the machined flutes/ring and vertically to the other patch half. viii. Patch material: A516-70, ID=12.25” thickness=1/2”. 24. Inspect the welds to ensure competency. 25. Conduct an MIT-OA to 1000psi to confirm SC integrity. 26. Gradually release wellhead load from Well Support Structure back onto patched surface casing. 27. Unbolt and remove the adapter flange 28. Reinstall 5K production tree. 29. Remove BPV and install TWC. Pressure test tree to 5000psi. 30. Re-install flowline and instrumentation Slickline 31. MIRU SL unit. 32. Pressure test to 300psi low and at least 3,100psi high. 33. RIH and pull 4-1/2” (3.813”) XN plug from 10,244’ md. 34. RIH and set 4.5” BBE at 1,514’ MD 35. RDMO 36. Turn well back over to production Post Repair Work 37. Weld cut conductor halves back onto conductor. 38. Reinstall well house and backfill gravel over cellar liner. 39. Cement SC by Conductor Annulus back to within 1ft of conductor top. 40. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Attachments: -Wellbore Schematic Clam shell option Option 2 – 2 Notify inspector to witness. Set plug in XN • . 14 Post Office Box 244027 JULry (nl' f1 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U3 ry1 201`� 3800 Centerpoint Drive Suite 100 A®GCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster 3 Alaska Oil & Gas Conservation Commission 0 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNEQ AuG 2 9 2016 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WellNo PermitNumber WeilName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 1-01 5CO29226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/020 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/122 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 itt r.. L H.. - wL May 22, 2012 ` I Mr. Jim Regg i — Alaska Oil and Gas Conservation Commission e■°1-) ©� 333 West 7 "Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, r / - Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement , pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 ��END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /I-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 / 1-18 1950930 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 , 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 /1-24 1982550 50029225770200 1.5 0.3 0.5 . 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 _ NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / Q-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / Q -20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 , 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / Q-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1-65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1-67 / T-20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 , 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 .. ~ e~ r~~ STATE OF ALASKA ~'' ALA OIL AND GAS CONSERVATION COM~10N `~~ REPORT OF SUNDRY WELL OPERATION f%~~S 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0 , Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ . Exploratory r 195-1500 - 3. Address: P.O. Box 196612 Stratigraphic r Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22601-00-00 . 7. KB Elevation (ft): 9. Well Name and Number: 56 KB ~ 1-03/P-16 ' 8. Property Designation: 10. Field/Pool(s): , ADLO-312828 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 11450 i feet Plugs (measured) 10500' true vertical 10122.57. feet Junk (measured) None Effective Depth measured 10472 feet true vertical 10026 feet Casing Length Size MD TVD Burst Collapse Conductor 88' 30" Surface - 130' Surface - 130' Surface 4414' 10-3/4" 45.5# NT-80 Surface - 4456' Surface - 4344' 5210 2480 Intermediate 10668' 7-5/8" 29.7# NT-95-HSSurface - 10608' Surface - 10045' 8180 5120 Blank Liner 377' 4-1/2" BLANK LINER 10296' - 10538' 9876' - 10038' Slotted Liner 912' 4-1/2" SL 12.6# L-80 10538' - 11450' 10038' - 10067' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _, True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 10187' 0 0 - Packers and SSSV (type and measured depth) 7-5/8" TIW SS HORIZ PKR 10187' 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: 197 11120 8451 1497 Subsequent to operation: 623 1445 11023 689 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development r- Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil r~ Gas r WAG r GINJ ~ WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature .J Phone 564-4944 Date 11/17/2008 Form 10-404 Revise604/2006 ti° ~ ~"~, ~ ~"~) ~ ~ ~~~~~~~ ~ ~ . .~~u~ ~~~ ~~~ Submit Original Only /y~z' 1-03/P-16 195-150 DFRF ATTA~_I-IMFAIT CJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 1-03/P-16 1/1/95 SL 10,257. 10,263. 9,992.83 9,996.24 1-03/P-16 1/1/95 SL 10,538. 11,427. 10,093.81 10,123.01 1-03/P-16 3/19/02 BPS 10,500. 11,450. 10,088.06 10,122.57 1-03/P-16 3/20/02 SQZ 10,257. 10,500. 9,992.83 10,088.06 1-03/P-16 3/24/02 PER 10,320. 10,330. 10,026.34 10,031.11 1-03/P-16 3/24/02 PER 10,454. 10,464. 10,077.41 10,080.08 1-03/P-16 11/4/08 APF 10,415. 10,440. 10,065.41 10,073.39 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 ~ r 1-03/P-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY LOG TIED INTO SLB CARBON OXYGEN LOG DATED 27-FEB-2002. WELL SHUT IN ON DEPARTURE, SSV CLOSED, VALVES OPEN TO GAUGES, DSO NOTIFIED, FINAL T/I/O = 2300/1450/90 PSI. "*JOB COMPLETE "~' 11/7/2008 "'WELL FLOWING ON ARRIVAL*'* (post pert) BRUSHED SVN WITH 3.80" GAUGE RING & 4 1/2" BRUSH SET 4.5" BBE (SER# BB-440) @ 1480'SLM . CLOSURE TEST GOOD `*`TURN WELL OVER TO DSO""" FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1936' FNL, 2032' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 387' FNL, 1554' FEL, Sec. 36, T12N, R16E, UM At effective depth 301' FNL, 1670' FEL, Sec. 36, T12N, R16E, UM At total depth 4981' FNL, 2440' FEL, Sec. 25, T12N, R16E, UM 12. Present well condition summary Total depth: Operation shutdown_ Pull tubing _ Stimulate _ Plugging _ Perforate _X Alter casing _ Repair well _ Other _ 5. Type of Well: 6. Datum elevation (DF or KB feet) Development __X RKB 56 feet Exploratory__ 7. Unit or Property name Stratigraphic__ Service__ (asp's 259175, 59824 74) (asp's 259702, 5984007) (asp's 259588, 5984097) (asp's 258839, 5984 721) measured 11450 feet Plugs (measured) true vertical 10123 feet Duck Island Unit/Endicott 8. Well number 1-03/P- 16 9. Permit number / approval number 195-150 10. APl number 50-029-22601-00 11. Field / Pool Endicott Oil Pool TD TAG @ 10472' (03/22/2002) CIBP SET @ 10500' (03/19/2002) Effective depth: measured 10472 feet Junk (measured) true vertical 10026 feet Casing Length Size Cemented Measured Depth Conductor 88' 30" Driven 130' Surface 4414' 10-3/4" 784 sx PF 'E', 461 sx 'G', 4456' 150 sx PF 'E' Intermediate 10668' 7-5/8" 536 sx Class 'G' 10608' Blank Liner 377' 4-1/2" Uncemented 10161' - 10538' Slotted Liner 912' 4-1/2" Uncemented 10538' - 11450' True VerticalDepth 130' 4344' 10045' 9876'-10038' 10038'-10067' Perforation depth: measured Open Perfs 10320' - 10330', 10454' - 10464'. Slotted Liner 10538' - 11427' Ported Liner Jt @ 10257' - 10263'. true vertical Open Perfs 10026'- 10031', 10077'- 10080'. Slotted Liner 10094'- 10123' Ported Liner Jt @ 9937' - 9940' 4-1/2", 12.6#, 13CR80 TBG @ 10187' MD. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" TIW SS HORPZONTAL Packer @ 10187'. 4-1/2" HES 'HXO' SSSV Landing Nipple @ 1514' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl 197 1225 RECEIVED Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 139 11148 Prior to well operation 03/14/2002 Subsequent to operation 03/29/2002 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations__ Oil _X Gas_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Casing Pressure Tubing Pressure 595 5106 8342 367 16. Status of well classification as: Suspended _ Service Date May 16, 2002 Pre Fl. Schnorr 564-5174 ~~~i~E~~ j.~ ~ ~,~~ IN DUPLICATE 1-03/P-16 Description of Work Completed NRWO OPERATIONS 03/24/2002 PERFORATING' PERFORATING 04/15/2002 CEMENT SQUEEZE' SSSV C/O OR STROKE SUMMARY 03/24/02 SHOT 20' WITH 2-7/8" ADD-PERFS IN TWO GUN RUNS. TIE-IN LOGS SWS WAS C/O-GR DATED 02/27/2002. GUN RUN #1 SHOT 10' 2-7/8" HSD P J, HMX, 6 SPF FROM 10454'- 10464'. GUN RUN #2 SHOT 10' 2-7/8" HSD P J, HMX, 2 SPF FROM 10320' - 10330'. 04/15/02 SET 4.5" BBE SSSV .ff' NBB-54 AT 1480' AMS-SLM. <<<WELL RELEASED FOR PRODUCTION>>> Fluids Pumped BBLS. Description 0 DIESEL FOR SURFACE EQUIP PRESSURE TEST TO 3000 PSI (0 TEST) 0 TOTAL , ADD PERFS 03/24/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" PJ HMX, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 10320' - 10330' 10454' - 10464' Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging CIBP & CMT SQZ Pull tubing_ Alter casing_ Repair well _X Other 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1936' FNL, 2032' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 387' FNL, 1554' FEL, Sec. 36, T12N, R16E, UM At effective depth 301' FNL, 1670' FEL, Sec. 36, T12N, R16E, UM At total depth 4981' FNL, 2440' FEL, Sec. 25, T12N, R16E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ (asp's 259175, 5982474) (asp's 259702, 5984007) (asp's 259588, 5984097) (asp's 258839, 5984721) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Duck Island Unit / Endicott 8. Well number 1-03/P- 16 9. Permit number / approval number 195-150 10. APl number 50-029-22601-00 11. Field / Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 11450 feet Plugs (measured) 10123 feet Effective depth: measured 10472 feet Junk (measured) true vertical 10026 feet Casing Length Size Cemented Conductor 88' 30" Driven 784 sx PF 'E', 461 sx 'G', Surface 4414' 10-3/4" 150 sx PF 'E' Intermediate 10668' 7-5/8" 536 sx Class 'G' Blank Liner 377' 4-1/2" U ncemented Slotted Liner 912' 4-1/2" Uncemented TD TAG @ 10472' (03/22/2002) CIBP SET @ 10500' (03/19/2002) Measured Depth 130' 4456' 10608' 10161'-10538' 10538'-11450' True VerticalDepth 130' 4344' 10045' 9876'-10038' 10038'-10067' Perforation depth: measured Slotted Liner 10538' - 11427' Ported Liner Jt @ 10257' - 10263'. true vertical Slotted Liner 10094' - 10123' Ported Liner Jt @ 9937' - 9940' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR80 TBG @ 10187' MD. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" TIW SS HORPZONTAL Packer @ 10187'. 4-1/2" HES 'HXO' SSSV Landing Nipple @ 1514' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/14/2002 Subsequent to operation 03/29/2002 OiI-Bbl 197 Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 139 11148 1225 5106 8342 Casing Pressure Tubing Pressure 595 367 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. 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. ,~~/~~u~.~ ~~)~ Title: Technical Assistant DeWayne R. Schnorr Date April 01, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 03/17/2OO2 03/19/2002 O3/2O/2OO2 O3/22/2OO2 03/23/2002 03/17/02 03/19/02 03/20/02 O3/22/O2 1-03/P-16 Description of Work Completed NRWO OPERATIONS CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES CEMENT SQUEEZE: CAST IRON BRIDGE PLUG; CEMENT SQUEEZE CEMENT SQUEEZE: CAST IRON BRIDGE PLUG; CEMENT SQUEEZE CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT--FOR RATE CEMENT SQUEEZE: GAS LIFT--FOR RATE SUMMARY DRIFT TBG TO 10,400' SLM W/3.65" x 10' DUMMY IBP. SLOWED TO A STOP DUE TO DEVIATION. DUMMY OFF STA # 5 & 6. OPEN A/L LINE TO TEST TBG. GOOD TEST. RDMO WELL LEFT SHUT IN. MIRU DS CTU #3. LOAD AND KILL WELL WITH FILTERED 2%. RIH AND SET WFD COMPOSITE PLUG AT 10,500' MD. TAG PLUG - GOOD SET. PRE AND POST INJECTIVITY TESTS SHOW GOOD INJECTIVITY. POOH PUMPING CHANGED LEAKY PACKOFFS. LOAD AND KILL WELL WITH FILTERED 2% KCL, RIH WITH 3: BALL DROP NOZZLE. PUMP 60 BBLS CLASS G 15.8 PPG CEMENT. LAY IN CEMENT FROM PLUG TO ABOVE PORTED LINER, SHUT-IN CHOKE SENDING CEMENT INTO FORMATION. WHP HELD AT 400 PSI AND INCREASED TO 450 PSI IN THE LAST 10 BBLS. PUH TO SAFETY, HELD PRESSURE FOR 30 MINUTES. CLEANED OUT WITH BIO AND 2% KCL TO 10485' CTMD. POOH. FP WITH 60/40 MW. <<<LEFT WELL SI AND FP>>> RAN 2 7/8" X 12' DUMMY GUN & 4-1/2" XN LOCATOR. LOCATE 4-1/2" XN NIPPLE @ 10214' WLM-30' CORRECTION. TOOLS STOPPED @ 10472' CORRECTED. RAN 4-1/2" RHC CS TO 10214' WLM & SET. PULLED 1" DV FROM STA #5 @ 5246' WLM. CAME OUT W/LATCH ONLY (BK). PULLED 1" DV FROM STA #6 @ 3525' WLM. CAME OUT W/LATCH ONLY (BK). PULLED RHC. CONTAINED 1 SPRING, 2 WOBBLE RINGS & THE VALVE W/NO-GO FROM STA #6. SET 4-1/2" SLIP STOP CS @ 5397' WLM. RAN KOT & LIB TO STA #5 @ 5248' WLM. IMPRESSION OF TOP OF NO-GO ON VALVE. START IN WELL W/"RL" BULLDOG SPEAR. CONTINUE ON NEXT DAYS WSR. JOB IN PROGRESS. 03/23/02 RAN RL SPEAR TO STA #5 @ 5248' WLM. LATCHED & PULLED VALVE W/NO- GO. NO SIGN OF SPRING. RUN GENERIC GL DESIGN TO STATIONS #5 & 6. NOTE: SPRING FROM 1" BK LATCH LOST IN WELL. Fluids Pumped BBLS. Description 1 DIESEL FOR SURFACE EQUIP PRESSURE TEST TO 3000 PSI (1 TEST) 161 60/40 METHANOL WATER 57 DIESEL 542 2% KCL WATER j Page I 1-03/P- 16 Description of Work Completed NRWO OPERATIONS 220 SLICK 2% KCL WATER 68 BIO 60 15.8 PPG CLASS G CEMENT 11 O9 TOTAL Page 2 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser?A~3~ Commissioner Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI 1 & 2 May 20 ,. 20~!: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. i inspected 25 well houses on MP! Row 1 & 2 w! no problems witnessed. SUMMARY: i witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. Attachmen..,.ts: SVS DIU 5-20-01jc cc; NON-CONFIDENTIAL SVS DIU 5-20-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX ,,, Operator Rep: Mark Souve AOGCC Rep:.. Jo.hr,.. Crisp. Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: LPS 235 Date: 5/20/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Numb.er Number PSI PSI Trip Code Code Code Pass..ed GAS or CYCLE~ 1-01/J19 1880370 235 150 125 P P P OIL 1-03/P16 1951500 235 15'0 135 e P ' e .... OiL 1.05/O20 '1861066 .... , 1-09A/L2 1970290 235 150 130 P P P OIL , 1-15/P25 1930560 ' i'_ I")A/I 1 1961990 .... 1-19/I18 1950930 235: 150 125 P" P 9 OiL 121/K25 1900020 ...... 1-25A/K2 1970750 235 '"150 150 P' "P ' 'P' OIL 1-27/P20 ' 1870090, 235 1501 135 P P P OIL 1.29/M25 '1,861810 .... 1-31/M21 1950720 235 1~0 125 P' P "P .... 0IL 1-33B/L2 1982550 235 150 145 P P P OIL 1-'3~/O25 ' 18618'40 '235 150 1~5 P P P OIL 1-39/P 17 1880630 , 1-45/Q26 1891240 , , 1-47MM2 1972030 1-49/P21 '1880780 235 150 130 P ' P P ~ oIL 1-~5/R25 1880210! 235 lS0 145 P P P OIL 1-57/R23 1881140 235 150 140'' P' P P OIL 1761/Q20 1941420 235 150 135 P P P OIL 1-63/T22 18~0060 235 150 145 P" P P OIL 1-65/N25 1951880 235 150 1~0 P P P OIL 2-04/M19 1860820 2-06/J22 1870180 " 2-08/K16 1880040 ~-12/Q1'6 ,1921170 ', .... . 2-14/016 1861490 2-18/L16 1900430 2-20/L15 1900600 2-26/N14 1880550 2-28/P19 1880860 ..... 2-30A/E1 1981880 2-32/SN3 1901190 , , 2-36/O14 1900240 ' " 2-38/SN1 1901290 [ i i i i i i i i i i i i il i i ii iii ii Il Well Pemit Separ Set ~ T~t Test Test Date ~l, WAG, Number Number PSI PSI Trip Code Code Code Passed GASor .,., , ,, ,, . , .. . .. ,., 2-42~13 1881450 2-~~1, 1970710 ............. :2-46B/S1 1971370 , ., , , t . . ,, 2-48/013 1951660 2'-50~08 193~70 235 "'is6 ' 145 .... e' ~ ..... e ~I~ ., , , . , _ . ,. 2-52/S14 1870920 . . 2-56~I 1980580 . , , . ,. 2-58/S09 19~520 :2'-~0~13 1930830 " '255 150 130 e P P ..... OIL 2-62/Q17 '1861580 .......... 2-68/S 17 1880970 , .. , , . , . ~ ,, 5-01/SD7 1801200 . ,,, . ,,, ,,, , t . , , ,.. , , , ... Wells: 17 Components: 5 l' Failures: 1 Failure Rate: ~.~% Fl oo oar Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc oN oP- BEFORe c:LO~LM~D°c Department BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 HAND DELIVERED January 8, 1998 David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Johnston: I understand that the following wells: 1-03/P-16, 2-46A/R-10, 4-06A/Q-30, and, 4-34/O-38, are all within the Endicott Participating Area of the Duck Island Unit and currently under confidential file at the AOGCC under the provisions of AS 31.05.035(c). Please consider this letter your authorization to allow Julie Heusser, a contractor to BP Exploration Alaska, Inc., to examine and copy, if necessary, relevant portions of these files on behalf of BPXA and the Working Interest Owners of the Duck Island Unit. If you have any questions or require further assurances, please contact me at 564- 5630. Very Truly Your.s, BPX Endicott Asset Manager RECEIVED ,AJas~ 0ii & ~3as 60r~s. commission P t:. Ri'4 ZT AC:,GCC ind"¥vSdus'i Y/e'i 'J ,S e o 'J o,;:j -i' c ,.-'.-'.~ 'J H a 't e r" 'i' a 'i s i]~ la v ::- n 't. o r" 'y' ~800TM '107 57 'i 0/' 2 L,-/" 95 ,, 9 5 '~' 'J 5 0 D Z F I,../G R/' S F-: ~ g 8 0 0 ..... J 0 7'; 5 '? 95--~'i50 ~-HT/,3R -< .::,800 'i0'757 95 ~. 150 ZDL/CNL/(.~F,:,/CAL ~'~9800~ i0750 · in/24 "q~, 0'i/' 17/'"97 '~,,lei'i '~'s 'i'n comp'l'¥ance ....... Z n 'i' t 'i' a i C O iff h'1 ~:: i'"J T S Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. international Airpo~ Road Anchorage, Alaska 99518 - 1 !99 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) January 14, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ~(~',~ ~ ~O ~ '""7 ~ "'"'] '"7 The following data of the MWD & SLIM1 GR for well 1-03/P-16, Job # 97017, ,,vas sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape State of Alaska Alaska Oil & Gas Conservation At'tn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape ARCO Alaska, Inc. Dede Schwartz, ATO-1336 Anchorage, AK 99510-0360 . . I OH LIS Tape Exxon Company U.S.A. Alaska Interest Organization Attn: Susan Nisbet 800 Bell Street, EB3083 Houston, TX 77002-7420 1 OH LIS Tape Certified Mail' Z 777 937 523 UNOCAL Attn: Debra Childers 909 W.9th Ave. Anchorage, AK 99519-0247 1 OH LIS Tape Amoco Production Company Attn: Shirly A. Kuhr 18506 Osprey Circle Anchorage, AK 99516 I OH LIS Tape Certified Mail' Z 777 937 514 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska~ 99519-66T'2' ~.':'~ /-" ¢-~ -~:~i~ Date Delivered: , , ;.., - - ,.,:.. Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc 95-150 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22601 4. Location of well at surface .-..'~"~ ........ ? 9. Unit or Lease Name 3343' NSL, 2032' WEL, SEC. 36, T12N, R16E .............. ~ ,~~ ~,...~ 4892'NSL, 1554'WEL, SEC. 36, T12N, R16EAt Total Depth ,i' ~E,~ ¢~ ~.~:.; ~.~_ 11. Field and Pooll'03/P' 16 ¢ ,~ Endicott Field/Endicott Pool 298' NSL, 2440' WEL, SEC. 25, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. KBE = 56' ADL 034633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09/30/95 11/02/95 11/06/95I 6-12' AMSL feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11450'MD/10123'TVD 11450'MD/10123'TVD YES [] NO []I 1514 feet MD 1465'(Approx.) :22. Type Electric or Other Logs Run DIFL/ZDL/CN/GR, Gyro, MWD, SBT, CBL 23. CASING, LINER AND CEMENTING RE(:X:)RD SETRNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive Surface 88' Driven 10-3/4' 45. 5# L-80 42' 4456' 13-1/2' zs~ sx PF 'r; ~6~ sx 'G', ~50 sx PF 'E' 7-5/8" 29. 7# USS-95 40' 10608' 9-7/8" 536 SX Class 'G' 4-1/2" 12. 6# L-80 10161' 11450' 6-3/4" Uncemeted slotted liner 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) Slotted Liner 4-1/2", 13CR80 10187' 10187' 10538'-11427' MD 10094'-10123' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect wi 48 bbls diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11/10/95 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlTF IGAS-OIL RATIO rEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE !28. CORE DATA iBrief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED Anchor~,ge Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKE, .~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Kekilduk/L CU 9630' 9416' 2B 10315' 9968' 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./~,~ _(/~~ Title SeniorDrillin,qEngineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C E IV E D Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONs PAGE: 1 WELL: 1-03/P-16 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/29/95 05:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: POOL 7 09/30/95 (1) TD: 0'( 0) 10/01/95 (2) TD: 2249' (2249) 10/02/95 (3) TD: 4315'(2066) 10/03/95 (4) TD: 4475' ( 160) 10/04/95 ( 5) TD: 4910'( 435) 10/05/95 ( 6) TD: 6757' ( 1847) MU & RUN BHA #1 MW: 0.0 VIS: 0 MIRU. MOVE FROM 1-33/M-23 TO 1-03/P-16. RIG ACCEPTED 09/29/95 @ 1700 HRS. NU DIVERTER. MIX SPUD MUD. MU BHA IN DERRICK. RU ATLAS WIRELINE. NU DIVERTER. MU & RUN BHA #1 & ORIENT. PULL BHA MW: 0.0 VIS: 0 RUN BHA #1. DRILLED T/278'. SPUD WELL @ 0630 HRS. SERVICE MUD SHAKERS. OK. DRILLED T/2249'. CBU @ 2249'. POOH T/1012'. PULLED BHA. DRILLING MW: 0.0 VIS: 0 RUN BHA #1. PULL BHA. RIH T/2249'. BACK REAM TO BOTTOM. DRILLED T/3202'. CBU @ 3202'. POOH T/2249', AT TOP OF CHECK TRIP INTERVAL. RIH T/3202', ON BOTTOM. DRILLED F/3202' T/4315'. PUMP CEMENT MW: 0.0 VIS: 0 RUN BHA #1. DRILLED T/4475'. CBU @ 4475'. POOH T/1300', @ TOP OF CHECK TRIP INTERVAL. RIH T/4475', ON BOTTOM. CBU @ 4475'. POOH T/1013'. PULLED BHA. RUN 10-3/4" CASING T/4456'. HANGER LANDED. CBU @ 4456'. MIXED & PUMPED SLURRY & DISPLACE. RU FOR TOP JOB. MIX & PUMP SLURRY. CEMENT RETURNS TO SURFACE. CEMENT PUMPED. DRILLING MW: 0.0 VIS: 0 RD CEMENT UNIT. RUN 10-3/4" CASING. ND DIVERTER. INSTALL WELLHEAD INTEGRAL COMPONENTS. NU BOP STACK. TEST BOP STACK. INSTALL WB. RUN BHA #2. RIH T/3385'. SERVICE BLOCK LINE. RUN BHA #2. RIH T/4319', ON BOTTOM. DRILLED CEMENT T/4363' TEST CASING. CBU @ 4363'. TEST CASING. RUN BHA #2. DRILLED CEMENT T/4485'. CBU @ 4485'. RUN BHA #2. DRILLED F/4475' T/4910'. DRILLING MW: 0.0 VIS: 0 RUN BHA #2. DRILLED T/5966'. START SCHEDULED WIPER TRIP. CBU @ 5966'. POOH T/4456', @ 10-3/4" CASING SHOE. RIH T/5966', ON BOTTOM. DRILLED T/6000'. CBU @ 6000'. DRILLED T/6328' SERVICE MUD SHAKERS, CHANGED SCREENS. DRILLED T/6757' RECEIVED MAY 211996 Alaska Oil & Gas Cons. Commission Anchorage WELL : 1-03/P-1 OPERATION: RIG : DOYON 15 PAGE: 2 10/06/95 (7) TD: 7338' ( 581) 10/07/95 (8) TD: 8175' ( 837) 10/08/95 ( 9) TD: 8937' ( 762) 10/09/95 (10) TD: 9475' ( 538) 10/10/95 (11) TD: 9788' ( 313) 10/11/95 (12) TD:10289' ( 501) DRILLING MW: 0.0 VIS: 0 RUN BHA #2. DRILLED T/7225'. ROP DROPPED, BIT QUIT. CBU @ 7225'. FLOW CHECK. PUMP DRY JOB. OBSERVE WELL STATIC. POOH T/1003', @ BHA. PULLED BHA. RUN BHA #3. SINGLED IN DP T/2900'. SERVICE TOP DRIVE. RUN BHA #3. RIH T/6600'. FILLED PIPE & BENCHMARK SURVEY @ 5112'. REAMED T/7225', ON BOTTOM. DRILLED T/7338'. POOH T/7200' ~ MW: 0.0 VIS: 0 RUN BHA #3. DRILLED T/8175'. CBU @ 8175'. OBSERVE WELL. POOH T/7200' FOR SCHEDULED WIPER TRIP. SERVICE WEAR BUSHING MW: 0.0 VIS: 0 DRILL F/8175' T/8937'. CBU. OBSERVE WELL. PUMP DRY JOB. TOH TO BHA. PULL BHA. LD MOTOR, MWD & BUMPER SUB. SERVICE WEAR BUSHING. DRILLING MW: 0.0 VIS: 0 RUN BHA #4. SINGLED DP T/1964'. TEST MWD VIA STRING. SERVICE BLOCK LINE. RUN BHA #4. RIH T/8836' BENCHMARK SURVEY @ 8937'. WASHED T/8937', ON BOTTOM. DRILLED T/9475' REAM TO BOTTOM MW: 0.0 VIS: 0 RUN BHA #4. DRILLED T/9788'. ROP DROPPED, BIT QUIT. CBU @ 9788'. FLOW CHECK & OBSERVE WELL STATIC. PUMP DRY JOB. POOH T/1008', LD DP, @ BHA. PULLED BHA. REMOVE WEAR BUSHING ON WELLHEAD. TEST BOP STACK, WITNESS WAIVED BY JERRY HERRING OF AOGCC. INSTALL WEAR BUSHING ON WELLHEAD. RUN BHA #5. RIH T/5089' & TAKE MW/) BENCHMARK. RIH T/9693'. REAMED T/9788', ON BOTTOM. DRILLING RUN BHA #5. DRILLED T/10282' MW: 0.0 VIS: 0 10/12/95 (13) TD:10531' ( 242) 10/13/95 (14) TD:10773' ( 242) DRILLING MW: 0.0 VIS: 0 RUN BHA #5. DRILLED T/10358'. CHANGE IN TORQUE, BIT QUIT. CBU @ 10358'. FLOW CHECK & PUMP DRY JOB. OBSERVE WELL STATIC. POOH T/950' @ BHA. PULLED BHA. RUN BHA #6. SINGLED , SERVICE BLOCK LINE. RUN BHA #6. RIH T/9925' IN DP T/1619' o REAMED T/10358', ON BOTTOM. DRILLED T/10531'. RAN ELECTRIC LOGS MW: 0.0 VIS: 0 BHA #6, DRILLED T/10773', REACHED PLANNED END OF RUN. CBU, POOH T/9340'. RIH T/10773', CIRC. HOLE SWEPT WITH SLUG. POOH T/950', PULL AND STAND BACK BHA. R/U LOGGING/BRAIDED CABLE EQUIPMENT. RAN ELECTRIC LOGS; DIFL, ZDL, CN, GR. DENSITY LOG FAILED. HOLE IN GOOD CONDITION. RECEIVED ~AY 2 1 1996 Alaska 0il & Gas Cons. Commie~iofl Anchorage WELL : 1-03/P-1 OPERATION: RIG : DOYON 15 PAGE: 3 10/14/95 (15) TD:10773' ( 0) 10/15/95 (16) TD: 6200' ( 0) 10/16/95 (17) TD: 7030' ( 830) 10/17/95 (18) TD: 7525' ( 495) 10/18/95 (19) TD: 7890'( 365) 10/19/95 (20) TD: 8940' (1050) 10/20/95 (21) TD: 9317'( 377) CBU MW: 0.0 VIS: 0 RAN ELECTRIC LOGS. FMT STUCK @ 10297'. RUN BHA #7, STRIPPED OVER WIRELINE. CBU @ 10297'. PULL DP MW: 0.0 VIS: 0 RUN BHA #7. CBU @ 10297'. FISHED @ 10297'. POOH T/758', PULLED BHA LD FISH. RD LOGGING/BRAIDED CABLE EQUIP. R~{ 3-1/2" DP T/1578'. RAN DP T/4456'. SERVICE BLOCK LINE. RUN DP T/10773', @ BOTTOM)OF RESERVIOR. CBU @ 10773'. ABANDONMENT PLUG. MIX & PUMP SLURRY. PULL 5" DP T/7300' -- CBU @ 7300'. PULL DP T/6800'. CEMENT KICKOFF PLUG. CIP @ 0300 HRS. PULL DP T/5800'. CBU @ 5800' PULL DP T/0' DRILLING MW: 0.0 VIS: 0 PULL 5" DP T/0', @ WELLHEAD. RUN BHA #8. FUNCTIONED DOWNHOLE TOOLS @ 1087'. RIH T/4456', @ CASING SHOE. CHANGED ELEVATOR BAILS. WOC, KICKOFF PLUG. RUN BHA #8. RIH T/5970' BENCHMARK @ 5100'. WASHED T/6307', @ TOC. DRILLED CEMENT T/6464', @ KICKOFF DEPTH. DRILLED T/7030' POOH MW: 0.0 VIS: 0 RU BHA #8. DRILLED T/7525'. ROP DROPPED, BIT QUIT. CBU @ 7525'. POOH T/2500'. REPAIR TOP DRIVE MW: 0.0 VIS: 0 RUN BHA #8. POOH T/1022', @ BHA. PULLED BHA. REMOVE WB. TEST BOP STACK. WITNESS WAIVED BY BOBBY FOSTER WITH AOGCC. INSTALL WB. RUN BHA #9. RIH T/4450' SERVICE BLOCK LINE. RUN BHA #9 T/7100'. BENCHMARK SURVEY @ 5116'. REAMED T/7525'. ON BOTTOM. DRILLED T/7848'. PRESSURE CHANGE, DOWNHOLE WASHOUT. REPAIR. POOH T/6558'. WASHOUT IN DP TUBE BELOW TOOL JT. LAID OUT BAD JT. AT TOP OF CHECK TRIP INTERVAL. RIH T/7848', ON BOTTOM. RUN BHA #9. DRILLED T/7890'. REPAIR TOP DRIVE PIPE HANDLER. POOH MW: 0.0 VIS: 0 REPAIR TOP DRIVE PIPE HANDLER. OK. RUN BHA #9. DRILLED T/8940'. REACHED GEOLOGICAL END OF RUN @ TOP OF TUFFS FORMATION. CBU @ 8940'. POOH T/1022', @ BHA. DRILLING MW: 0.0 VIS: 0 RUN BHA #9. PULLED BHA. RUN BHA #10 T/280'. TEST MWD & ~ MOTOR. RIH T/4456', @ 10-3/4" CASING SHOE. SERVICE TOP DRIVE. OK. RUN BHA #10 T/8750'. RUN BENCHMARK SURVEY @ 5116'. WASHED & REAMED T/8940', @ BOTTOM. DRILLED F/8940 T/9317' RECEIVED b~AY 21 199G Alaska Oil & Gas Cons. Commissio~ Anchorage WELL - 1-03/P-1 OPERATION: RIG : DOYON 15 PAGE: 4 10/21/95 (22) TD: 9555'( 238) 10/22/95 (23) TD: 9811' ( 256) 10/23/95 (24) TD: 9890' ( 79) 10/24/95 (25) TD: 9957'( 67) 10/25/95 (26) TD:10072' ( 115) 10/26/95 (27) TD:10299' ( 227) DRILLING MW: 0.0 VIS: 0 RUN BHA %10. DRILLED T/9535', SLIDING. CBU @ 9535' POOH T/1020'. OBSERVE WELL @ CASING SHOE. PULLED BHA. RUN BHA %11. SERVICE TOP DRIVE, BLOCK LINE. RUN BHA %11. RIH T/9535', ON BOTTOM. DRILLED T/9555'. CBU @ 9811' MW: 0.0 VIS: 0 RUN BHA #11. DRILLED T/9650'. PRESSURE CHANGE, DOWNHOLE WASHOUT. POOH T/8410'? HOLE FOUND IN DP JUST ABOVE TOOL JT. AT TOP OF CHECK TRIP INTERVAL RIH T/9650' ON BOTTOM · · DRILLED T/9811'. BIT INDICATES UNDERGAUGE. BIT QUIT. POOH T/9535'. AT TOP OF CHECK TRIP INTERVAL. REAMED T/9811' WITH DULL BIT TO BOTTOM TO SMOOTH HOLE & EDGES. CBU @ 9811' CBU @ 9890· MW: 0.0 VIS: 0 RUN BHA %11. CBU @ 9811'. POOH T/2785'. OBSERVE WELL @ SHOE. PULLED BHA. RUN BHA #11. CHANGE SLEEVE ON 7-3/4" ADJUSTABLE MOTOR. PU NEW BIT & ORIENT. RIH T/4456' @ 10-3/4" CASING SHOE. FUNCTIONED DOWNHOLE TOOL @ 4456'. FILL PIPE @ SHOE & TEST MWD. RIH T/9811' DRILLED T/9872'. MWD FAILED-WORK STRING. DRILLED T/9890'. WORKED TOOLSTRING @ 9890'. DOWNHOLE TOOL FAILURE. CBU @ 9890'. MIX & PUMP DRY JOB. DRILLING MW: 0.0 VIS: 0 RUN BHA #11. CBU @ 9890'. POOH T/4456'. OBSERVE WELL @ SHOE. LD DP T/1860'. REPAIR IRON ROUGHNECK. RUN BHA #11. POOH T/2783'. PULLED BHA TO LD MWD & MOTOR. RETRIEVE WEAR BUSHING. TEST BOP STACK. INSTALL WEAR BUSHING. RUN BHA #12 WITH NEW BIT, MOTOR & MWD TO ORIENT. RIH T/4521' PU DP WITH NR RUBBERS. AT 10-3/4" CASING SHOE. CBU @ 4~21' TEST MWD TOOL. POOH T/2660'. AT TOP OF CHECK TRIP INTERVAL. RIH T/9800' REAMED T/9890'. DRILLED F/9890' T/9957' POOH MW: 0.0 VIS: 0 RUN BHA #12. DRILLED T/10003'. BIT QUIT. CBU @ 10003'. PUMP DRY JOB. POOH T/2795' PULLED BHA. RUN BHA %13. SERVICE MWD TOOL. RIH T/4456', @ 10-3/4" CASING SHOE. SERVICE BLOCK LINE. RUN BHA #13. RIH T/5188'. RIH T/9957'. REAMED T/10003'. ON BOTTOM. DRILLED F/10003' T/10072'. CBU @ 10072'. POOH T/6500' DRILLING MW: 0.0 VIS: 0 POOH. OBSERVE WELL @ SHOE & BHA. POOH WITH BHA. LD MOTOR, MWD & LEAD COLLAR. RELOAD MWD IN PIPE SHED. GR FAILED. PU BIT, ADJUST MOTOR, MWD & ORIENT BHA. RIH T/5089'. BENCH MARK SURVEY. RIH WITH DP T/9958'. ORIENT TOOLFACE & WASH F/9958' T/10072'. NO HARD REAMING. DRILLING F/10072' T/10299'. PUMPING SWEEPS WHILE DRILLING. RECEIVED ~AY 2 1 199~ Alaska 011 & G,3s Cons. Commlsslor) Anchorage .ELL : 1-03/P-1 OPERATION: RIG : DOYON 15 PAGE: 5 10/27/95 (28) TD:10620' ( 321) 10/28/95 (29) TD:10620' ( 0) 10/29/95 ('30) TD:10620' ( 0) 10/30/95 (31) TD:10620' ( 0) 10/31/95 (32) TD:10778' ( 158) 11/01/95 (33) TD:ll000' ( 222) TRIP FOR 9-7/8" HOLE OPENER MW: 0.0 VIS: 0 BHA #14, DRILLED T/10312'. BIT QUIT, PUMP HI VIS SWEEP AND CBU. OBSERVED WELL AND PUMPED DRY JOB. POOH T/2795' , OBSERVED WELL AT SHOE AND BHA. RIH T/5089', ACCEPTABLE SURVEY OBTAINED. RIH T/10245', WASHED TO 10312'. DRILLED T/10620'. RU CASING HANDLING EQUIP MW: 0.0 VIS: 0 RUN BHA #14. CBU @ 10620'. POOH T/9571'. AT TOP OF CHECK TRIP INTERVAL. RIH T/10620'. CBU. POOH T/2795'. PULLED BHA. RUN BHA #15 T/10620'. CBU. POOH T/2628'. PULLED BHA. REMOVE WB. NU BOP STACK. INSTALL 7-5/8" RAMS & TEST BONNET SEALS. RU CASING HANDLING EQUIP TO RUN 7-5/8" CASING. RU TOP DRIVE MW: 0.0 VIS: 0 RUN 7-5/8" CASING T/10607'. HANGER LANDED. CBU @ 10607' REPAIR STANDPIPE MANIFOLD. RUN CASING. CBU. CEMENT CASING. DID NOT BUMP PLUG. RD CASING HANDLING EQUIP. INSTALL SEAL ASSY IN WELLHEAD. RU & INSTALL 3-1/2" RAMS. TEST BOP STACK. WINESSING WAIVED OF TEST BY LOU GRIMALDI, STATE INSPECTOR. SWITCH TOPDRIVE & IRON ROUGHNECK TO 3-1/2" DP & RU. COMPLETE LOGGING RUN MW: 0.0 VIS: 0 RU TOP DRIVE. RUN BHA'#ll. PU NEW BIT FOR DRILLING CEMENT. SINGLED IN DP T/7500'. SERVICE BLOCK LINE. RUN BHA #11. SINGLED IN DP T/10495', TAG CEMENT. 23' ABOVE FLOAT COLLAR. ON BOTTOM. DRILLING CEMENT T/10518', @ FLOAR COLLAR. CBU @ 10518'. POOH T/3582'. PULLED BHA. RAN ELECTRIC LOGS F/10416' T/8650'. VERY GOOD BOND. COMPLETE LOGGING RUN WITH CEMENT BOND LOG F/10416' T/8650' DRILLING MW: 0.0 VIS: 0 RAN ELECTRIC LOGS. RD ATLAS WIRELINE. RACKED BACK DP. RUN BHA #11. RIH T/3615'. TEST MWD. RIH T/10440' CBU @ 10440' MWD FAILED. RIH T/10518', TAGGED FLOAT COLLAR. DRILLED FLOAT COLLAR, FLOAT JTS & FLOAT SHOE. DRILLED T/10640'. CBU @ 10640'. RUN BHA #11. CBU. DRILLED F/10640' T/10778'. DRILLING MW: 0.0 VIS: 0 RUN BHA #11. DRILLED F/10778' T/10982'. MWD SURVEY @ 10967'. CBU @ 10982'_ POOH T/10052'. AT TOP OF CHECK TRIP INTERVAL. RIH T/10982'. ON BOTTOM. CBU. POOH T/3615'. PULLED BHA. RUN BHA #12. RIH T/3647'. SERVICE BLOCK LINE. RIH T/10709'. MWD SURVEY @ 10709'. OK @ 10945'. DRILLED F/10982' T/Il000'. RECEIVED ~yIAY ~ 1 199G Alaska Oil & Ga~ Cons. Commission Anchorage : 1-03/P-1 OPERATION: RIG : DOYON 15 PAGE: 6 11/02/95 (34) TD:l1315' ( 315) 11/03/95 (35) TD:l1450' ( 135) 11/04/95 (36) TD:l1450' ( 0) 11/05/95 (37) TD:l1450 PB: 0 11/06/95 (38) TD:l1450 PB: 0 DRILLING MW: 0.0 VIS: 0 RUN BHA #12. DRILLED T/11286'. CHANGE IN TORQUE, BIT QUIT. CBU @ 11286' POOH T/10607', @ 7-5/8" CASING SHOE. FLOW CHECK. WELL STATIC OBSERVED. POOH T/3647'. PULLED BHA. DOWNLOAD ANADRIL SEA & GR TOOL. RUN BHA #13. RIH T/11184'. REAMED T/11286'. ON BOTTOM. DRILLED T/11315'. CBU @ 10607' MW: 0.0 VIS: 0 RUN BHA #13. DRILLED Tf11450'. CBU @ 11450'. POOH T/10607', @ 7-5/8" CASING SHOE. RIH T/11450'. CBU @ 11450'. POOH T/3647'. PULLED BHA. RU CASING HANDLING EQUIP. RUN 4" CASING T/1276'. RUN 2-1/16" TUBING T/1276'. RU LINER HANGER & PACKER. RUN CASING ON LANDING STRING T/10607', @ 7-5/8" CASING SHOE. CBU @ 10607'. BROKE CIRC. RU SLICKLINE UNIT MW: 0.0 VIS: 0 RUN 4-1/2" CASING ON LANDING STRING T/11450'. CBU @ 11450' SET LINER HANGER & PACKER @ 10187' & TEST VIA ANNULUS. OK. RELEASE PACKER FROM HANGER & SHEARED OUT BALL SEAT. PULLED DRILLPIPE. AT TOP OF LINER WITH 2-1/16" WASH STRING. CBU @ 10187' HOLE DISPLACED WITH BRINE. FLOW CHECK WELL & BLOW DOWN TOP DRIVE. OBSERVED WELL STATIC. LD DP T/10160' LD TUBING T/1200'. RU SLICKLINE UNIT. RU TO SET PLUG IN XN NIPPLE IN LINER. RUN TUBING MW: 0.0 RU SLICKLINE UNIT. RU SHOOTING FLANGE & LUBRICATOR. CONDUCT SLICKLINE OPERATIONS. COMPLETE RUN WITH RUNNING TOOL & NIPPLE PLUG F/0' T/10244'. TEST LANDING NIPPLE ASSY VIA STRING. OBSERVE LEAK ON NIPPLE PLUG. RETRIVAL RUN FOR SLICKLINE OPERATIONS. PLUG NOT HOLDING. ATTEMPTED 3 MORE SETTING RUNS ON SLICKLINE EQUIPMENT & RETRIVAL RUNS WITH NIPPLE PLUG T/10244' COMPLETE RUN WITH STANDING VALVE. PLUG TESTED OK. RECOVER TIW OVER SHOT/BELL GUIDE. RD SLICKLINE UNIT. NU TOP RAM & CHANGE TO 4-1/2". RU BELL NIPPLE. TEST BOP STACK. OK. RU TUBING HANDLING EQUIP TO RUN 4-1/2" SINGLE COMPLETION. RAN TUBING T/10187' FREEZE PROTECT WELL MW: 0.0 RUN 4-1/2" TUBING T/10187', @ TOP OF LINER. INSTALL TUBING HANGER. REV CIRC @ 10187' HOLE DISPLACED WITH INHIBITED BRINE. SPACE OUT TUBULARS. LANDED HANGER & ENERGIZE SEALS. INSTALL HANGER PLUG. RD BOP STACK. INSTALL ADAPTER SPOOL. TEST DUAL CONTROL LINES. RU SURFACE TREE & TEST. RETRIEVE HANGER PLUG. TEST TUBING. TEST CASING & SHEAR RP VALVE IN TOP GLM. FREEZE PROTECT WELL WITH DIESEL. SIGNATURE: (drilling superintendent) DATE: RECEIVED I,~AY ~ 1 1996 Alaska 011 & Gas Cons. Commission Anchorage RECEIVED f4~R ii 2 ~99~ BPXA PDC PA~E NO, ~rAN~ WELL NAME 1-03,4:'-16 HA D_-~ATICO'; i ENDICg]TT LOCATION 2 DOYON 15 ,9~N~IC DECLINATION 28,67 GRID COh~;ERG]NCE AHGLY~ -QoOO DATE~ 02-NOV-95 WELL NL~ER 0 APl i.~;; ~ 5002"72260100 ~LL H~ LOCATION: LAT(N/-S) 70 , 35277350 DEF'(E/-W) -i47,955722939 ,JO~ ~.fJ, 36731 AFE NO, 727101 a'lrT~. ~ : ~. IN F~DINI'(?IP) .~ M~'iSURED DEPTH 88,00 TR~ -V~,"[' DEPTH 88,00 -, ~ T ~...'?T,", I ~z.~MUTH 0,00 LAT!~JDE(N./-$) T?. IH GYRO S~qJEYS Fq;iOJE~ ~"TED SURVBg' RECEIVED MAY Y. 1 1996 Alaska Oil a Oas Cons. Commission Anchorage ~;E ,NO,. SURLY ~LL'ULATIONS CIRCULAR ~C )/F'-16 HA ~EA~RD INTERVAL VERTICAL D~PTH D~F'TH ft ft ft 88,00 0,0 88,00 I80,00 ~.0 180,00 2./-6,00 86,0 356,00 90,0 .355,95 449,00 93,0 448.81 TAE~ET STATION AZI~L~tl LATITUDE SECTION I~D& N/-S ft ~eg deg ft 0,00 O,C~ 0,00 0,00 0.26 0,32 304,72 0.15 1,25 1,00 307,76 0,74 3,98 2,50 310,~ 2,4? 9,07 3,80 30%20 5.74 ErRn~dRE DlorLAC:HEITr at ft ft 0.00 0.00 -0,~ 0,26 -I.00 !.~ -7.07 ~.10 AZIMUTH BLS dee/ deg lOOft O,CX~ 0.00 ~w,~ 0.35 9o6,~ 0,7? 308,48 1,~7 309+C6 1,40 541,00 632,00 724.00 816.00 908,00 '~o0 540,51 91.0 631,01 ~.0 722,31 92,0 8!~.4~ 92,0 ?04,56 16,36 5,30 307,~ 10,22 25,85 6.70 308.60 16.06 ,.~ 7,50 314.~'J ~.~0 49,41 8,20 3~8,00 61.68 7,70 ~1,20 42,34 -k,8; lo,40 308,55 1,64 -20,~ 25,9i ~8,31 1,55 -,8,8~ 37, ,....°'-' 30?,30 1.15 -37,52 49,75 311.03 0,95 .~ 7. 62,35 I004.00 1099.00 i174.00 12~?.00 1~5.00 96,0 95.0 1094.14 95,0 1188.39 95.0 1282,~ 96.0 1o, 6.69 72,92 6,% 332,50 52,47 82°02 6,60 346,20 89,83 7,80 358,80 74,58 96,04 9,80 [6+,~$ 88.78 98,34 11,30 ~,~':~ ~n 104,27 -52,47 ,..,~v'~ ~n315,00 .~' ,71 -~^,41 ~.~ 44 318,08 1.72 ~ ~4,~ ~2,20 2,08 -~ ,84 '"' ~" ' -55.A7 104,79 q~ o~ ~ ~ ... ~l./,~ -47 ~ 1N,~ '~"" '~ c' 7 I.,1, 1611 1706,61 1802,90 1898,34 132,5 150o,o9 94,3 1557,05 ?4,7 1691,?? 96,3 178..4,46 95+4 1880.11 95,47 11,68 45,W 124,~" ~ 90.58 11,16 53,74 136,31 84..35 11,24 54.% 147.10 77,84 1I,I0 ~,09 1~,85 71,14 11,!.7 56,21 168,25 o'l,:,, 1.0 -30,TM 127,9A ', , - 16 + =': ~ o.':, ":,~ ~,.- ....... o_'..o,07 :l,80 -1,67 i47,10 357,35 0,17 13,57 158, ,~.J"" 4+91 0,19 '" O ~a '~n ".-o 170,6~ 9,7:[ : 19'}~,87 2089,33 21~3,13 2279,80 2378,71 95,5 i9/o,8~ 95,5 ~0o/,68 93,8 2160,04 96.9 ~350,88 64,24 10,97 ~.,..., ,.: ~o: 1,~° ,:,o~, ~n 44,0.5 _ !83 , ;:4 13. ,&~ 0,23 58,00 10,:31 53.37 o. ,? ~,, ~ '- ~., !.~ +~..-- _.-,,,.,~ 1v7',.~, 17,25 0+94 53,65 ,',-= · ,= ~,,_, 4/..,u.~ 1,49 1;,=,99 50+14 9+67 47,:.4 210,14 ,:..'~, o,~ ...... ,:,:_.'.'=, ._.,. '~" 21,''~.),.0,~... ;.:7 46,09 '" ~" "' ?5 O, "' ,,.~; 50,15 220,80 ,.03 ,4/1,00 2567," OO 2.662.35 2,'.~ +11 ~'% ir, £02 0 ~ 0£ 96,7 25[c?,10 ?4,7 94,8 27~ 96,5 2821,14 42,13 9,75 ~" ~ ..... *"~ 30,.~.. 9,41 50,=~ 262,93 26.~2 9,¢5 45,50 273,51 ...... -:o.~,,'~ 24,82 u,Sv 118,87 ~o ,',= ~ ~ .c~+lo 0,21 130,58 284,68 ~,30 0,62 142,50 279,06 28,45 O, 1.8 154,~:., 31.4,(;0... ~,~"' "~ 0,~5 OOA0ej6 3043,09 . ~i0 33Z7,38 94,? 2914,'~'o~ 94~5 [<107,78 93,7 3100,13 rp ~ 3194,20 95,3 3288,3! · .: ~? 23,65 10,22 4~,,,, 28,4,78 20,17 9,78 46,73 =,o,...,~°' 0.~ 16,?? 9,57 45,26 307,00 13,82 ?+00 ' '"' ~ ' .... 4t.~./ oJ.z+oo 10,44 %05 47,5i ~-, ,, OLi ~/O i.:._,, ,: .:,,",, ..:- .." 30,2..-'; 0 177,83 '-"= "- 3:: .... ~h' 30,99 0,47 189. 1.5' 360,5? 31, ,.'d 0,~,.,"-'~ 200 .-u .... ,,.... .~,' ..... 0 32,""' - ~0 - '-",..' 2ii ......... "= ':":' '~ '~ 0 06 e ~/ ._;07 * 7 _: -J~_ + ~., z 3423.50 35!5,03 o,.11,'.~ 3708,26 3805,24 5'6.1 ~83,05 9!,5 3473,C~ 76,5 ~68,07 70,u 0t D7 2,22 10,30 S0~24 ~,v', ~,', -t,48 9,A7 ...... -4,43 '" ~ z+o~ 46 .... 37i,94 -7+81 10.12 ~"~ 40 ~£0, ....... ~o~,Y4 49! ': 248,18 '~= '~ ~='-' "' .... 50 ..... " ,!~9,5A :34,04 0,<:.~ 34,53 34,'-?0 O o MAY ?..1 1996 Oil & ~n Oon~. commission Anchorage r,& Hi). 3 .... 03/P-16 HA TAPGEt STATI~ AZIMU~ LATITUDE SECTION IHCUq. R/-S ft dea deg. ft -1I .a~ 9.76 47.~2 394,~ -15,76 9.47 52,62 404,64 -20.00 9.79 47,02 414.93 ~ ~ ?.62 42,25 426,48 -Z;.'&7 9.54 42.62 437.80 DEPARTURE DISPLACI~'HT at E/-W ft ft 283.1B 485,4B 2~5,53 501,07 307,70 ' 516,57 319.10 532.64 3Z?.45 547,91 AZI~.KH DL9 deg/ dec lOOft 35.68 0.46 36.14 0,88 36,56 1.04 36,81 n c.~ 36,96 0.11 ~5,5 4320.97 i84.6 ~'~ '" 4~0~,6/ ~5,4 4596,56 r.~,o q6Yg,Ot -27.87 10.16 45,70 449,51 -34.89 10.13 47.'?3 471.,'-'5 -39,20 !0.~ 50,18 482,86 -~o.~ 10,30 47.9I 494,09 -48,/-'5_ 10,44 ~.31 504,54 340.85 564,12 37.17 0.85 oz~ ~ 596,19 37.69 0,21 3~.34 ..A'~,~.~-~°°:38,0I 0.48 390,29 6~.65 38,31 0.43 403.73 646.19 38.67 1.60 4940,02 5!31.14 5227,53 5.:.~.~, 10 94.3 '76.0 .~0o4, %,4 5159,54 'f'3+6 525! -54.98 9,92 56.26 513,79 -61,16 10.25 55.96 5~,08 -./.70 10,59 58+79 532,44 -/4,~i i0.67 52,50 542,46 -78.86 9,8~ 46,~8 553.18 417,60 662,10 39,10 0~55 431.43 678.05 39.52 0.35 446,06 694,59 39,96 0.64 460.72 711,71 40.34 473.43 728,11 40.56 1,39 5416,46 5511,08 ! !! 5004,00 5796,54 95~4 5~5,54 04 .A :'zl.']-n "' , . .;-~u,/2 ?--, ; ~.. q' C,. /'. .6 :2 97._>'-- %26,&5 -82.81 i0.11 49,39 564,18 -86.36 9.87 44.~ 575.5~ -89.14 10.16 44,17 587.06 -92.48 9.66 47.~ 598.74 -96,16 9.72 47,87 609,44 485,73 744,46 497.68 760.77 40,86 509.03 /77,.01 40.93 521,05 793,72 41,03 532.~1 809.51 41.16 0.08 5¢89 ~ 6179,~.4 97,0 r~'A'" '"" .. J7~7~78 9A,? ..... = .... ou05,~ 93,8 6097,56 '"=to.,: 6191,90 -99,71 9.50. 46.~ - iuo ..... ,.,,~ ?.99' ,E....~8= 631,58 -107.06 10.37 48,31 ~43.16 ~ 0 -110.43 '?.76 4o,,7 654,49 -112,74 9,83 41,04 ...%6.49 544,52 825.0.-, 41,28 C). ,o.:. ~" 4i,c.o O. 556,44 841.74 '~ 50 569,05 856,76 41,50 0.50 580,87 875.(~ 4t '-'"' _ :_,: 1,04 591,87 891,36 41,61 0,53 6409.40 6504.°~ 6694,97 94.8 6417.04 ?6.3 6511.73 ~,~,:~ 6604 =' -114.64 '^ ~' ~v,~ 40,95 676,87 -t15.44 10.20 40.~ ,%4.17 '117,54 9.8I 42,57 696,48 -!20,19 i0,01 44.48 708.50 -l~a. OI ,~,~= 38,52 722,42 no to %7.76 41.03 0.40 607,~ ~ 914.77 41,59 0.~5_. .18.1/ 931,24 41,59 0.5~ 6~?.59 947,81 41,62 0.40 641.31 966.01 41.60 2.90 8789.59 6885.70 65'79.29 707:3,87 7!69,65 94.6 'A ' 96,1 6790,51 93.6 ..4881,43 94,6 6973,07 95.6 7065.60 -~.,-.22 12,74 33.37 '120.C~ 13,67 23.,97 758,45 -115~3 ,0.80 20,&5 778.78 -t09,04 I4,77 16,29 801,10 -!00.43 15,27 11~ 825,16 .5o,04 986,00 ~43.48 1007.70 671.95 i028.75 679,.S'5 10~0.o/ 685,35 -o ,= 41,46 0.87 4i.,18 o -- 40.78 0.80 40.30 I ~= 39.71 1.32 -%,ii 15.19 8,27 849.85 -79.2? 14,94 8.78 874.40 -68,66 15,10 6,56 898.67 -6!.44 15,28 9.02 915.20 -46,ov ~ ~ ~" ' A ~ · ~^ 1~,~4 ~,93 y4~,3~ M9.72 10'74.51 39.06 693,401115,97 697.10 1137.35 RIV, D 69'?,66 ll_,,-,,,O 37.40 0.34 .q, ,--.' 703.95 1181.o4 lV~.~{~.~5 3 Alask80lt & Oa~ Cons. Commission Anclmrage SURg~¥ CALCUMTION8 ~Fx-~~ CIRCU~R ARC --i /F'-16 HA Ni~R~ INTERVAL VI~?I£AL D~PTH D~H ft ft ft 7710.76 64,5 7567.85 7806.69. 95.9 7680.67 7901,60 94,9 7772,89 7998.40 96.8 7866.98 8094.38 96.0 TAG:GET S?ATION AZIM~PH I,ATITIJ'QE SECTION INCLN, H/.-S ft deo dca ft -~*~. 12 15,~) 5,53 965,27 -26,71 b,8, 7,'~, 989.38 -16.97 13,40 10,10 1011,51 -7.~ 13,80 8,40 2,04 12.80 10.19 DEPARTUR~ BISF'LAC~.MEgr at AZI~TH ~/-W dea/ ft ft deo 10Oft ~ , 70~,,:,2 11'95,,.,,. ~ 36,17 0,~ 706,26 1216,76 35.60 1.63 711,&j 1Z36,74 ~,13 0,91 715,25 1~7,~. 34,67 0.58 718.60 1277,~ 3~.25 1, la 6190.03 8285.02 8381.46 8475.76 8572.12 '~.6 ~353.98 ~,0 8147.~ 96.4 8241.83 94,3 8334.31 96.4 6428.86 9.41 10,95 M.78 1074.97 I5,62 11,11 i3,95 1092,57 22.18 i1,~ ~3.87 11!0,73 28,65 11,30 13,94 1128,64 35.25 I0,9~ 13.11 1146,70 722,99 1295,48 oo,~"~ ~" 2,17 731,97 'q~ '~ /oo.o, 1347.62 33.~2 / ~),/~ 0.42 8&55.70 6760,76 8855,45 8961,50 9055,01 ~,6 8520.'93 95,1 6614,63 94,7 8707.92 106.1 8812,37 94,5 8905.49 41,67 9.70 10,29 1163,09 48.10 9,74 11,11 1178.86 54,43 9,95 11,57 ~194~74 61.92 10,05 9,i0 1212,65 68.33 9,54 12,73 1228,64 744,13 1380,77 32,61 1,42 -/'7' . /4. ,1i 1395,67 32.36 0,15 750.30 .,..-,,.,,'a~,~.~.,,";, 32,13 o,,.o":'~ _ . :.'.,'/,91 31,85 0,42 '7.. ¢: ,c, '144?,'.;'.'q31,,z,3 0,85 9158,31 92~5,73 9a~9,32 9~Ofl 91 9495,54 102.3 ?006,47 88,4 9093.85 92,4 9185.33 98,9 9283.04 57,3 '.9339.~ 74.06 8,89 15,03 1244,~ 78,44 8.74 15,94 1257,60 83,36 V,O3 1~,.~ 127[,47 89,96 8.65 4,34 1266,46 94.24 8.31 ~ =" ,o~,.,~ ~..~,.~ 31,43 0,73 764,16 1471, =-/.,, 31,o~ 0,23 767,67 i485,24 :}1,12 0.65 7A9,?? '" .... l~,z~ gO.";~ 1,~'~ .......... 770,51 i506,80 30,75 953[,05 '1563,20 9590,96 9626,94 9657,67 0'"5,5 9374.84 32,1 9406.66 W,8 94:34.03 36,0 9469.37 30,7 9499,42 96,95 8,41 1,85 1300,05 '?9.86 9,00 353~40 1304,?0 103,12 10,i7 3~./~ [30?,43 108.50 11,49 ~7.58 1315,83 l~,u~ lZ.o4 330,61 ~,J.~°'~ ~o 770,7,~_ ....,o,.,tc!t ~ 30,05 0,76 769,69 i518,69 30,45 6.23 767,54 · ~o,~: ~g,,':o 5,6'! 9687,15 9747,48 9781.02 9804,01 29.5 9528,09 34,8 9561,57 ~,6 9585,87 :)3,5 9617,3I ~o.u ~60B,53 120,39 14 .... :~': ~v ~.. 40 ,07 ~u~.~ ~0~/+ ~,o~ I6,99 320,80 133.4,89 136.91 19,08 o'~no~u,~o7 1040.??""' 148,12 21,59 ~ ...... "'"' ~cv,c7 x56../0 23,64 3J.5~79 i356.~c ,ol,u4 1530,09 ~"',83 ......... looo 29,50 /Su,oa i536,64 '"" 23 6,21 742,88 '= ~J4u 28,62 7,48 ,'o>,:o :..,,b,,'8 28,51 11067 9869,37 9855.17 9927,51 ,>.- ,..., 9&57,83 ' '~ ~ 709/ 25.8 971%62 .,~,.. 9747,09 ')z 3 9~7.44 170,06 26.00 312, I0 13,'5,5,90 185.17 28,64 306:% ""-'"' ''~ 197.78 34,5'0 30'5,96 J. 383,05 215.01 "'~ "' ":.r.,, o-, / 0 o.J0 .~ ]4 ~ "~"'q """ 1-2, ;.'o + :30 234.90 · -,o,87 :308,41 1405,69 727,20 l,:~ ,l.~ - .'~ ~8,uo 8,73 .t...'~! 475.55 155'?,72 25.44 3,08 ?99i,86 10027.r~) 10058,46 10~3x).00 10~20,~4 28.0 9800,68 35,1 9829,70 31+5 9855,37 31,5 on.~ '~a ' '~1 ~ y ~ 30~8 YYOa.o7 250.55 34,[6 308.0'0!l*~+'%'?'~'r m,-, 270,34 34.51 306,71 N27,,t! ...... t ,.~, ~.~ 307,76 ~?,12 304,8~ 1449,61 · ,~/.',0 42, ~,~ 306~;>[ ~"* ~ /4.q..'-.5 '... 563,20 25,12 , ;, '1 --:? ,M: ,// 1567, J.,.-=~ 24,.4 i 2,29 ,m~ :-,~ *[r~-, t.'..t t-j~ bO--,, £." Z.;/: i, .a'r z....,, }:'6 ~' 617,,3:2 1575,,f,':/ 23.0,3 __ ~0,39 1996 .~G£ HO, 9URVEY CALCULATIONS CIRCULAR ARC MLCllqODx:~:~:~* .$/P-16 HA IHF. ASURHD INIUZRtIAL V~q~ICAL TARGET STA?ION AZIITdTH -LA?ITUDH DlZI=ql{ DEPTH SEt'lION IRCDh I,V-S ft ft ft ft deg. deg. ft 10151.05 30.2 ?925.44 348.85 45,45 305.26 I473.49 10185.67 34,6 9949.02 374,20 48.71 305,80 1488,23 10216,64 31.0 9968,81 3?8.00 51,81 306.14 1502.21 10247.83 33.2 9988.70 424,55 54,52 305,03 1517,66 10280.01 30.2 10005,72 44?.47 56,86 305.05 1531.98 DEPARTURE DISPLACEPH~IT at ~ZIPPJTH ft ft deo 584.17 1585,06 21,63 563.54 1591.35 20.74 544,27 1597,77 17.92 522,67 1405,14 19,00 502,26 1612,21 18,15 DIS 10.13 9,47 10.06 8,58 7,76 10309.42 2~,4 10021.14 474,52 5%?0 305.60 1545.46 10343,31 33,? 10037,24 504,32 43,36 306.51 15.~,01 10377.20 33.9 10051.53 535,02 ~,76 304,27 1582,24 10406,79 29,6 10062,59 562,44 6%34 306,40 1598,50 10440.~ 33,7 10073,55 594,25 72,~ 3~.32 1617,37 481,83 1619,78 17,31 457,72 1629,61 16,31 433.00 1640.42 15.-230 410,89 1650,47 14,42 385,26 1~2,62 13.40 10,44 I0.49 10.04 8,74 %88 10473,3~ 32,9 10082,44 425,94 76,0I 306.56 1636.21 10501,65 28.3 10088,38 653,53 7?,72 306.93 1652,73 10531,93 30.3 10093,05 683.42 82,53 306.77 1670.67 10561,24 2%3 I0~6.54 712,50 83.78 304.77 I688,09 p 10422,00 60,8 10102,17 772,86 85,60 309,20 1725.33 10715,40 93,6 10107,35 845.~ 85,40 311,40 1785.69 10747,50 31.9 10111.35 897,18 87.20 313,70 I807.26 10777,40 30,1 10112.?0 ~6,88 ~.70 312,50 1827.84 10805,00 27.4 10114,38 ?54,00 84.?0 311,30 184~,11 10834,00 31.0 10115.41 984,75 89.30 311.30 18&5,56 359,75 I675,29 12,40 337.62 1686,86 11,~ 313.68 1699.86 10,63 2?0,37 1712,87 9.76 242,70 1742,32 8,01 171.53 1773,91 5.4? 148,12 1813.32 4.69 126.21 1832.17 3.?5 105,84 1849.14 3,28 82,~ 1868,38 2,53 10.18 13,20 9.31 4,25 4,96 2,34 9,29 4,75 4.37 7,74 10867,00 31+0 10115,73 1015,55 89,50 310,~ 1886.85 1087P.O0 32.0 10115.70 1047.37 ?0.40 307.60 1907.44 10736,00 37+0 10115,28 1084,26 90,70 308,50 1~0.75 i0963,00 27,0 10115,17 1II1,I9 89.80 306.30 1947,52 10~98.00 35.0 I0115,5~ I144.07 88,80 2308,60 1969.33 57,14 1887,78 1,80 34.~ 1707.74 5,91 I930,76 0,18 -15,25 1947,58 359.55 -42.62 I969.79 358,76 2,66 4,44 2,98 3.41 3.17 11028,00 30,0 10116,51 1176.00 87,70 308,I0 1987.98 11061,00 33.0 10117,89 1208,91 87,50 307.60 2008.21 11073,00 32,0 10119,20 1240,85 87.80 304.50 2027,47 11122,00 29+0 10120,27 1269,81 88,00 306.70 2044,75 11156,00 34,0 10121,57 1303,76 87.60 304,40 2064,98 -66,10 1989,08 2358,10 -92,13 2010,32 357.37 -117,65 2030,88 356,68 -140,92 2049,60 356,06 -168,2I 2071,82 355,34 4,35 1.63 3.56 0,97 1.47 11188,00 32,0 10122,86 I335,72 87,80 305,00 2083.64 11217,00 2~.0 10123,92 1364,69 88.00 304.90 2100.65 11255.00 38.0 10125.15 I402.65 88.30 304.~ 2122.84 11285.60 30.6 10125.68 1433.25 89,70 304,40 2140.17 11313.00 27.4 10125.42 1440+65 91,40 304.10 2155,59 -194.18 2092.67 354,68 -217.64 2111,70 354.09 -248,46 2137.33 353.32 -273,67 2157,60 352.71 -296.32 2175,86 352,i7 4,42 6,58 6,10 4,62 6,30 11346,00 11378.00. 11370,00 33.0 10124,44 1493.~ ?1.~ 304.30 2174.13 32.0 10123,97 1525.&3 91,10 305.70 2192,48 I2,0 10123,74 1537.42 91,10 306.40 217~,54 -323.40 2198.07 351.53 0,67 -349,81 2220,21 350,93 4.42 -359.51 2228,73 350.72 5,83 RECEIVED RECEIVED MA~ 2 2 i996 - 'BPXA PDC : P~GE NO, c~'~ ss~ " W'J~I,T. HA~ 1-03/P-[G (PH) LD~TIO~ 1 I~DI~TT LOCATIOH 2 DOYOH 15 HN:;:N£TIC DECLINATION 28,67 ~ID CO~[;I~ICE ANOLE DhTE: 11-0CT-95 ~LL NUMBER bPI NO. 5002?2260100 W~L ~AD LOCATION: LAT(N/-$) 70.952_77,'3~0 JOB HO, 36731 A~ NO,. 727101 AZIMUTH ~1:]1't ROT~¥ TABLE TD TAR(;:~T IS D~P(~-W) -147,9557~39 :334.62 TIE IN F~INT(TIP) : MB~SUR~D DEPTH 88.0O TRUE VERT D~TH 86,00 INCLINATION 0.00 AZIMUTH 0.00 LATITUD~(N/-S) D~'ARTUPJ~(?.,/-W) 0,0 RECEIVED MAY 21 199G Alaska 011 & Gas Cons, Commission Anchore, ge 541.00 632.00 724.00 816,00 1004,00 1099.00 1194,00 1289.04) 1385,00 I517.S4 1611,86 1706.61 1802,90 1898.24 1993,87 2089.33 2163.13 2279.80 2376,71 2471.00 2567,66 2662.2~ 2757,11 2853.61 294O,56 3043,O9 3136,76 3232.O9 3327.36 3423.S0 3515,03 3611.48 3708.26 3805,24 92.0 S40.51 91.0 631,01 92.0 722,31 92.0 813,45 92.0 904.56 96,0 999,79 ~S.O lo94.14 95,0 I18~,37 95.0 1282.29 96,0 1376,67 132.5 1506.59 94,3 159%05 ?4.7 1691.~9 96.3 1766,46 iS.4 1680.11 95,5 1973,85 95.5 2067.68 93,8 2160.04 ?6.7 2255.33 96,? 2350,88 ?4.3 2443.82 96,7 2529.10 94.7 2632.47 94,8 272S,95 %.5 2821.14 94,? 2914,69 ?4.5 3OO7.78 93.7 3100,13 95.3 3194.20 95,3 328~,3I 96+1 :3383.05 91.5 3473,08 ?6.5 3568.07 96,8 3663.53 97.0 3759.11 TA~'~£T STATION AZIIIUll4 LATITUD£ $~TI~( INCH, ft d~ deg ft 0.00 0.00 0,00 0,00 0.22 0.32 304.72 0.15 1.10 1,00 307,76 0,74 3,59 2,50 310.00 2,4? 8,21 3,80 309,20 5,74 14,73 5.30 307.00 I0,22 23.23 6.70 208.,~ 16,06 33.68 7.S0 314.20 22.60 45,5? 8,20 318,00 32,66 57.87 7.70 321.20 42.34 69.8? 6,90 332,50 52,47 80,94 6,60 346,20 62.63 92,17 7,80 358,80 74,58 104.07 9,80 16.60 88,78 114.72 11,30 35,50 104,27 12S.42 11.68 45.b-7 124.23 120.26 11.16 53.74 136.31 133.61 i1.24 54.48 147.10 I36.80 11,10 b5,o9 157.85 139.67 11.17 56.21 168.25 -,..stP-16 (Pti) D~ARTURE DISPI.ACI~ at ft ft 0.00 0.00 -0.21 0.26 -1.00 1.25 -3.13 3,99 -7.07 ?.10 AZIi~H DLS deo/ deq lOOft 0.00 0,00 304,72 0.35 306.~S 0.79 308.48 1,67 30?.06 1.40 -12,82 16,40 30G,~ 1,64 -20,33 2S.91 306,31 1.55 -28,83 37.26 309,30 1,15 -37.52 49.~ 311.03 0.75 -45,78 62,35 312,77 0,72 -52,47 74.20 -56.41 84.44 -57,84 94.36 -5~,67 104,79 -47.87 114.73 315+00 1.71 318,08 1,72 322,20 2.08 327,'?i 3, 53 330.04 3.91 -30.75 127.98 346.10 1,54 -16,57 137.31 353.07 1.80 -1,67 . ' 147.10 359.35 0. i7 13.57 158.43 4.91 0,19 28.78 170,69 9,71 0,24 142.28 10.97 56,69 178,38 44.06 182.74 145.20 10.31 53.37 168.47 58.51 197,34 149.2LA 9.75 46,05 198,~9 70.97 211.26 154.35 9,67 47,54 210.14 82.84 225,88 158,76 9,57 50,15 220,80 '?5,03 240,38 162.06 9.75 47.53 221.22 168.03 9.71 46,33 242,37 172.56 9.48 49.SS 2S2.94 176.47 9,41 50,52 262,93 181.00 9.46 45.50 273.51 13.88 0.23 17,25 0,94 17.63 1.47 21.52 0,27 22.29 0,46 106,94 254,75 24,82 0.50 118.87 26?,?5 2J.13 0,21 130,58 284,66 27,30 0,62 142.50 299.06 28.46 0.18 154,2J 314,00 29,42 0.85 165.91 32?.59 30.23 0,8i 177,83 345,37 30,99 0,47 189.16 ;3,50.59 31.64 0.35 200.26 375,50 32,23 0.68 211.27 38?.95 32.81 0.06 R 186.18 10.22 46.43 284,78 191,27 9.78 46.73 296.06 196.29 9.57 45,26 307,00 201,14 9.00 47,27 317.63 20~.57 9.05 47.51 327.76 210.I6 10.43 48.85 338.60 214.45 10,30 50.24 349,29 219.47 9.67 43.80 360.65 224,83 %32 46.28 371,74 229.99 10.12 46.21 383.26 223.40 '405,66 235,94 421,51 246,18 437.79 259,47 453.50 271.29 469.56 33,42 1.45 34.04 0,31 34,53 1,33 34,90 0,5'5 35,29 0,82 ECEIVED SURVEY CALCtJI, ATIONS ..,,,.,,~ =-.~-16 (Pi'l) I~REO 1HTERYAL UERTICAL ft ft ft 38~.43 ?4.2 3851.89 3995,86 96,4 3946.96 4071,25 95,4 4041.01 4187,60 96,4 4135,98 4279.74 92,1 4226,85 TARGET ' STATION AZI~LrfH LA?ITUI)£ - 9ECTION IHCLN, ft dm] deg. ft 234,91 9,76 47,82 3?4,34 23B,92 9,47 52,62 404,64 243.00 9,79 47,02 414,93 248,54 9,62 42,25 426,48 254,33 9,54 42,62 437,80 DFARllRS DIS~LA~J~B~T at ~lI~t~H fi: fi: deg 283,18 485,48 35,6B 255,53 50h07 36,14 307,70 516,b'7 36,56 319,10 532,64 36,81 329,45 547,91 36,96 d~/ lOOft 0,48 0,88 1,04 0,85 0,11 4375,28 4559,&5 4~55,27 4750,88 4845,72 95,5 4320,97 184,6 4502,67 95,4 4596,56 95,6 4690,62 94,8 4783,92 260,03 10,16 45,70 449,5! 269.97 10,13 47.93 471,75 274,52 10,35 50,18 482,86 279.12 10,30 47,91 494,09 282,80 10,44 56,31 504,54 340,85 564,12 37.17 354,55 -596,I9 37,69 377,35 612,83 38.01 390,29 629,65 38,31 403.73 646,19 38.67 0,85 0,21 0,48 0,43 1.60 4940,02 5035,14 5131,14 5227.53 53~1,10 ?4,3 4876,73 95,1 4970,38 96+0 5064,80 96,4 5159,54 93,6 5251,61 285.21 9,92 56,26 513,79 287,68 10,25 55,96 523,08 2B?,86 10,59 58,79 532,44 2?2.63 10.67 52,50 542,46 296,87 9.82 46.98 553,18 417,60 662,10 39,10 0,55 431,43' 678,05 3?,52 0,35 446,06 694,59 39,96 0,64 460,72 711,71 40,34 1,21 473,43 728,11 40,56 1,39 5416,46 5511.08 5604.66 5702,I2 5796.54 ~5,4 5345,54 94,6 5438,72 93,6 5530,88 97.5 5626,88 94,4 5'719,96 301,53 10.11 49.39 564.18 30~.54 9,87 44,22 575,39 312.22 10,16 44,17 587,06 317.62 9.66 47.5'5 598.74 322,25 9,72 47,87 609,44 485,73 744,4.6 40,73 0,53 497,68 760,77 40,86 0,98 5(Y'/,03- ' 777,01 40,~ 0,31 521,05 793,72 41,03 0,78 532,81 80%51 41,16 0,08 58~2,20 5989.22 6086.09 6179,84 6275.58 95,7 5814,28 97,0 59O9,90 96,9 6OO5,25 93,8 6097,56 95,7 6191,90 327.03 9,~0 4~,50 620,29 332,12 9,99 46.58 631,58 337.I8 10.37 48,31 &43+16 342.35 9,76 43,97 654,49 346,48' 9,83 41.04 6~,49 544,52 825,39 41,28 556.44 841.74 41.38 569,05 858,76 41,50 58O.87 875,08 41,59 591,87 891,36 41.61 0,33 0,50 0,50 1,04 0,53 6369.82 6465.94 6562,25 6656.86 6754,14 94,2 6284.70 96.1 6379,24 96,3 6473.79 94.6 6566,54 97,3 6661,64 355.05 10.21 40,'~ 678,87 362,08 I0.58 40.51 692,01 370.90 11,3~ 31,37 706.85 383,24 I1,~ 15,04 723.99 400.00 12,78 4,35 744,12 602,63 907,76 41,60 613,94 925,10 41.58 624,63 943,30 41,47 631.96 961,00 41,12 635.30 978,43 40.49 0,40 0,39 1,99 3,43 2.63 6850.58 6945,00 7139.52 7232.07 %.4 6755.35 94,4 684~,35 95.6 6'K37.72 98.? 7031.31 ~.6 7118,19 420.17 14.57 0.51 766.89 443.30 16,38 355,47 792,04 470,18 17,99 349.62 820,02 501.49 19,71 341,46 850,85 533,27 20./.3 337+48 880,71 636,22 996,44 39,68 2,08 635,27 1015.33 38,73 2,3? 631,54 1035,02 37.60 2,47 623.49 1054,84 36,23 3,18 612.28 1072,~ 34.81 1.78 7326,90 7423.56 7520,63 7615.40 7711,24 94,8 720~,85 %,7 7297,07 97,1 7387,40 94,8 7475,24 95,8 7563,81 566.88 20.94 336,65 911,69 599,17 i(770.96 601,56 21.12 335,29 943.37 585,05 1110,06 &37,09 21,83 336,06 975,76 5'70,41 1130,25 672.66 22.26 335.38 1008.18 555,78 1151,22 70~.26 22,65 335,68 1041,50 540,62 1173.45 R 33.31 0,45 31,81 0,54 30,31 0,79 28,87 0,53 D 4 I~~ INTt~UAL UI~ICAL ft ft ft 7807,68 96,4 7652,70 7903.70 ?6.0 7740.05 7998,32 94,6 7827.45 8094.13 95.8 7915.17 8191,35 97,2 8004.19 8285,97 8300,66 8474,05 8570,44 8856,13 8761,66 8~56.24 8959,56 9056.64 9150,72 ?245,95 933?.30 9435,13 952?,89 9626,~ 9721,?? 9~18.13 ~719,00 10013.35 10110,33 10206.89 10295.50 T~ STATION AZD~OTH ft deg deg 746.65 23,01 337.58 784.6B 23.70 335.66 822.83 23,85 333,75 94.6 8090.76 936.47 23.76 330.41 94.7 8177,33 976.75 24.06 330,65 94.2 8263.14 1015.46 24.61 330.31 95.6 8350.02 1055.24 24,71 331,Li 95,7 8436,~ 1095.19 24,74 330,86 95,5 8523.67 1135,I2 24,80 330,t9 94+6 8509.50 1174,74 24.&9 330.2S 103.3 8703,14 1218.2~ 2S.12 330,36 97.1 8791,57 12.58,23 23.63 329.93 94,1 8878,27 1294,70 22,08 333,19 95.2 8967.01 1229,19 20.42 232.81 93,3 ~054.84 1260.81 19,18 222,22 95.8 9145,66 1391,38 18,04 333,85 94,8 9235,83 1420.54 17.80 336,04 96.8 9328.04 1449.91 17.57 228.65 95.3 9416.85 1478,76 17.78 339.57 96.1 9510,27 1506,07 17.91 341.31 I00.9 9606.10 1539.62 18.80 341,20 94.4 9694.95 1571.18 20.51 240.08 97,0 9785.74 1605.11 20,67 340.61 ?6.6 9876.04 88,6 ~58,82 LATITUDE O~ARTU~DI~C~at AZIMUTH DLS N/-S E/-~ deg/ ft ft ft deg lOOft 1075,84 ~2S.78 1197.45 26.05 0,85 1110,77 510,67 1222,54 24,69 1,07 1145,26 494,37 1247.40 22.25 0,82 1179.58 476,91 1272,34 22,01 0,68 1214,02 458.43- 1297.69 20.69 0.53 1247,36 439.82 1322,65 19,42 0,39 1280,79 420.94 1348,19 18.19 0,33 1314,56 401,82 1374,60 17.00 0.60 1349,34 382,31 1402,45 15,82 0,36 128&.34 362,?0 1431,12 14,69 0;I1 1419,20 343.21 1460.10 13,59 1453,71 223,50 1489,26 12.55 1491,~ 301,?0 1521,~ 11,44 1526.40 281.96 1552.22 10.47 1558,50 264,53 1560,79 9,63 - 1589.25 248,87 1608,62 8,90 1617,44 234.54 1634,36 8.25 1644,83 220.93 .. '1659,60 7,65 1671,24 208,56 1684,2.1 7,11 1698,37 197.25 1709.79 6,62 1725,41 166.94 1735.51 6,18 1753.18 i77.08 1762,10 5,77 1783,25 166.87 1791,04 5,3~ 1813,19 I56.34 1819.9I 4,93 1845,20 144,~ 1850.98 4.49 1639.18 20.81 228.21 1877.30 1670.74 21.00 227,60 1906,60 I32.84 1882.00 4,05 120.95 1910,43 3,63 0,31 0,11 0.22 1,55 2,13 1,75 1.34 1.21 0.75 0,85 0.37 0,57 0.88 1.85 0,25 0.89 O,['-r3 RECEIVED r, AAY 2 I 1996 Alaska Oil & ~a~ Cons, Commission Anchorago LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 19 October 1995 Transmittal of Data ECC #: 6502.00 Sent by: HAND CARRY Data: OH-LDWG ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP ' 1-03/P-16 PH (~MPI) ENDICOTT Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B stre~t Suite 201 Anchorage, AK 9~5~'8 , ov Received b / _~~/ LARRY GRANT Attn. ALASKA OIL + GAS .CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 November 1995 Transmittal of Data Sent by: HAND CARRY .. Dear Sir/Madam, Enclosed, please find the da~a as described below: W~LL ~ DESCRIPTION 1-03/P-!6 PH (MP~)~ 1 SBT/GR FINAL BL+RF Run ~ 1 Run ~ 1 Run # 1 ECC No. 5722.01 6502.02 Please sign and return to: Attn. Rodney D. Pau!son Atlas Wireline Services ' 5600 B Street Suite 201 Anchorage, AK 99518 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. .; Date: 18 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL~ BL+RF' Run 3- 1 1 GR/CCL FINAL BL+RF Run # 1 1 PFC/PERF FINAL BL+RF Run # 1 1-03/P-16 PH (MPI) 1 FMT/GR FINAL BL+RF Run ,~ 1 ECC No. 5985.14 6446.06 6502.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 ~. Anchorage, AK 99518 Received b~ - ' Date LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 October 1995 Transmittal of Data ECC #: 6502.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: £ 1-03/P-16 PH (MPI) % ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 DIFL/GR FINAL BL+RF Run # 1 1 ZDL/CN/GR FINL BL+RF Run # 1 1 BH PRO FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Anchorage, AK 99518 MEMORANDUM TO: Chairmaff' State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 3, 1995 THRU: Blair Wondzell, ~ FILE NO: P. !. Supervisor ~/q(*~- AKHLJCCD.doc FROM: John Spaulding//~-~ SUBJECT: Petroleum lnsp? BOPE Test Doyon 15 BPX Endicott 1-03/P-16 Duck Island Unit PTD 95-150 Tuesday October 3,1995: I witnessed the BOPE Test at BPX, Endicott, Main Production Island on Doyon rig 15. The AOGCC test report is attached for reference. I found the rig to be quite clean and in very good working order, with good access routes. The test went quite well with no failures observed. I observed one minor leak in the on the accumulator valve handles and brought this to the attention of Tool pusher John Welch. This leak does not affect the operation of the accumulator and will be repaired during the next rig move. Summary'.. I witnessed the successful BOPE test on Doyon rig 15, no failures, 4 hour test time. Attachments' AKHLJCCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 10 3/4" Test: Initial X Workover: DATE: 10/3/95 Doyon Rig No. 15 PTD # 95-150 Rig Ph.# 659-6510 BPX Rep.: E. Vaughn 1-03/P-16 Rig Rep.: J. Welch Set @ 4413' Location: Sec. 36 T. 12N R. 'I6E Meridian Umiat Weekly Other TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves 1 Check Valve NA Well Sign yes Drl. Rig ok Hazard Sec. yes Test Press. P/F 300/3,000 I 500/5,000 I 500/5,000 1 500/5,000 '1 500/5,000 2 500/5,000 500/5,000 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 500/5,000 P 500/5,000 P 5OO/5,0OO P 500/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/5,000 P 42 500/5,000 P 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2650 avg. 3,075 ] P 1,250 P minutes 45 sec. minutes 49 sec. Remote: Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. Notif7 the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: System pressure was somewhat slow and the valves on the accumulator were found to be leaking slightly and will be repaired on the next rig move. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AKH LJCCD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 21, 1995 Adrian Clark, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit 1-03/P-16 BP Exploration (Alaska), Inc. Permit No 95-150 Surf Loc 3343'NSL, 2032'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc 352'NSL, 2420'WEL, Sec. 25, T12N, R16E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. David V~/. Johnston Chairma'~.~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ofwork Drill[] RedrillF~llb. Type ofweli. ExploratoryF-1 Stratigraphic Test[-1 DevelopmentOil~l Re-Entry [] DeepenI-Ii Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3343' NSL, 2032' WEL, SEC 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 5198' NSL, 1766' WEL, SEC 36, T12N, R16E 1-03/P-16 2S100302630-277 At total depth 9. Approximate spud date Amount 352' NSL, 2420' WEL, SEC 25, T12N, R16E 09/23/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 312828 2420 feet 10' 1-01/J-19 at7.5'MD feet 2560 11490'MD/10126'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 900 feet Maximum hole angle 90 o Maximum surface 4200 psig At total depth (TVD) 10076'/5237 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 90' Surface Surface 90' 90' Drive 13.5" 10. 75" 45.5 L-80 BTC 4480' O' O' 4480' 4386' 784 sx PF 'E', 461 sx 'G', 150 sx PF 'E' 9.875" 7.625" 29.7 USS-95 Butt 10700' O' O' 10700' 10126' 5475X 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 Structural Conductor .... Surface R. ~ .,, L. ! Eb Intermediate Production SEP 1 4 1995 . Liner Perforation depth: measured AI~ tJll & Gas Coils. C0rrl~issi0.rl true vertical ~,'lch0rag8 20. Attachments Fi~ng fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prograr~/E1 ~[me vs depth plot [] Refraction analysis[] Seabed reportl-'-I 20 AAC 25.050 requirementsl-I 21. I hereby ce~j~f'~t../t'fi,~/?oregoingfis true and correct to the best of my knowledge Signed ~'~\/("~;~-'~--~~L Titl"?~eni°rDrillingEngineer ~:z:~c/h~'~ / C -- Commission ~J~se Only ~ / Permit Number APl number_, ApprovaLda. te See cover letter ~',~.-./,/~,~'"'~::~ 50-O...~ ~ -.2.-.2.. GO ,,/ ~' -.',,:~ / -" ~..~f for other requirements Conditions'of approval Samples required [] Yes J~ No Mud log required []Yes ~ No Hydrogen sulfide measures J~ Yes [] No Directional survey requ~rea ,~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; ,~5M; I-I10M; I-I15M; Other: Original Signed By by order of / ,-_Appr°ved~A ,A~bY _ ..... David W. Johnston Commissioner me commission Date ~ Form 10-401 Rev. 12-1-85 Submit Pilot Hole Abandonment Plug Well 1-03/P- 16 RIH to TD of pilot hole 10,800 MD. with open ended DP. Circulate. RU Halliburton. In sequential stages lay 160 bbl of balanced plugs across the reservoir. Volume based on bringing cement top 300' above reservoir and 30% excess over gauge hole. G Cement +.2%Halad 344+.2% CFR-2 15.8 ppg 1.15 Yield TT 3 Hours POH to 7300' leaving mud of drilling weight or greater between plugs. Spot 50 bbl high vis pill of weight equal to or greater than mud weight..POH to 6800 circulate and lay cement plugs kick off plug.. ~' RU Halliburton. Lay 56 bbl balanced plug. Volume based on placing cement to 275' above KOP of(6675') + 50% excess G Cement .6% CFR-3,.25% LAP 17 ppg .99 Yield TT 2:45 hours POH Wait on cement a minimum of 12 hours. / I Well Name: I 1-03/P-16 Well Plan Summary I Type of Well (producer or injector): ] Producer Surface Location: 3343 FSL 2032 FEL S36 T12N R16E UM Target Location: 5198FSL 1766 FEL S36 T12N R16E UM Bottom Hole Location: 352 FSL 2420 FEL S25 T12N R 16E UM AFE Number: ] 727101 I Estimated Start Date: ] 9-23-95 IMD: I 11490 [ I Rig: I DOYON 15 Operating days to complete: I 32 TM I I~cuE: 156 Well Design (conventional, slimhole, e,tc.): [ SLIMHOLE Formation Markers Horizontal Well Bore: Formation Tops MD TVD (BKB) UPPER SV SHALE 3400 3366 BASE UPPER SV 3724 3686 TOP SV MARINE 4175 4131 SHALE BASE SV 4312 4266 MARLINE SHALE / SV-5 4312 4266 BASE SV-5 , 4581 4531 TOP UGNU 5772 5706 TOP WEST SAK 6801 6721 TOP 7776 7671 SEABEE/AYLYAK TOP SHALE 8931 8796 WALL/TUFFS HRZ 9501 9351 BASE HRZ 9786 9626 PUT RIVER Absent Absent LCU 9786 9626 KEKIKTUK 3C 9786 9626 5225 psi 3B 9894 9724 5237 psi. 3A 10056 9859 4720 psi. 2B 10432 10076 4600 psi 2A 4285 psi Well Plan Summary Page 1 Casin /Tubin ProSram: 'Hole Size'- Csg/ '~Wt/Ft"- Grade Conn Length Top Btm Tbg O.D. MDfFVD MDflWD 13.5 10.75 45.5 L-80 BTC 4480 0 4480/4386 9.875 7.625 29.7 USS-95 Butt 10700 0 10700/10126 6.75 - 4.5 12.6 L-80 1000 10500/10098 11490/10126 Logging Program: Open Hole Logs: DIL/MSFL/LDT/CNL~GR FMT 10-15 points Horizontal Hole MWD,GR Cased Hole Logs: SBT/Gyro Mud Program: ] Special design considerations ] Surface Mud Properties: I SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 300 40-60 30-60 60-80 8.5-9.5 none- 10 to to to to to to to 9.5 100 20-40 15-20 20-30 8.5-9.5 none-10 Intermediate Mud Properties: Subject to change based on pilot hole drilling results. Density Marsh Yield 10 sec 10 min pH Fluid (PPG) .Viscosity PoiI~,t gel gel Loss 9.2-10.8 50-6- 20-30 12-15 25-30 9.5-10.0 <6 to to to to to to to Production Mud Properties: Subject to change based onPilot hole drilling results I Density Marsh Yield 10 sec 10 min LSRV Fluid (PPG) Viscosity Point gel gel cps Loss 9.2 NA 40-45 18-23 24-29 + 50,000 +6 to to to to to to to Clorided mg/liter _+ 40,000 K:N ratio >1 Well Control: Well. Plan Summary Page 2 Well'control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: ]900 I Maximum Hole Angle: 1 45 in pilot hole and 90.0 in I-Ii~h an~le hole Close Approach Well: I 1-01/J-19 The above listed wells will be secured during the close approach. Deep well intersections NONE. EP 1 1995 Gas Cons. Commission Anchorage Well Plan Summary Page 3 1-03/P-16 Hazards Pressure: Abnormal pressures in the 3C/3B may be encountered due to gas injection approximately 1000' downdip of the target location at well 2-12/Q-16. Estimated sandface pressure based on average 1995 injection pressure is 5237 psi. Gas: The moved GOC is expected in the 3A.' Faults: Niakuk 300' north 300' throw Unnamed* 200' south 30' throw * this fault will be intersected in the Horizontal Build Section no problems are anticipated most likely fault to be a sand on sand interface and be invisible to drilling. Geologic Notes Horizontal section will be drilled along strike of steeply dipping block adjacent to Niakuk Fault HAW target depth has 100' TVD standoff from GOC and 45' TVD standoff from OWC ( GOO standoff more critical) 1-03/P-16 CEMENT PROGRAM- HALLIBURTON 10-3/4" SURFACE CASING .CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 784 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 461 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Pe~.rmafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100. bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Lead slurry w/30% excess over gauge hole. 2. Tail slurry to 3400 w/30% excess over guag~ hole. 3400 'MD = top of SV shale 2. Top job volume.,~50 sx. ~ 9-7/8 Pilot Hole Abandonment CEMENT TYPE: Premium ADDITIVES: .2% Halad 344,.2% CFR-2 WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. SACKS: 780 THICKENING TIME: 3hrs CEMENT VOLUME Volume based on placing cement to 300' above the top of the Kekektuk with 30% excess. MIX WATER: 5.00 gps 9-7/8" Kick Off Plug CEMENT TYPE: Premium ADDITIVES: .6% CFR-3,.25% LAP WEIGHT: 17ppg YIELD: .99ft3/sx APPROX. SACKS: 317 THICKENING TIME: 2:45hfs CEMENT VOLUME Volume based on placing cement 275' above kickoff point of 6675' with 50% excess. MIX WATER: 3.6gps 1-03/P-16 CEMENT PROGRAM- HALLIBURTON 7 5/8" PRODUCTION CASING. CASING SIZE: 7 -5/8", 29.7# CIRC. TEMP 135°F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 547 PUMP TIME: 4 hfs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Displace... at 14 bpm with rig pumps. CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 9786. SEP 14 1995 Gas Cons. Commission Anchorage Request for Annular Injection Well 1-03/P-16 will be drilled in accordance with the attached Permit to drill. The following criteria for annular injection have been met. 1)The Surface casing will be set 4386 TVD BKB which is below the required SV shale 3,200'-3,500' TVD. 2) A determination has been made the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 3) Pumping into hydrocarbon reservoir will not occur. 1-03/P-16 OPERATIONS SUMMARY: Dig out cellar, Weld on landing ring. Ensure landing ring is the proper height with Endicott Field personnel install diverter. MIRU Doyon 15. Hold pre spud meeting with crew. 1. Test diverter. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadrill & Gyrodata to insure they are following JORPS. Drill hole to 4386' TVD. 2. Run 10-3/4" 45.5 ppf surface casing 3. Cement surface casing. 4. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. 5. ND diverter. NU Bop's & test. 6. Drill out shoe and perfohn LOT. 7. Directionally drill pilot hole to 10,45 I'TD. Well site geologist will help pick final TD (175' below lower most possible perforation in 2Al 10120' tads)..Have sample catchers and well site geologist on site before drilling the Kekiktuk. 9. Use ke~ seat wiper for Tuffs and HR- 10. RU E/Line & mn open hole logs ("Triple Combo" ).+ FMT..Z. 11. Plug/back the pilot hole to 6500' MD. 12. DireCtionally drill intermediate hole to 10,126 TVD. Well site geologist will help pick final target TVD based on pilot hole results. 13. Run 7-5/8" production casing and cement. 14. Run bond logs on'wire as deep as possible. 15. PU 6-3/4 "BHA and drill 10' outside 7-5/8" casing. Change over mud system to Xanvis. Directionally drill horizontal section to 11490'. 16 .Make hole opener run with 7-5/8" casing scraper spaced out to the packer setting depth approximately 10,300'. 17. Run 4-1/2" L-80 slotted/solid finer with finer top packer at 10,300'. Release from the packer and displace Xanvis mud to filtered seawater. Spot lithium hypochloride breaker across the finer.. 18. Run 4-1/2" 13CR-80 completion with SBR and locate onto slick stick on the SS packer. 19. ND Bop's. NU and test 4-1/16" 5M# tree. Test packer. [~:i. .. ~ ~ ~ ~ i~ 20. Freeze protect tubing.. S F.? ~ 4 1995 Alaska oil & Gas Cons. Commission Anchorage 21. RD MO Rig. 14:21 Anadr-~Cl DPC 907 3".4 2160 P.05 -. SHARED 'SERVICES DRILLING -I '-:7't *t "' ' 1-03/P-16 tPGJ PILOT HOLE I . F- - !.~,--j't,, I,., ~ -.., -_ VERTICAL SECTION VIEW " ~1 Section at: 335.'79 f ~li~ _ . '- TVD Scale.' 1. inch : ~200 feet ~1 '1 )__. ~J-t' I ' - Dep' Scale."~ inch :.~200 feet. '~ +l ~-i ~ Drawn.. ' 09/07/95 III ..... _, ..... .~ ~' . ,~ . 1__ Markee Identification MD ~8 SECIN INCLN ; -.~,,,,, . A) ~ 0 0 0 0.00 .. ' '- B) ~GE BUILD }.5/~ 300 300 0 0.00 - j)mm I C)-END 1.5/~00 BUILD . 900 898 45 9.~ )-- ~ ~1 I 1 D) K~ CURVE 2.5/~ gO0 BgB- 45 g.~ El END 2.5/~00 CURVE 1395 . 13BB 97 9.4~ ~ ...... = ............... T~%~-~ ~'-~$ F) C~VE 2.5/t00 ~78-. 6600 450 9.41 )_ ~ I-! F / G)' ENO 2.5/~00 CURVE 7524 74S7 60S 22.76 ':~ L.. m H) TARGET - PILOT H~E I04~3 10081 17lB 22.76 ~ .I - .... :.t .... ~a~, .............. ~.,.J.;-. '.'.'1 '- ~1 ' ' I: ,. .~ .... ~ ' .- ...... . I ~.' ..... ]- ~ ; . -- g ',~ .... ~ ~, ~.~ .... - ,, ~, ~'~l~ .... f(P ~f ~, I~ ' · I ~' / ~lm &)~ ..... -' . ~-- "'.'m::. ''i ~ ' ~ _~_ ~ ~ .... ~ ~ , '-, - ' ....... I' --- -I ..... :l ~ ,~-i-- ,~ .... I 1 '*~"'~"~*"~'-' ~ "::: :: :: :::::: :: :::: :~:: :'""~b "' j F ~-~ ~ "" ,--- . ........................ , . ~:~ ~ ........... = _ _ .. ~I IIIII I I I~l I I I, IIIII I I II I~I I ~ II I I ........ ~.- ............... . ............. - __- ...... h . ,, -I .... . O 600 ~200 ~800 ~400 3000 '3600 4~00 4800 5400 6000 6600 7200 7800 Section Depa~tune 14:23 Anadr~l DPC 907 ~¢4 2160 SHARED SERVI'CES Marker Identif ica[ion MD N/S A) KB 0 0 O) NUDGE BUILD 1.5/100 300 -- 0 C) END t.5/100 BUILD 900 36 O) KOP CURVE 2.5/100 900 36 E) END 2.5/t00 CURVE t395 95 F) CURVE 2.5/:~00 6678 7tO GJ END 2.5/t00 CURVE 7524 9i! H) TARGET - PILOT HOLE 10413 1930 I) TD IOBJ5 2072 E/W 30 30 27 580 561 39 DRILLING 1-03/P-16 (P6) PILOT HOLE PLAN VIEW.' _ CLOSURE · 2072 feet aL AZimuth ~.09 DECLINATION · +2g.707 (E) SCALE ....... :- J inch = 400 feet. DRAWN ....... :09/07/95 ~400 12OO :~000 800 (lnadrill [C) 95 Pl~ 2.5b.0i t~: 14 Pi4 pJ 600 400 200 0 200 <- WEST' EAST -> 400 600 800 JO00 i200 14:30 Anadr~-~l DPC 907 ~44 2160 P.13 · I i i 'SHARED SERVT_'i:I 'S DR.ILLING i 1-03/P-16 (PC)' HA SECTION VERTICAL.SECTION VIEW · . ii i Section at: 303.57- TVD Scale · ! inch : 500 feet Dep Scale' ! inch: 500 feet Drawn .... · 09/07/95 i i i i i Marker Zdentification ND &KB SECTN - INCLN A) TIE-iN CURVE 2.5/100. §67B 6600 -9] 9.4t B) .ENO ~,5/t~ ~RVE .69~ ~ -86 33.~4 C} .~VE 8/t00. 96~6 9473 90 13,14 -Ol E~ 8/100. C~VE ~0704 10~26 8~ ~,~ E) TARGET (~L) 10704 lOI~ 805 ~.~ F). TB (ESL) 15490 10~26 $590. ~,00 -5OO -250 0 25O Uma~rill [c)~ P~r~P6~JAw 2.5~.0~ 1~57 ~ p) 5O0 750 JO00 ~1250 1500 1750 2000 2250 2500 2750 3000 Sect ion Dep,arture __ __ 14:28 Anadr~-~l DPC p.1°2 907 344 2160 SHARED 'ERVICES DRZLLING ...... ii i i . 1-03/P-16 (P6) HA SECTION VERTICAL SECTION VIEW Section at: 303.57 TVD Scate' I inch : 1200 feet Oep. Scale.' ! inch-- 1200 feet Drawn. '' 09/07/95 Marker Ioentification ND BKB SECTN INCLN 'A) TIE-IN CURVE 2.5/1~ 6678 6600 - B) END 2.§/100 CURVE 6938 ~55 C) C~ 8/100 9626 9473 O) E~ 8/100 C~VE ~0704 10~ 805 90.00 E) TA~ET [BSL) t0704 10]~ 805 gO.O0 F) lO (E~) 11~90 lOl~ 1590 90.00 0 600 1,200 1800 2400 3000 3600 4200 4800 5,400 6000 6600 7200 7800 _ Sect ion Departure (Anad~i)) [c)95 P]6P6HAt~ 2.5a.0! ]2:57 PI~ P] -- , WELL PERMIT CHECKLIST WELL NAM~ GEOL AREA PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION 1. Permit fee attached .................. ~ Y 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. I.Y 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. I .Y 10. Operator has appropriate bond in force ......... I .Y !1. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING Choke manifold complies w/API RP-53 (May 84) ...... ~ Work will occur without operation shutdown ....... ~ N Is presenoe of ~2S gas probable ............ ~ N 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N ~ ~ .~ 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~.Y 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate ..................... N 26. BOPE press rating adequate; test to ~5~) psig.~ N 27. 28. 29. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis gf shallow gas zones .......... 33. Seabed condition survey (if off-shor~) ........ ~/~ N 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: 'COMMISSION ~...-- C~mments/Instruotions: · '"'~"~heklist rev 03/94 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. * ALASKA COMPUTING CENTER * ....... SCHLUFIBERGER COMPANY N;~IE : B.P. EXPLORATION WELL NAME : MPI 1-03/P-16 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE BOROUGH STATE : ALASKA API .VUMBER : 50-029-22601-00 REFERENCE NO : 97017 LIS Tape Ve__fication Listing Schlumberger Alaska Computing Center 13-JAN-1997 15:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/01/13 ORIGIN : FLIC REEL NAldE : 97017 CONTINUATION # : PREVIOUS REEL : CO[6VE41~f : B.P. EXPLORATION, ENDICOTT MPI 1-03/P-16, API #50-029-22601-00 **** TAPE HEADER **** SERVICE NAME : ~DIT DATE : 97/01/13 ORIGIN : FLiC TAPE NAME : 97017 CONTINUATION # : 1 PREVIOUS TAPE : CO~.'.¥T : B.P. EXPLORATION, ENDICOTT MPI 1-03/P-16, API #50-029-22601-00 TAPE HEADER ENDICOTT MWD LOGS rWELL NA24E : A~I NL~IBEP. : OPERATOR: LOGGING COMPA~IY: TAPE C.~EATION DATE: JOB DATA JOB ATU~.!BER : LOGGING ~NGIiVEER : OPERATOR WITNESS: SO'FACE LOCATION SECTION: TOWNSHIP: P~NGE: FSL: FEL: ~gL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRIC~ FLOOR: GROUND LEVEL: BIT RUN 1 97017 K~I~P WELL CASING RECORD i ST STRING 2ND STRING MPI !-03/P-16 500292260100 BP EXPLORATION SCHLUMBERGER WELL SERVICES i3-JAN-97 BIT RUN 2 BIT RUN 3 36 12N ! 6E 56. O0 56. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SiZE (IN) DEPTH. (FT) 6. 750 7. 625 10620.0 LIS Tape Ve_ _~ication Listing Schlumberger Alaska Commuting Center !3-JAN-1997 15:12 3RD STRING PRODUCTION STRING MERGED ~Pz~D AND SLIM1 GR DATA. NO DEPTH SHIFTS APPLIED AS PER BOB ~ETZGER. $ $ PAGE: **** FILE :HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O0!COI DATE : 97/01/13 MAX REC SIZE : 1024 FiLE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED ~fERGED Depth shifted and clipped curves; all bi~ runs merged. DEPTH INCR~-~ENT: O. 5000 FILE SO?/~,£~Y LDWG TOOL CODE START DEPTH STOP DEPTH SL~'~ 8872.0 10402.5 $ BASELINE CURVE FOR SHIFTS: NONE CG~VE SHIFT DATA (MEASL?,ED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE SLWD SL~ $ R~,ID~R, KS : ~'~ERGED ~ffWD AND SLIM1 GR DATA. NO DEPTH SHIFTS WERE DONE AS PER BOB ;~ETZGER. INTERPOLATED GR PROCESSED AT AK iCS ON 13-JAN-97. $ .......... EQUIVAL~.,%~f UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE ! 8872.0 10933.0 2 10933.0 11402.5 LiS FORMAT DATA LIS Tape Ye~ _ication Listing Schlumberger Alaska Computing Center 13-JA~I-1997 15:~2 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT Il 66 85 12 68 13 66 14 65 FT 15 66 68 16 66 ! 0 66 0 ** SET TYPE - CH~V ** NA~ SERV ~IT SERVICE API API API API FILE ~KIMB ~VO~iB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD _NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRRW [~WD AAPI O0 000 O0 0 i I 1 4 68 0000000000 GRIN f~WD AAPI O0 000 O0 0 ! 1 I 4 68 0000000000 ** DATA ** DEPT. 11402. 500 GRRW. MWD -999. 250 GRIN.MWD -999. 250 DEPT. i0000.000 GP~W.f~WD -999.250 GRIN.f~VD 24.250 DEPT. 8872.000 G~W.~,~ -999.250 GRIN.z~WD -999.250 ** END OF DATA ** LIS Tape Ve_ _ication Listing Schlumberger Alaska Computing Center i3-JAIV-1997 15::2 PAGE: **** FILE TRAILER **** FILE N~E : EDIT . 001 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/01/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * FILE HEADER * * * * FILE NAME - EDIT .002 SERVICE · FLiC VERSION · 001 CO! DATE · 97/01/13 f~AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW i~WD Curves and log header da¢a for each bit run in separate files. BIT RUN NL~BER: ! DEPTH INCR2~M~¥T: O. 5000 FILE SUMPiARY VE~OR TOOL CODE START DEPTH STOP DEPTH SLWD 8872.0 10933.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFI?IARE VERSION: DOWArHOLE SOF_~WARE VERSION: DATA TYPE (F~2~ORY or Pj~ar.-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG I_~rTERV;r, (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINI~_~JM .~VGLE : MAXI£4IX~ .ANGLE: TOOL STRING (TOP TO BOTTOM) VE=~OR TOOL CODE TOOL TYPE $ BOREH. OLE ~AND CASING DATA 02-NOV-95 REAL - TIME 11450.0 8872.0 11402.5 TOOL ND?~BER LIS Tape Vt_ _ication Listing Schlumberger Alaska Computing Cenrer 13-JAN-1997 I5:~2 PAGE: OP~V HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: M~ID D~.,¥SITY (LB/G): MUD VISCOSIT"£ (S) : ~JD PH : MLrD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (Obff4M) AT TEMPERATURE (DEGF) : ~.FUD AT MEAS~TLED T~4PERATURE (MT): ~4IID AT ;~X CIRCULATIONG TEMPE~ATrJRE : MUD FILTRATE AT (MT): MUD ~E AT (MT): NEUTRON TOOL F~TRIX: MATRIX DENSIT"£ : HOLE CORRECTION (IN): TOOL STANDOFF (itl): ~,gR FREQUENCY (HZ): R~VARKS: $ ,, LIS FOX, fAT DATA 6.75O 10620.0 FLOPRO ** DATA FOPJ~AT SPECIFICATION RECORD ** ** SET 7"£PE - 64EB ** TYPE REPR CODE V~_LUE I 66 0 2 66 0 3 73 12 4 66 1 5 66 ¥ 73 7 65 8 68 0.5 9 65 FT !! 66 85 12 68 !3 66 0 14 65 FT 15 66 68 16 66 0 66 ! LIS Tape Ve_ _zication Listing Schlumberger Alaska Computing CenTer 13-JAN-1997 15:12 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~JMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 I 4 68 0000000000 GR RAW CPS O0 000 O0 0 2 1 1 4 68 0000000000 GR ~WD AAPI O0 000 O0 0 2 1 1 4 68 0000000000 ..................................................................................... ** DATA ** DEPT. 10933.000 GR..~W 12.000 GR.MWD 20.200 DEPT. 10000.000 GR.RAW 37.440 GR.MWD -999.250 DEPT. 8872. 000 GR. RAW - 999. 250 GR. MWD - 999. 250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O0iCOI DATE : 97/01/13 MASf REC SIZE : 1024 FILE I"£PE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 00i CO ! DATE : 97/01/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE .%UJ?4B ER 3 RAW ~K~D Curves and log header daCa for each bit run in separate files. BIT RUN ND?4BER: 2 DEPTH INCRa~AF2VT: O. 5000 FILE S~Y V~.~VDOR TOOL CODE ST;~T DEPTh' STOP DEPTH LIS Tape Ve__='ication Listing Schlumberger Alaska Computing Cen~er 13-JAN-1997 15:12 PAGE: SLWD 10933.0 $ LOG HEAD~..~ DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~EMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG I~rrERVAL (?T) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINI~JM ANGLE: MAXIMDW ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL 7"fPE $ BOREHOLE A~ID CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH. (FT) : BOREHOLE CONDITIONS MUD TYPE: ,~KID DENSITY (LB/G): MUD VISCOSITY (S) : £,KID PH : MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVIT"£ (O~ff~) AT TEMPERATOU~E {DEGF) : MUD AT ~_VEASURED 'T~¢PERATURE (MT): MUD AT MAX CIRCULATIONG TEMPEP~TO~E : f4IID FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSIT~f : HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ}: RE~a_RKS : $ LIS FOR~T DATA 11402.5 02-NOV-95 REAL- TIME 11450.0 8872.0 11402.5 91.1 · TOOL ~FuY,~BER 6. 750 10620.0 FLOPRO LIS Tape Ve~_=ication Listing Schlumberger Alaska Computing Center 13-JA~¥-1997 15:~2 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 ! 5 66 6 73 7 65 8 68 0.5 9 65 FT i! 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 ! 0 66 ! ** SET ~£PE - C.~¥ ** NAME SERV UNIT SERVICE APi API APi API FILE NLWB NUMB SIZE REPR PROCESS ID OR-DER # LOG ~fPE CLASS MOD ~FUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GR RAW CPS O0 000 O0 0 3 I 1 4 68 0000000000 GR ~TD AAPI O0 000 O0 0 3 i 1 4 68 0000000000 ** DATA ** DEPT. 11402.500 GR.RAW -999.250 GR.f~ -999.250 DEPT. 10933.500 GR.RAW -999.250 GR.~;D -999.250 ** E~ OF DATA ** LIS Tape Ve~_=ica~ion Listing Schlumuberger Alaska Computing Center 13-JAN-1997 15:~2 PAGE: **** FILE TRAILER FILE NAME : EDIT .003 SERVICE · FLIC V~SION · O01CO1 DATE : 97/01/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE N~E : EDIT DATE : 97/01/13 ORIGIN : FLIC TAPE NAME · 97017 CONTI~%~JATION # : 1 PREVIOUS TAPE : CONJ~VT · B.P. EXPLORATION, E~iCOTT MPI !-03/P-16, API #50-029-22601-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/01/13 ORIGIN : FLIC REEL NAME : 97017 CONTINUATION # : PREVIOUS REEL : CO~IT ~ B.P. EXPLORATION, ENDICOTT MPI 1-03/P-16, API #50-029-22601-00 1 - 03/P- 16 PH ENDICOTT Run 1: 13 - October - 1995 DIFL/GR ZDL/CNIGR .-.--_ 9720 10758 ~q/ESTERN i, ~_~ ~/~ .... ATLAS /Logging Services Tape Subfile 2 is' type': iS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6502.00 K. RICHARDS P. BARKER 1-03/P-16 PH 500292260180 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 18-0CT-95 RUN 2 RUN 3 36 12N 16E 3343 2032 56.00 54.00 15.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 10.750 PRODUCTION STRING 9.875 REMARKS: DIFL/GR & ZDL/CN/GR. CIRCULATION STOPPED AT 2000, 12-0CT-95 4456.0 10773.0 PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL GRZ SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH 9736.5 9740.0 9741.0 9741.5 9757.5 9758.5 9784.0 9784.5 9786.0 9787.0 9798.5 9804.0 9805.0 9807.0 9807.5 9815.5 9816.5 9819.5 9820.0 9822.5 9833.5 9847.5 9849.0 9852.5 9853.0 9864.5 9866.5 9867.5 9869.5 9872.0 9876.0 9881.5 9890.0 9892.0 9899.5 9900.5 9904.0 9905.5 9906.0 depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9727.0 10703.0 9782.0 10758.0 9720.0 10725.0 9750.0 10750.0 9785.0 10732.0 GR from Induction tool. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH LL8 ILD SP GRZ 9737.5 9741.0 9741.5 9742.5 9758.5 9759.0 9784.5 9785.5 9798.5 9798.5 9822.5 9822.5 9848.5 9848.5 9852.0 9852.0 9805.0 9805.5 9807.5 9808.5 9816.5 9817.0 9820.0 9821.0 9848.5 9853.5 9864.0 9866.0 9867.5 9869.0 9872.0 9876.0 9882.0 9890.5 9892.0 9899.5 9900.0 9904.5 9906.0 9906.0 all runs merged; RHOB 9758.5 9759.0 9786.0 9787.5 9799.5 9805.0 9805.5 9807.5 9808.5 9816.5 9817.0 9820.0 9821.0 9823.5 9833.5 9849.0 9853.5 9864.0 9866.0 9867.5 9869.0 9872.0 9876.0 9882.0 9890.5 9892.0 9899.5 9900.0 9904.5 9906.5 no case 9918.5 9919.5 9920.0 9920.5 9935.5 9937.0 9941.0 9942.5 9946.5 9950.0 9957.5 9963.5 9969.0 9974.0 9974.5 9978.5 9981.5 9982.0 9985.0 9986.0 9987.0 9993.0 9999.0 10004.5 10007.5 10010.5 10011.0 10012.0 10016.5 10018.0 10018.5 10020.0 10024.0 10025.0 10026.0 10026.5 10032.5 10037.0 10038.0 10041.5 10045.5 10049.0 10054.0 10056.5 10057.0 10057.5 10061.0 10063.5 10064.0 10064.5 10066.5 10070.0 10071.0 10071.5 10072.0 10074.5 10076.0 10079.0 10081.5 10086.0 9942.0 9946.5 9963.0 9974.0 9982.0 9993.5 10011.0 10019.5 10021.0 10027.0 10049.5 10054.5 10064.0 10079.5 9942.0 9946.0 9963.0 9969.0 9974.0 9978.5 9982.5 9993.5 10007.0 10011.0 10019.5 10021.0 10025.5 10049.5 10057.5 10064.0 10079.5 9950.5 9982.0 10018.0 10026.5 10038.5 10063.5 10066.5 10071.5 10081.5 J919.0 9919.5 9920.0 9921.0 9941.5 9958.0 9964.0 9975.0 9986.0 9986.5 9999.5 10006.0 10012.5 10013.0 10025.0 10026.5 10033.0 10037.5 10038.0 10041.5 10046.0 10058.0 10071.0 10071.5 10075.0 10077.0 10087.0 9919.0 9919.5 9920.0 9921.0 9935.0 9937.0 9942.5 9946.5 9963.5 9975.0 9981.5 9987.5 9993.0 9999.5 10006.0 10011.5 10018.0 10019.5 10022.0 10025.0 10033.0 10037.5 10038.0 10041.5 10046.0 10056.5 10061.0 10065.0 10071.0 10073.0 10075.0 10077.0 10079.0 10081.5 10087.0 10093.0 10095.5 10096.5 10097.5 10100.0 10102.0 10106.0 10109.0 10109.5 10114.5 10115.0 10118.0 10119.5 10120.0 10123.0 10125.0 10127.5 10137.0 10142.5 10144.0 10146.0 10146.5 10149.0 10149.5 10151.0 10151.5 10155.0 10156.5 10157.5 10161.0 10162.0 10164.0 10167.5 10168.0 10171.0 10171.5 10172.5 10176.0 10176.5 10177.0 10179.0 10180.0 10185.5 10186.0 10189.0 10191.5 10195.0 10196.5 10199.5 10200.0 10204.0 10208.0 10209.5 10213.0 10213.5 10218.5 10219.5 10223.0 10230.0 10096.5 10100.5 10107.0 10109.5 10114.5 10120.5 10123.5 10144.0 10145.5 10148.5 10151.0 10154.5 10161.5 10171.5 10176.5 10178.5 10186.5 10189.0 10218.0 10087.5 10096.5 10100.5 10107.0 10109.5 10115.0 10120.5 10123.5 10142.0 10145.5 10150.0 10151.5 10155.5 10158.0 10161.5 10167.0 10171.5 10176.5 10186.5 10189.0 10194.5 10199.5 10218.0 10086.5 10093.5 10110.0 10120.0 10146.5 10168.5 10172.5 10177.0 10185.5 10207.5 _~087.5 10097.0 10097.5 10102.5 10115.5 10119.0 10126.0 10128.0 10138.0 10152.0 10157.0 10161.5 10172.0 10172.5 10179.0 10180.5 10192.0 10198.0 10200.5 10204.5 10209.5 10213.0 10214.0 10220.0 10223.0 10230.0 10088.0 10094.0 10097.0 10097.5 10102.5 10116.0 10119.0 10126.0 10128.0 10138.0 10145.0 10146.5 10149.5 10152.0 10157.0 10161.5 10165.0 10168.5 10172.0 10172.5 10179.0 10180.5 10192.0 10198.0 10200.5 10204.5 10209.5 10213.0 10214.0 10220.0 10223.0 10230.0 10235.5 10240.5 10243.5 10244.0 10254.5 10257.5 10263.0 10267.5 10269.5 10272.0 10275.0 10277.0 10277.5 10280.5 10281.0 10288.0 10294.5 10302.5 10303.0 10307.5 10309.0 10315.0 10315.5 10320.0 10337.5 10340.5 10346.5 10351.0 10352.5 10355.0 10357.5 10364.0 10372.0 10372.5 10381.5 10382.0 10384.0 10384.5 10393.0 10396.5 10399.0 10405.5 10413.5 10429.0 10433.0 10433.5 10438.0 10451.0 10452.0 10459.0 10460.0 10473.5 10474.5 10482.0 10482.5 10488.5 10489.0 10489.5 10492.5 10499.5 10267.5 10281.5 10303.0 10307.0 10308.5 10320.0 10351.5 10353.5 10355.5 10358.0 10363.5 10382.0 10384.0 10392.0 10433.5 10489.0 10235.5 10267.5 10281.5 10303.0 10307.0 10308.5 10320.0 10351.5 10353.5 10355.5 10358.0 10363.5 10381.0 10384.5 10392.0 10412.5 10433.5 10473.5 10489.0 10258.0 10277.0 10302.5 10352.0 10383.5 10396.5 10489.5 10240.5 10244.0 10244.5 10255.0 10263.5 10271.5 10274.0 10276.0 10278.5 10281.0 10288.5 10295.5 10304.0 10307.5 10315.0 10316.0 10338.0 10340.5 10347.5 10351.0 10372.0 10373.0 10399.5 10406.5 10430.0 10433.5 10434.5 10438.5 10451.5 10452.0 10459.5 10460.0 10473.5 10482.5 10488.0 10492.5 10499.5 10240.5 10244.0 10244.5 10257.5 10263.5 10271.5 10274.0 10276.0 10278.5 10281.0 10288.5 10295.5 10304.0 10307.5 10315.0 10316.0 10338.0 10340.5 10347.5 10351.0 10358.0 10384.0 10399.5 10406.5 10430.0 10433.5 10434.5 10438.5 10451.5 10452.0 10459.5 10460.0 10473.5 10481.5 10488.0 10501.5 10502.0 10508.0 10509.5 10511.0 10511.5 10513.5 10516.0 10516.5 10521.5 10525.5 10534.0 10537.5 10538.0 10542.0 10553.0 10554.0 10561.5 10562.0 10566.5 10568.5 10572.5 10579.0 10582.5 10588.0 10595.0 10597.5 10599.0 10601.5 10602.0 10607.0 10610.5 10619.0 10620.0 10622.0 10626.5 10634.5 10635.5 10641.0 10651.5 10653.0 10664.5 10667.5 10672.5 10673.5 10674.5 10681.5 10689.5 10691.0 10692.5 10696.0 10696.5 10700.0 10705.5 10719.0 10722.0 10739.5 $ BASELINE DEPTH 9784.0 10502.5 10508.0 10509.5 10513.0 10532.5 10553.0 10562.0 10578.5 10581.5 10588.5 10595.0 10597.5 10602.0 10610.0 10625.5 10641.0 10668.0 10691.5 10696.5 NPHI 9784.5 10502.5 10508.0 10509.5 10513.0 10532.5 10553.0 10561.0 10578.5 10581.5 10588.5 10595.0 10598.0 10602.5 10610.0 10621.0 10624.5 10634.5 10641.0 10664.5 10668.0 10694.5 10700.0 10705.5 10722.0 10739.0 10525.5 10542.5 10562.5 10601.0 10606.5 10635.5 10668.5 10501.0 10510.5 10511.5 10515.5 10516.5 10521.5 10537.5 10538.5 10554.5 10567.0 10568.5 10619.0 10619.5 10651.0 10653.0 10672.5 10673.0 10674.0 10681.5 10691.5 10698.0 10501.0 10510.5 10511.5 10515.5 10516.5 10521.5 10533.5 10537.5 10538.5 10554.5 10567.0 10568.5 10572.0 10599.0 10619.0 10619.5 10651.0 10653.0 10672.5 10673.0 10674.0 10681.5 10691.5 10696.0 10718.5 9784.5 9804.0 9805.0 9807.0 9807.5 9815.5 9816.5 9819.5 9820.0 9822.5 9849.0 9852.5 9864.5 9866.5 9867.5 9869.5 9872.0 9876.0 9881.5 9890.0 9892.0 9899.5 9900.5 9906.0 9912.5 9918.5 9919.5 9920.0 9920.5 9935.5 9941.0 9957.5 9963.5 9974.5 9985.0 9986.0 9993.0 9999.0 10004.5 10010.0 10012.0 10024.0 10026.5 10032.5 10038.0 10045.5 10049.5 10053.5 10056.0 10063.5 10070.0 10072.0 10074.5 10076.0 10079.5 10082.0 10083.5 10086.0 10087.0 10096.5 ~ ~5.5 9805.0 9805.5 9807.5 9808.5 9816.5 9817.0 9820.0 9821.0 9823.5 9849.5 9853.5 9864.0 9866.0 9867.5 9869.0 9872.0 9876.0 9882.0 9890.5 9892.0 9899.5 9900.0 9905.5 9912.5 9919.0 9919.5 9920.0 9921.0 9936.0 9941.5 9958.0 9964.0 9975.0 9986.0 9986.5 9994.0 9999.5 10006.0 10011.0 10013.0 10025.0 10026.5 10033.0 10039.5 10046.0 10051.0 10054.0 10057.5 10063.5 10071.0 10073.0 10075.0 10077.0 10080.0 10082.0 10084.5 10087.0 10087.5 10097.0 10097. 10100. 10109. 10115. 10118. 10123. 10125. 10127. 10137. 10143. 10149. 10151. 10155. 10161. 10171. 10172. 10179. 10180. 10191. 10196. 10200. 10202. 10206. 10209. 10213. 10213. 10219. 10223. 10228. 10235. 10238. 10240. 10243. 10244. 10254. 10263. 10269. 10272. 10275. 10277. 10280. 10288. 10294. 10303. 10307. 10315. 10315. 10337. 10340. 10346. 10351. 10372. 10372. 10399. 10405. 10415. 10423. 10429. 10433. 10433. 1~ 7.5 10101.0 10110.0 10115.5 10119.0 10123.5 10126.0 10128.0 10138.0 10144.0 10149.5 10152.0 10156.0 10161.5 10172.0 10172.5 10179.0 10180.5 10192.0 10198.0 10200.5 10203.5 10206.5 10209.5 10213.0 10214.0 10220.0 10223.0 10229.5 10235.5 10238.5 10240.0 10244.0 10244.5 10255.0 10263.5 10271.5 10274.0 10276.0 10278.5 10281.0 10288.5 10295.5 10304.0 10307.5 10315.0 10316.0 10338.0 10340.5 10347.5 10351.0 10372.0 10373.0 10399.5 10406.5 10416.5 10424.0 10430.0 10433.5 10434.5 10438.0 10451.0 10452.0 10459.0 10460.0 10473.5 10482.5 10488.5 10492.5 10499.5 10501.5 10511.0 10511.5 10516.0 10516.5 10521.5 10530.0 10531.5 10534.0 10537.5 10538.0 10554.0 10561.5 10566.5 10568.5 10582.0 10588.0 10589.0 10597.5 10599.5 10619.0 10620.0 10635.5 10651.5 10653.0 10672.5 10673.5 10674.5 10681.5 10690.0 10696.5 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL GRZ SDN 2343 $ REMARKS: it 8.5 10451.5 10452.0 10459.5 10460.0 10473.5 10482.0 10488.0 10492.5 10499.5 10501.0 10510.5 10511.5 10515.5 10516.5 10521.5 10529.0 10531.0 10533.5 10537.5 10538.5 10554.5 10563.0 10567.0 10568.5 10582.5 10587.5 10589.0 10598.0 10599.5 10619.0 10619.5 10635.5 10651.0 10653.0 10672.5 10673.0 10674.0 10681.5 10691.0 10698.0 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 3 9727.0 10703.0 1 3 9782.0 10758.0 1 5 9720.0 10725.0 1 5 9750.0 10750.0 1 5 9785.0 10732.0 MAIN PASS. "GRZ" REFERS TO THE GAMMA RAY RUN WITH THE ZDL TOOL. MTEM, TEND, & TENS (from DIL tool) WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, CALl, TEND, & TENS (from ZDL tool) WERE SHIFTED WITH RHOB. CN WN FN COUN STAT /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.0UT /??MATCH4.OUT /??MATCH5.0UT /??MATCH6.OUT $ : BP EXPLORATION (ALASKA) : 1-03/P-16 PH : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 4 2 LL8 DIL 68 1 OHMM 4 3 ILM DIL 68 1 OHMM 4 4 ILD DIL 68 1 OHMM 4 5 RT DIL 68 1 OHMM 4 6 DI DIL 68 1 IN 4 7 SP DIL 68 1 MV 4 8 MTEM DIL 68 1 DEGF 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 11 GR SDN 68 1 GAPI 4 12 RHOB SDN 68 1 G/C3 4 13 DRHO SDN 68 1 G/C3 4 14 PEF SDN 68 1 BN/E 4 15 CALl SDN 68 1 IN 4 16 TEND SDN 68 1 LB 4 17 TENS SDN 68 1 LB 4 18 NPHI 2435 68 1 PU-S 4 19 FUCT 2435 68 1 CPS 4 20 NUCT 2435 68 1 CPS 4 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 181 Tape File Start Depth = 10800.000000 Tape File End Depth = 9720.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45382 datums Tape Subfile: 2 729 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9726.5 DIFL 9777.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10716.0 10772.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 13-0CT-95 FSYS REV. J001 VER. 1.1 2000 12-0CT-95 401 13-0CT-95 10773.0 10760.0 9800.0 10757.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 2806XA 3506XA 1503XA 9.875 4456.0 .0 LSND 10.80 55.0 9.5 4.5 182.0 .965 .367 .983 .000 65.0 182.0 57.0 .0 MUD CAKE 'AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX. · MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): REMARKS: DIFL/GR MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-03/P-16 PH : ENDICOTT : NORTH SLOPE : ALASKA 75 .000 .00 .000 1.5 57.0 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 VILD DIFL 68 1 MV 6 RT DIFL 68 1 OHMM 7 DI DIFL 68 1 IN 8 SP DIFL 68 1 MV 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 SPD DIFL 68 1 F/MN 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 48 * DATA RECORD (TYPE# 0) Total Data Records: 225 994 BYTES * Tape File Start Depth = 10784.000000 Tape File End Depth = 9720.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55342 datums Tape Subfile: 3 300 records... Minimum record length: 58 bytes Maximum record length: 994 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String ~1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 2 5 .2500 VENDOR TOOL CODE START DEPTH GR 9719.0 ZDL 9749.0 2435 9726.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10755.0 10775.0 10762.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 13-0CT-95 FSYS REV. J001 VER. 1.1 2000 12-0CT-95 711 13-0CT-95 10773.0 10760.0 9800.0 10750.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 9.875 4456.0 .0 LSND 10.80 55.0 9.5 4.5 182.0 .965 .367 .983 .000 .975 .000 65.0 182.0 57.0 .0 57.0 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: ZDL/CN/GR MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-03/P-16 PH : ENDICOTT : NORTH SLOPE : ALASKA THERMAL SANDSTONE 2.65 .000 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR ZDL 68 1 GAPI 4 2 ZDEN ZDL 68 1 G/C3 4 3 ZCOR ZDL 68 1 G/C3 4 4 PE ZDL 68 1 BN/E 4 5 CAL ZDL 68 1 IN 4 6 CHT ZDL 68 1 LB 4 7 TTEN ZDL 68 1 LB 4 8 SPD ZDL 68 1 F/MN 4 9 CNC 2435 68 1 PU-S 4 10 CNCF 2435 68 1 PU-S 4 11 CN 2435 68 1 PU-L 4 12 LSN 2435 68 1 CPS 4 13 SSN 2435 68 1 CPS 4 4 46 310 01 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 635 99 1 4 46 635 99 1 4 46 636 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 246 Tape File Start Depth = 10823.000000 Tape File End Depth = 9719.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1072~_ datums Tape Subfile: 4 319 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASS Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10215.0 DIFL 10264.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10711.0 10767.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: 13-0CT-95 FSYS REV. J001 VER. 1.1 2000 12-0CT-95 313 13-0CT-95 10773.0 10760.0 9800.0 10757.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 2806XA 3506XA 1503XA 9.875 4456.0 .0 LSND 10.80 55.0 9.5 4.5 182.0 .965 .367 .983 .000 .975 65.0 182.0 57.0 .0 57.0 MUD CAKE AT NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX · · MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: DIFL/GR REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-03/P-16 PH : ENDICOTT : NORTH SLOPE : ALASKA .000 .00 .000 1.5 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 VILD DIFL 68 1 MV 6 RT DIFL 68 1 OHMM 7 DI DIFL 68 1 IN 8 SP DIFL 68 1 MV 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 SPD DIFL 68 1 F/MN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 48 * DATA RECORD (TYPE# 0) Total Data Records: 120 994 BYTES * Tape File Start Depth = 10779.000000 Tape File End Depth = 10211.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 848~_ datums Tape Subfile: 5 194 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASS Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 6 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE GR ZDL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): START DEPTH STOP DEPTH 10294.0 10642.0 10323.5 10662.0 10300.0 10648.5 13-0CT-95 FSYS REV. J001 VER. 1.1 2000 12-0CT-95 805 13-0CT-95 10773.0 10760.0 9800.0 10750.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 4456.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: LSND 10.80 55.0 9.5 4.5 182.0 .965 .367 .983 .000 .975 .000 65.0 182.0 57.0 .0 57.0 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: ZDL/CN/GR REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-03/P-16 PH : ENDICOTT : NORTH SLOPE : ALASKA THERMAL SANDSTONE 2.65 .000 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR ZDL 68 1 GAPI 4 2 ZDEN ZDL 68 1 G/C3 4 3 ZCOR ZDL 68 1 G/C3 4 4 PE ZDL 68 1 BN/E 4 5 CAL ZDL 68 1 IN 4 6 CHT ZDL 68 1 LB 4 7 TTEN ZDL 68 1 LB 4 8 SPD ZDL 68 1 F/MN 4 9 CNC 2435 68 1 PU-S 4 10 CNCF 2435 68 1 PU-S 4 11 CN 2435 68 1 PU-L 4 12 LSN 2435 68 1 CPS 4 13 SSN 2435 68 1 CPS 4 4 46 310 01 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 635 99 1 4 46 635 99 1 4 46 636 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 93 Tape File Start Depth = 10710.000000 Tape File End Depth = 10294.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 130532 datums Tape Subfile: 6 Minimum record length: Maximum record length: 165 records... 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 95/10/18 01 **** REEL TRAILER **** 95/10/19 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 19 OCT 95 8:20a Elapsed execution time = 3.57 seconds. SYSTEM RETURN CODE = 0
