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Home My WebLink About193-083Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' 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 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 13,010 feet 12,840 feet true vertical 10,361 feet N/A feet Effective Depth measured 12,840 feet feet true vertical 10,228 feet 9,824'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / 13-CR / NSCT 12,388' 9,895' Baker SABL-3 12,299' (MD) 1,545' (MD) Packers and SSSV (type, measured and true vertical depth)7-5/8" Packer SSSV 9,824 (TVD) 1,542' (TVD) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Hilcorp Alaska, LLC 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,090psi2,717' 10,352' 110' 8,180psi Burst N/A 3,580psi 5,140psi Tubing Pressure 2,000 N/A measured N/A Conductor Length 110' 2,721' Authorized Name: David Gorm dgorm@hilcorp.com Size 1,940 DUCK IS UNIT MPI 2-60 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 270 Gas-Mcf 50 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. 321-150 360 Authorized Signature with date: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-083 50-029-22375-00-00 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL0034633 30" 10-3/4" 12,998' Casing Pressure Casing 2,159 Oil-Bbl measured true vertical Packer Surface Production 7-5/8" 12,299' WINJ WAG 0 Water-Bbl MD 110' 2,721' 12,998' TVD PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad Helgeson (1517) 2021.05.11 11:27:02 - 08'00' By Meredith Guhl at 12:36 pm, May 11, 2021 DSR-5/11/21 SFD 5/11/2021RBDMS HEW 5/12/2021 _____________________________________________________________________________________ Revised By: DH 5/3/2021 SCHEMATIC Endicott Unit Well: END 2-60 Last Completed: 1/30/1994 PTD: 193-083 TD =13,010’ (MD) / TD = 10,361’(TVD) 30” RT Elev.: 55.3’/ BF Elev.: 16.12’ 7-5/8” 3 5 6 7 8 11 10 12 13 10-3/4” 1 2 Squeezed Perfs PBTD =12,840’ (MD) / PBTD = 10,238’(TVD) 4 FISH:Full Bore Spinner Cone @ ±12,917’ 9 Open Perfs CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 30" Conductor 48 / H-40 / N/A N/A Surface 110' N/A 10-3/4" Surface 45.5 / J-55 / BTC. 9.95” Surface 2,721’ 0.0962 7-5/8" Production 29.7 / NT95HS / NSCC 6.875” Surface 12,998’ 0.0459 TUBING DETAIL 3-1/2” Tubing 9.2 / 13-CR/ NSCT 2.992” Surf 12,388’ 0.0087 JEWELRY DETAIL No Depth Item 1 1,545’ SSSV Landing Nipple (2.75” ID) w/ 3-1/2” BBE 2 3,691’ GLM #7 3 6,211’ GLM #6 4 8,350’ GLM #5 5 9,397’ GLM #4 6 10,317’ GLM #3 7 10,993’ GLM #2 8 11,700’ GLM #1 9 12,250’ SWS Nipple (2.75” ID) 10 12,299’ Baker SABL-3 7-5/8” Packer 11 12,330’ SWS Nipple (2.75” ID) 12 12,376’ SWS Nipple (2.75” ID) 13 12,387’ 3-1/2” WLEG 9-CR –Bottom @ 12,388’ – 2.99” ID PERFORATION DETAIL Endicott Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 3C5 12,615’ 12,635’ 10,071’ 10,086’ 20’ 9/12/1996 Open 3C4 12,655’ 12,667’ 10,101’ 10,110’ 12’ 6/11/1995 Open 3C4/ 3C3 12,690’ 12,720’ 10,127’ 10,150’ 10’ 6/20/1995 Open N/A 12,697’ 12,717’ 10,133’ 10,147’ 20’ 1/29/1994 Squeezed N/A 12,759’ 12,769’ 10,178’ 10,186’ 10’ 1/29/1994 Squeezed N/A 12,785’ 12,797’ 10,198’ 10,207’ 12’ 1/29/1994 Squeezed N/A 12,801’ 12,821’ 10,210’ 10,224’ 20’ 1/29/1994 Squeezed WELL INCLINATION DETAIL Max Deviation is 49 deg. @ ±6,700’ Angle at Top Perf: 40 de. @ 12,615’ TREE & WELLHEAD Tree 4-1/2”, 5000psi / Cooper Wellhead 13-5/8”/ 5,000psi/ FMC PBD Standard Wellhead GENERAL WELL INFO API: 50-029-22375-00-00 Drilled, Cased & Completed by Doyon 15 - 1/30/1994 Perforate – 6/20/1995 Perforate – 5/8/1996 Perforate – 9/12/1996 Set Plug in SWS Nipple – 8/26/2009 Pull Plug from SWS Nipple – 12/11/2014 Pull Plug and RTP – 3/8/2015 OPEN HOLE / CEMENT DETAIL 10-3/4” 998 cu/ft PF “E”1,432 cu/ft “G” in a 13-1/2” Hole 7-5/8” 2,289 cu/ft Class “G” in a 9-7/8” Hole SAFETY NOTE: H2S readings average 230 to 260 PPM on A/L & gas injectors. Well requires a SSSV H2S readings average 230 to 260 PPM END 2-60 Casing Repair Summary: 4/4/2021 – Prep the cellar, Cut out the cellar floor, prepare the well cellar to install the shoring sleeves. 4/5/2021 – Set the BPV, ND the Tree, NU the Well Support structure adapters to the TBG head. Mobilize the well support structure to END 2-60. Spot the Well support structure over the well. 4/6/2021 – RU the Well Support Structure to the well. 4/7/2021 - RU the well support structure to the adapters attached to the WH. 4/8/2021 - Pull 10K on the well to pre-load the wellhead. Cut the conductor away and chip the cement out. No wellbore load transferred to the WSS. Exposed the CSG split. Temporary external patch over the split to allow for a good nitrogen purge. The CSG split ended at the Collar connection. The split did not extend past the connection. 4/9/2021 - Complete UT inspection on the Wellhead and surface CSG. Identified internal drilling wear to the base of the exposed casing section. Proceed with installing the shoring walls and excavate deeper. 4/10/2021 - Cut the extra conductor off. Inspect the lower section of CSG. Identified good CSG 6' below the base of the BH. 4/11/2021 - Clean the lower section of CSG and start welding on the wedding band for the base of the CSG patch. 4/12/2021 - Complete welding the lower wedding band. Beveled the base of the mandrel hanger for the upper section of the planned CSG patch. 4/13/2021 - 24 hr cooling period for welding work 4/14/2021 - Install 6' clam shell (5' piece and a 1' piece butt welded to the base of the 5' piece), weld the lateral sections of the patch and weld the circumference. 4/15/2021 - Weld Upper CSG patch. 4/16/2021 - 24 hr Cooling Period post welding work 4/17/2021 - Inspected the final casing patch welds. Excavate down 4 more feet, exposing a total of 15' of Conductor. 4/18/2021 - Cut away the conductor pipe, chipped away the cement. Complete an inspection of the 10- 3/4" CSG down to the top of the cement. 4/19/2021 - Complete inspection on the 10-3/4" Casing. Confirmed with the Engineer the UT inspection results. Pressure tested the OA to 1000 psi. Pressure held passing test. No visible external leaks. Scheduled AOGCC witness pressure test. NOTE: The internal CSG wear extended continuously down the Surface CSG. The minimum ID found was 0.245”. Utilizing API 5C3 pressure rating calculations for the CSG determined the CSG to be rated for approximately 2000 psi on burst with the existing internal CSG wear. No extensive external corrosion. 4/21/2021 - Complete AOGCC Witnessed MIT on the OA to 1000 psi. The pressure test passed. Preparing the Conductor pipe for the re-install. 4/22/2021 - Completed the Conductor Install, Released the WSS. 4/23/2021 to 4/29/2021 – Cement conductor and treat with Blue Goo. Backfill cellar and install grate flooring. Complete reconnection of piping. 4/30/2021 – Pulled plug @ 12,376’. 5/1/2021 – Brushed X-Nipple at 1,545’ and set 3-1/2” BBE. Performed passing drawdown test. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 2-60 DUCK 1S UNIT MPI 2-60 Sre: Inspector Reviewed By: P.I. Supry jr>tL Comm Well Name DUCK IS UNIT MPI 2-60 API Well Number 50-029-22375-00-00 Inspector Name: Bob Noble Permit Number: 193-083-0 Inspection Date: 4/20/2021 Insp Num: mitxcxrloazonoazl Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-60 Type Inj I N TVD Tubing o 0 0 0 PTD 1930830 Type Test I SPT Test psi 1000 IA o 0 0 0 BBL Pumped: 05 BBL Returned: 0.5 _ OA 0 1096 j 1044 - 1023 _ Interval OTHER P/F P Notes: Post surface casing repair as per Sundry 321-150. ✓ Monday, April 26, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I�,-j 511 � 7i2i DATE: 4/08/2021 P. I. Supervisor 1 FROM: Guy Cook SUBJECT: Surface Casing Damage Petroleum Inspector DIU MPI 2-60 Hilcorp Alaska LLC. PTD 1930830; Sundry 321-150 4/08/2021: Arrived at Endicott Main Production Island and met with Jon Arend and Joshua Green with Hilcorp. We discussed the well and went out to visually inspect and take pictures of the casing damage. The split in the 10 Y44 -inch surface casing was 15 inches long between the surface casing hanger and the first collar. The pup joint that was split was a total length of 20 '/z inches long from the bottom of the integral casing hanger to the first collar. The damage extended farther down past the first collar but had not yet been uncovered. I requested them to give the AOGCC the opportunity to witness the damage once it was uncovered and before they did any repairs. The gray material covering the split in some of the pictures is a material called Belzona. It is similar to Baker -Loc and is used to stop the nitrogen used to purge the casing from leaking out into the confined space. Attachments: Photos (6) 2021-0408_Surface_Casing_Damage_DIU_2-60_gc.docx Page 1 of 4 I J •�'� � �r�� <�j� moi. � r� N O N 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): 13,010'N/A Casing Collapse Conductor N/A Surface 2,090psi Production 5,140psi 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: 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 DUCK IS UNIT MPI 2-60 C.O. 462.007 Baker SABL-3 7-5/8" Packer and SSSV 12,299MD/ 9,824TVD and 1,545MD/ 1,542TVD 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. Authorized Signature: 3/30/2021 3-1/2" Perforation Depth MD (ft): See Schematic See Schematic 110' 30" 10-3/4" 7-5/8" 2,721' 12,998' Perforation Depth TVD (ft): 3,580psi 8,180psi 2,717' 10,352' 2,721' 12,998' 12,840' Endicott Field / Endicott Oil Pool 110' 110' 9.2# / 13CR80 TVD Burst 12,388' MD N/A Length Size 10,361' 12,840' 10,238' 2,100 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 193-083 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22375-00-00 Hilcorp Alaska LLC Tubing Grade:Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:26 pm, Mar 26, 2021 321-150 Chad Helgeson (1517) 2021.03.26 13:00:47 - 08'00' SFD 3/26/2021 *Photo document repair for 10-404 DSR 3/30/21 10-404 MGR30MAR21C Required? Yes 3/31/21 dts 3/30/2021 JLC 3/31/2021 RBDMS HEW 4/2/2021 Surface Casing Leak Repair Well: END 2-60 PTD: 193-083 API: 50-029-22375-00-00 Well Name:END 2-60 API Number: 50-029-22375-00 Current Status:SI –SC Leak Rig: Wellhead Support N/A Estimated Start Date:3/30/2021 Estimated Duration:10 days Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd:No Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:193-083 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Tom Fouts (907) 777-8398 (O) (907) 351-5749 (M) AFE Number: Well EZ Inputs Required:Yes Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: ~4,166psi @ 10,000’ TVD ~4,166psi @ 10,000’ TVD ~2,100psi (Based on offset SBHPS) (Based on offset SBHPS) (Max BHP-(0.1 psi/ft x 10,000 TVD) Brief Well Summary: Well 2-60 is a gas lifted producer with a confirmed surface casing leak at 11.5’ below the OA valve. The well is a high water cut (~92%) well that requires artificial lift to flow (confirmed w/ passing No-Flow test on 03/09/15). A WellLock treatment of the SCxConductor annulus was attempted on 3/12/16 and a passing N2 test to 600 psi was obtained but diesel was again observed in the annulus when well was RTP’d. Well has been shut in since 4/30/16. OA Status: Open shoe. OA fluid level near surface, displaced entirely with diesel. Estimated that Production Casing TOC at 4,100’, 1,400’ below SC shoe (~340 bbls class G at .03825bpf in 7-5/8 by 9-7/8” annulus). Injectivity not achievable w/ the hole in the surface casing. SC Leak Depth/Rate: Leak was determined to be 11.5’ below the OA valve. Leak rate was established at 1:1 ratio @ pump pressure w/ diesel using a triplex pump. Known Casing split exists near surface. Objective: Remove conductor and weld a casing patch to restore OA integrity. Notes On Wellbore Condition: x Surface casing leak is estimated ~11.5” below the OA valve. x Surface casing was hung with a fluted mandrel hanger that sits above the landing ring. x 7-5/8” CSG TOC – 12,420’ MD (CBL 7-5-1995) x Estimate Load on the WH ~150 Klbs x Current surface pressures on well, T/I/O = 1,007/10/0. Procedure: Pre-Sundry Work Existing plug set @ 12,376’ will confirm plug is holding and no pressure exists on the tubing. Prep Work 1. Disconnect flowline and instrumentation. 2. Verify tubing, IA and OA pressures have been bled to 0psi. 3. 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. Confirm safety rep and confined space procedures in accordance with ASH are complete when personnel are entering the confined space. CMIT-TxIA to 1500 psi. Surface Casing Leak Repair Well: END 2-60 PTD: 193-083 API: 50-029-22375-00-00 4. 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 adequate space for conductor removal. 5. 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 6. Install BPV and nipple down tree at the tubing head adapter to makeup Wellhead Support Structure adapter flange. 7. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 8. 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. 9. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual. 10. Pull 50,000 lbs gradually building up load in 1,000 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. 11. Drill holes (cold cutting drill bit) in the conductor roughly 2’ and 5’ below the landing ring. 12. 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. 13. 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. 14. Cut and remove conductor from above the 5’ 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. 15. 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. 16. 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 17. 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 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 Surface Casing Leak Repair Well: END 2-60 PTD: 193-083 API: 50-029-22375-00-00 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”. b.Option 2 – Confirm final Well Support Structure load with OE prior to welding the patch. Cut out split 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. 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. 18. Inspect the welds to ensure competency. 19. Conduct a MIT-OA to 1,000psi to confirm SC integrity a. The OA has an open shoe, the OA is not expected to hold 1,000 psi solid. Plan to observe pressure fall off until a stable pressure is obtained. During the pressure test monitor the surface CSG/Conductor annulus for communication. Notify the operations engineer to review the pressure test results before proceeding. 20. Gradually release wellhead load from Well Support Structure back onto patched surface casing. 21. Unbolt and remove the adapter flange. 22. Reinstall 5K production tree. 23. Remove BPV and install TWC. Pressure test tree to 5,000psi. 24. Re-install flowline and instrumentation. 25. Remove TWC. Slickline 26. MIRU SL unit. 27. Pressure test to 300psi low and at least 2,100psi high. 28. RIH and pull 3-1/2” (3.813”) PXX plug from 12,376’ md. 29. RIH and set 3.5” BBE at 1,545’ MD 30. RDMO 31. Turn well back over to production Post Repair Work 32. Weld cut conductor halves back onto conductor. 33. Reinstall well house and backfill gravel over cellar liner. 34. Cement SC by Conductor Annulus back to within 1ft of conductor top. 35. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Attachments: Schematic Proposed Schematic 2017 Initial Repair Timeline (Rolling pressure test) Perform post welding CMIT-TxIA to 1500 psi to assure competency of 7-5/8" casing before pulling plug. 10-3/4" section will be a split then welded circum- ferentially and axially in place. _____________________________________________________________________________________ Revised By: TDF 3/25/2021 SCHEMATIC Endicott Unit Well: END 2-60 Last Completed: 1/30/1994 PTD: 193-083 TD =13,010’ (MD) / TD = 10,361’(TVD) 30” RT Elev.: 55.3’/ BF Elev.: 16.12’ 7-5/8” 3 5 6 7 8 11 10 12 13 10-3/4” 1 2 Surface Casing Leak @ 11’ Squeezed Perfs PBTD =12,840’ (MD) / PBTD = 10,238’(TVD) 4 FISH:Full Bore Spinner Cone @ ±12,917’ 9 Open Perfs CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 30" Conductor 48 / H-40 / N/A N/A Surface 110' N/A 10-3/4" Surface 45.5 / J-55 / BTC. 9.95” Surface 2,721’ 0.0962 7-5/8" Production 29.7 / NT95HS / NSCC 6.875” Surface 12,998’ 0.0459 TUBING DETAIL 3-1/2” Tubing 9.2 / 13-CR/ NSCT 2.992” Surf 12,388’ 0.0087 JEWELRY DETAIL No Depth Item 1 1,545’ SSSV Landing Nipple (2.75” ID) 2 3,691’ GLM #7 3 6,211’ GLM #6 4 8,350’ GLM #5 5 9,397’ GLM #4 6 10,317’ GLM #3 7 10,993’ GLM #2 8 11,700’ GLM #1 9 12,250’ SWS Nipple (2.75” ID) 10 12,299’ Baker SABL-3 7-5/8” Packer 11 12,330’ SWS Nipple (2.75” ID) 12 12,376’SWS Nipple (2.75” ID) ***3-1/2” PXX plug set on 10/10/17*** 13 12,387’ 3-1/2” WLEG 9-CR –Bottom @ 12,388’ – 2.99” ID PERFORATION DETAIL Endicott Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 3C5 12,615’ 12,635’ 10,071’ 10,086’ 20’ 9/12/1996 Open 3C4 12,655’ 12,667’ 10,101’ 10,110’ 12’ 6/11/1995 Open 3C4/ 3C3 12,690’ 12,720’ 10,127’ 10,150’ 10’ 6/20/1995 Open N/A 12,697’ 12,717’ 10,133’ 10,147’ 20’ 1/29/1994 Squeezed N/A 12,759’ 12,769’ 10,178’ 10,186’ 10’ 1/29/1994 Squeezed N/A 12,785’ 12,797’ 10,198’ 10,207’ 12’ 1/29/1994 Squeezed N/A 12,801’ 12,821’ 10,210’ 10,224’ 20’ 1/29/1994 Squeezed WELL INCLINATION DETAIL Max Deviation is 49 deg. @ ±6,700’ Angle at Top Perf: 40 de. @ 12,615’ TREE & WELLHEAD Tree 4-1/2”, 5000psi / Cooper Wellhead 13-5/8”/ 5,000psi/ FMC PBD Standard Wellhead GENERAL WELL INFO API: 50-029-22375-00-00 Drilled, Cased & Completed by Doyon 15 - 1/30/1994 Perforate – 6/20/1995 Perforate – 5/8/1996 Perforate – 9/12/1996 Set Plug in SWS Nipple – 8/26/2009 Pull Plug from SWS Nipple – 12/11/2014 Pull Plug and RTP – 3/8/2015 OPEN HOLE / CEMENT DETAIL 10-3/4” 998 cu/ft PF “E”1,432 cu/ft “G” in a 13-1/2” Hole 7-5/8” 2,289 cu/ft Class “G” in a 9-7/8” Hole SAFETY NOTE: H2S readings average 230 to 260 PPM on A/L & gas injectors. Well requires a SSSV _____________________________________________________________________________________ Revised By: TDF 3/25/2021 PROPOSED Endicott Unit Well: END 2-60 Last Completed: 1/30/1994 PTD: 193-083 TD =13,010’ (MD) / TD = 10,361’(TVD) 30 ” RT Elev.: 55.3’/ BF Elev.: 16.12’ 7-5/8” 3 5 6 7 8 11 10 12 13 10-3/4” 1 2 Surface Casing Leak @ 11’ Squeezed Perfs PBTD =12,840’ (MD) / PBTD = 10,238’(TVD) 4 FISH: Full Bore Spinner Cone @ ±12,917’ 9 Open Perfs CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 30" Conductor 48 / H-40 / N/A N/A Surface 110' N/A 10-3/4" Surface 45.5 / J-55 / BTC. 9.95” Surface 2,721’ 0.0962 7-5/8" Production 29.7 / NT95HS / NSCC 6.875” Surface 12,998’ 0.0459 TUBING DETAIL 3-1/2” Tubing 9.2 / 13-CR/ NSCT 2.992” Surf 12,388’ 0.0087 JEWELRY DETAIL No Depth Item 1 1,545’ SSSV Landing Nipple (2.75” ID) 2 3,691’ GLM #7 3 6,211’ GLM #6 4 8,350’ GLM #5 5 9,397’ GLM #4 6 10,317’ GLM #3 7 10,993’ GLM #2 8 11,700’ GLM #1 9 12,250’ SWS Nipple (2.75” ID) 10 12,299’ Baker SABL-3 7-5/8” Packer 11 12,330’ SWS Nipple (2.75” ID) 12 12,376’ SWS Nipple (2.75” ID) 13 12,387’ 3-1/2” WLEG 9-CR –Bottom @ 12,388’ – 2.99” ID PERFORATION DETAIL Endicott Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 3C5 12,615’ 12,635’ 10,071’ 10,086’ 20’ 9/12/1996 Open 3C4 12,655’ 12,667’ 10,101’ 10,110’ 12’ 6/11/1995 Open 3C4/ 3C3 12,690’ 12,720’ 10,127’ 10,150’ 10’ 6/20/1995 Open N/A 12,697’ 12,717’ 10,133’ 10,147’ 20’ 1/29/1994 Squeezed N/A 12,759’ 12,769’ 10,178’ 10,186’ 10’ 1/29/1994 Squeezed N/A 12,785’ 12,797’ 10,198’ 10,207’ 12’ 1/29/1994 Squeezed N/A 12,801’ 12,821’ 10,210’ 10,224’ 20’ 1/29/1994 Squeezed WELL INCLINATION DETAIL Max Deviation is 49 deg. @ ±6,700’ Angle at Top Perf: 40 de. @ 12,615’ TREE & WELLHEAD Tree 4-1/2”, 5000psi / Cooper Wellhead 13-5/8”/ 5,000psi/ FMC PBD Standard Wellhead GENERAL WELL INFO API: 50-029-22375-00-00 Drilled, Cased & Completed by Doyon 15 - 1/30/1994 Perforate – 6/20/1995 Perforate – 5/8/1996 Perforate – 9/12/1996 Set Plug in SWS Nipple – 8/26/2009 Pull Plug from SWS Nipple – 12/11/2014 Pull Plug and RTP – 3/8/2015 OPEN HOLE / CEMENT DETAIL 10-3/4” 998 cu/ft PF “E”1,432 cu/ft “G” in a 13-1/2” Hole 7-5/8” 2,289 cu/ft Class “G” in a 9-7/8” Hole SAFETY NOTE: H2S readings average 230 to 260 PPM on A/L & gas injectors. Well requires a SSSV Endicott 2-60 Casing Repair 4/15/2017 AIC MOBED equipment to sight to begin ground thaw operations. Equipment MOBED-450 excavator, shale bin, loader, steam unit and drill Drill holes in front of 2-60 and 2-14 and begin steaming ops Encounter water between 6 and 8’ below surface at 2-60 and 3’ below grade at 2-14 DEMOBE drill unit 4/16/2017 Thaw ground with steam unit day and night shift. Focused on 2-60 due to high water table on 2-14 4/17/2017 Hold ATP meeting with AIC crew and facility personnel Opened up ground in front of well 2-60, encounter water at ~6’ below grade. Made decision to cover hole back in until next day to allow more time to dig, set well point and boxes 4/18/2017 Excavate in front of 2-60 Order shale bin from AIC for gravel storage. AIC crew assembling trench boxes on pad Move all gravel to shale bin upon arrival 4/19/2017 Continue excavation for outer trench box and sump Dig through mostly frozen ground to ~15’ below grade. Excavator penetrated into apparent thaw bulb attempt to pump water out enough to set corrugated pipe for sump. Pump unable to keep ahead of water. Observe thawed material undermining ground where work was taking place. Knocked in unstable areas around excavation, barricade off area, shut down for the day to access situation and make plan forward. Water level equalized at ~3’ below grade 4/20/2017 Backfill hole at 2-60 until situation can be reassessed. Decide to shift excavation to 2-14 while making plan forward on 2-60. Move to thawing ground at 2-14 4/23/2017 Install well point 1 1/2’ off front corner well house foundation I-beam using perforated 24” diameter CMP sunk to ~8’ below grade and 18” diameter perforated CMP placed inside of 24” and sunk to ~14’ below grade Test dewatering capabilities from well point using 2” pump going into open top bin, pump was able to keep ahead of water in sump 2ea 500bbl frack tanks onsite for storage of water from well points Move back to 2-14 for excavation 4/25/2017 Move 1 frack tank to 2-60 from 2-14, set up pump and begin dewatering Decision made to attempt excavation on 2-60 with AIC crew while GBR performs welding on 2-14 Plan change to not utilize outer trench box area only using 1 set of trench boxes directly around well to minimize area of excavation and area for dewatering 4/26/2017 Thaw and begin excavation of material in and around well house foundation I-beams 4/27/2017 Continue excavating with steam unit and super sucker prepping foundation for removal I-beam exposed and ready to pick 4/28/2017 Remove floor grating on cellar Excavate around cellar to floor depth prep cellar for cutting Crew pulled off 2-60 to excavate further on 2-14 to facilitate removal of additional conductor to get below leak site. Crane still made off to 2-14 4/29/2017 Rig up and pull foundation I-beams Cut cellar and remove Place bottom trench box around well continue excavation 4/30/2017 Continue excavation to ~13’ below grade, set upper trench box Awaiting completion of welding on 2-14 for removal of conductor 5/01/2017 Build scaffolding in bottom of trench Drill drain holes in conductor to drain fluid beginning at ~5’ below cement flutes 5/02/2017 Rig up facility crane to well tree to provide support while cutting conductor Begin to cut top 2’ of conductor for removal Upon removing top section of conductor found 10 ¾” casing split beginning at top of cement squeeze running up 8-10” Mistras performed UT thickness testing on casing. Surface casing has internal wear damage due to drilling damage in a ~5” band down vertically alongside one side. Wall thickness in area of split ranges from .096” at top of split to .220” towards the bottom of split. Thin area on casing runs upward through landing ring area to threaded pup joint at tree Tack weld conductor halves back in place to provide lateral support of tree after crane is removed 5/03/17 Decision made to abandon efforts to repair casing leak due to the unknown depth of internal mechanical drilling wear damage and length of the casing split Weld up conductor halves, remove scaffolding and prepare excavation for backfill 5/04/17 Backfill excavation to cellar depth 5/05/2017 Fly in cellar halves and fit up for welding 5/06/2017 Weld up cellar halves replace floor grating 5/07/2017 Pull trench box, set foundation I-beams and complete backfill STATE OF ALASKA AL.OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Repair Surface Casing ❑� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC �/ Development 0Exploratory ❑ 193-083 at)0 2e p,�..1 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22375-00-00 C 16 I` s/'" ') 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED L..irPE I V E _p ADL0034633 DUCK IS UNIT MPI 2-60 s—.¢.... --¢...-/7 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MAY 1 9 2017 N/A Endicott Field/Endicott Oil Pool 11.Present Well Condition Summary: AOGCC Total Depth measured 13,010 feet Plugs measured 12,840 feet true vertical 10,361 feet Junk measured N/A feet Effective Depth measured 12,840 feet Packer measured 12,299 feet true vertical 10,228 feet true vertical 8,824 feet Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' N/A N/A Conductor 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Surface 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13-CR/NSCT 12,388' 9,895' 12,299(MD) 1,545(MD) Packers and SSSV(type,measured and true vertical depth) SABL-3 SSSV 9,824(TVD) 1,542(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNED W4 f '- ,n Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 50 13 Subsequent to operation: 0 0 0 50 4 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory El Developmentl= Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-086 Authorized Name: Bo York Contact Name: Taylor Wellman"? -J Authorized Title: Operations Manager Contact Email: tW@IIn18r1(C7hIICOrp.COCY1 I/Mk Authorized Signature:'/� Dati 5017 Contact Phone: 777-8449 dk S----ZZ--/7" - 74 't f4'' V MAY 1 9 2017 Form 10-404 Revised 4/2017 RBDMS / Submit Original Only • Endicott Unit Well: END 2-60 SCHEMATIC Last Completed: 1/30/1994 Hilcora Alaska,LLC PTD: 193-083 TREE&WELLHEAD RT Elev.:55.3'/BE Elev.:16.12' Tree 4-1/2",5000psi/Cooper 0,0 g E Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead 30' �� OPEN HOLE/CEMENT DETAIL Surface 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole Casing Leak 7-5/8" 2289 cu/ft Class"G"in a 9-7/8"Hole @11' CASING DETAIL W Size Type Wt/Grade/Conn Drift ID Top Btm BPF 1 1 430" Conductor 48/H-40/N/A N/A Surface 110' N/A Etl 10-3/4" Surface 45.5/J-55/BTC. 9.95" Surface 2721' 0.0962 L* -5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 10-3/4" TUBING DETAIL ir 2 3-1/2" Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 JEWELRY DETAIL No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) 3 2 3,691' GLM#7 3 6,211' GLM#6 4 8,350' GLM#5 5 9,397' GLM#4 4 6 10,317' GLM#3 7 10,993' GLM#2 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 10 12,299' Baker SABL-3 7-5/8"Packer 5 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID)***3-1/2"PXX plug set on 2/9/17*** 1 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID , 6 WELL INCLINATION DETAIL ' Max Deviation is 49 deg.@±6,700' r` I t Angle at Top Pert 40 de.@ 12,615' 7 . =r PERFORATION DETAIL 4, Endicott Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9 T $ ' ) ;;' 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open e ") 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open � 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open E *. N/A 12697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed N/A 12759' 12769' 10,178' 10,186' 10' 1/29/1994 Squeezed !i» N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed r`" 4 N/A 12,801' 12821' 10,210' 10,224' 20' 1/29/1994 Squeezed GENERAL WELL INFO '--* 9 ,, API:SO-029-22375-00-00 Drilled,Cased&Completed by Doyon 15 -1/30/1994 ' 10 Perforate-6/20/1995 s Perforate-5/8/1996 1 11 ' Perforate-9/12/1996 l;',1 12 'N Set Plug in SWS Nipple-8/26/2009 .. Pull Plug from SWS Nipple-12/11/2014 k,‘ -13 Pull Plug and RTP-3/8/2015 , }Open Perfs SAFETY NOTE: H2S readings average 230 to 260 PPM on TOC @ 12,860 .4.s A/L& as injectors.Well requires a SSSV 4/29/1996 ?'k1C r Squeezed Perfs g 1 q ".-J ? FISH:Full Bore 7-5/8' . ' `' Spinner Cone @ - ' ±12,917 TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Revised By:1CM 2/28/17 • Endicott 2-60 Casing Repair 4/15/2017 AIC MOBED equipment to sight to begin ground thaw operations. Equipment MOBED-450 excavator, shale bin, loader, steam unit and drill Drill holes in front of 2-60 and 2-14 and begin steaming ops Encounter water between 6 and 8' below surface at 2-60 and 3' below grade at 2-14 DEMOBE drill unit 4/16/2017 Thaw ground with steam unit day and night shift. Focused on 2-60 due to high water table on 2-14 4/17/2017 Hold ATP meeting with AIC crew and facility personnel Opened up ground in front of well 2-60, encounter water at—6' below grade. Made decision to cover hole back in until next day to allow more time to dig,set well point and boxes 4/18/2017 Excavate in front of 2-60 Order shale bin from AIC for gravel storage. AIC crew assembling trench boxes on pad Move all gravel to shale bin upon arrival 4/19/2017 Continue excavation for outer trench box and sump Dig through mostly frozen ground to^'15' below grade. Excavator penetrated into apparent thaw bulb attempt to pump water out enough to set corrugated pipe for sump. Pump unable to keep ahead of water. Observe thawed material undermining ground where work was taking place. Knocked in unstable areas around excavation, barricade off area,shut down for the day to access situation and make plan forward. i • A, sit , .... . .. ,,,,,, _ ..,„ " It° ti 014 V 4. x < R . , 111 r q y ,tspiti",.1. '"-.:., ' • ..:1°-*“. ;,. +� yo,:r„..z....,,77..i.1„,tt:tt,zs.: :4.,,..:S4,:.,c...::::,41:1_,,, 14: w"..,,i 1,e's,,,,,.tv,2t,..:4: 1,;,.:1, s. ,7,,,..,,,,,..4::::.:,t.:::::,... :,77,,........,i.7:,: ':.1: 4 4,,,,, : ,,,, ,. .„,...„. , ,.„... , ,,,.., ,,,,.. . .„.„,„.. *„..„ , . ,,„,,,:.,,,,11,,,‘ :, Water level equalized at"'3' below grade 1 : ^s ° a a_ "3 ,.*r'i .*k $ 1� ,• � M 3 1 &' '' „ `er 4a �- e " � f4y ti S,:,...... - . "� . �. . • • 4/20/2017 Backfill hole at 2 60 until situation can be reassessed. Decide to shift excavation to 2 14 while making plan forward on 2 60. Move to thawing ground at 2-14 ' ' i ET-" , it 1 , - 't '''''' '- . '''''"4, 1. ;Cr -' 'Om' ' ,y Y �. , Vi . a .. 1 Eft .� ., ,4fLF w n r., "� � xp ,. .:- ,,"'''''.174,;,, .,.y s ..' � ,. i`--x�``�" ,„fir. w-t • ., 4 te r'll:AC '�`i , r- � '""` v , =mac'' ' ' �sr '* ., 1-'7'":—'. , -4"4": .. ." .41...* -,....:' -\...4"k4t.Z.. ''''"tZti*,...4.1.- $ p';, k z . +« M '47.;-..4'1141'..,' . i _ a AC*-- w « :. m ' 4/23/2017 Install well point 1 1/2' off front corner well house foundation I beam using perforated 24" diameter CMP sunk to "8' below grade and 18" diameter perforated CMP placed inside of 24" and sunk to ' 14' below grade Test dewatering capabilities from well point using 2" pump going into open top bin, pump was able to keep ahead of water in sump Zea 500bbI frack tanks onsite for storage of water from well points Move back to 2 14 for excavation . 4..d -4, --,. t .''',4:7' .7. it .F., ,if, „„„4 , :4 'Iwo' g, � • �y is \4 (rr'` <, fP 4 1107 a a • 4/25/2017 Move 1 frack tank to 2-60 from 2-14, set up pump and begin dewatering Decision made to attempt excavation on 2-60 with AIC crew while GBR performs welding on 2-14 Plan change to not utilize outer trench box area only using 1 set of trench boxes directly around well to minimize area of excavation and area for dewatering 4/26/2017 Thaw and begin excavation of material in and around well house foundation I-beams 4/27/2017 Continue excavating with steam unit and super sucker prepping foundation for removal I-beam exposed and ready to pick w • A.� rAl,y ,fie af5 c 11111111111 411111.11 • x ':41"141' ' '.a�i4 a' «" 'a 4/28/2017 Remove floor grating on cellar Excavate around cellar to floor depth prep cellar for cutting Crew pulled off 2-60 to excavate further on 2-14 to facilitate removal of additional conductor to get below leak site. Crane still made off to 2-14 4/29/2017 Rig up and pull foundation I-beams Cut cellar and remove Place bottom trench box around well continue excavation . • iN ff, 4. iioi 4V f '...,.i?,,:,,-,,,.. g ' , 4,1,..,,i ,1 r „, , :. ,,, ,., , ,. t , -... ''' ._. ..,,,. ,. , ____,............gniiiomMlp,..._, 4/30/2017 Continue excavation to —13' below grade, set upper trench box Awaiting completion of welding on 2-14 for removal of conductor 4141 111,- C !ill ► �I ,�t► �'`' ..,- i; i.444:''-'"?''''.''''' - - . ....,-.-':'::,,,,,:g' "*"4"""'**::"I':;ttlii'tf':.1"L';''r''r--.X''i',S,':';';:'I''I.,'V' ':s r .` w - ,:iirt- . t imfro, , • .,,, '. ._ • +t 5/01/2017 Build scaffolding in bottom of trench Drill drain holes in conductor to drain fluid beginning at—5' below cement flutes <� . 4 3 Int � & --g'-i:v;,:4'''',.-t ' -" '''A .,.• .� F¢ , c �� -:,...,;,....i!,...!, ''i5 �." xa .' • R "'; ' ..'"*..'40.; ,- 't i 8 ,yy f ei'4':'."E4''''C't' ' ' ' 'f*,A t ' 'ts1 ygi'.4) t 15 ^ € ' '''', ' j '' 13 41':: i ' ‘:O.'/ .,.t. 4 . * opi'<t awl. »e t dd /„ t s e rafts ' - ." ''''',%!S,,:i ',E.,;.°. � " 5/02/2017 Rig up facility crane to well tree to provide support while cutting conductor Begin to cut top 2' of conductor for removal Upon removing top section of conductor found 10%" casing split beginning at top of cement squeeze running up 8-10" • 0 ,, 11 0 Ili lily ?. "'' �" s iiii‘b, , 71,111 , �... 4440 Skii#00.' ' • • , .,trit . k s • v; • '• ; r $ 4 , Z tF • • • Mistras performed UT thickness testing on casing. Surface casing has internal wear damage due to drilling damage in a ^'5" band down vertically alongside one side. Wall thickness in area of split ranges from .096" at top of split to .220" towards the bottom of split. Thin area on casing runs upward through landing ring area to threaded pup joint at tree Tack weld conductor halves back in place to provide lateral support of tree after crane is removed 5/03/17 /Decision made to abandon efforts to repair casing leak due to the unknown depth of internal mechanical drilling wear damage and length of the casing split Weld up conductor halves, remove scaffolding and prepare excavation fortion for IF „„m00000000000100040,„„, *44 0 s Y � i .m t wr t 4. 3 n s { *ate 4.14' 5/04/17 Backfill excavation to cellar depth 5/05/2017 Fly in cellar halves and fit up for welding • Ill 5/06/2017 Weld up cellar halves replace floor grating V....,,,,;,:i.,7i$.,,,:..7;„.,.,:.,,,,s,::;!,,.:;,..,4::...1,1",...iti,"'...:!7,.'....2,,,,...4".:_.,,,-/47:.........-.,:‘,-::::„,:,,,.., v.,:',..$..:.";,!-. fir, s a it '''-'42Z..'-'4,,,,,:* . � w, ' ,. !�` �" ; yam` 't� " j--•%*- • §x. q t' $ max, ';*, q. " `i„*� °^ $v^+wx a' "`*°d•"�.`a `� i. a ,a. to ,,,,. .. fi rax 4�r 5/07/2017 Pull trench box, set foundation I-beams and . , . . ,, , ..., ,,_ , complete backfill f , „, ,, , .i.,„ , ::::.,4, u, 1 A � .Wu ' g� 4 . #ii t ` "C ,F ,, PAY" re, ^:- & i; ....:,,,..,7.:3,,I ..,..-..,..4,-...,:c..4.1„,,, ,,..,-„,:,..,.,... . IN .: . ,:,--,,,,:,.-77 . ...r.,,i,it„,,,ilk,. r� m IP • OF Ttt 4",8'\1///*4), THE STATE Alaska Oil and Gas—sem ti, o ee TT cc Conservation Commission f17L�V IKJ\ t ih i� 333 West Seventh Avenue k.e>" rt- '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �R ��.• Main: 907.279.1433 �F -„SQ. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 SCANNED MAR 2 0 7017 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-60 Permit to Drill Number: 193-083 Sundry Number: 317-086 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 i Daniel T. Seamount, Jr. Commissioner rj DATED this 2 3 day of February, 2017. RBDMS LL- FEB 1. 7 2017 • • • RECEIVED ' STATE OF ALASKA rEe 1 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ADGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Repair surface csg D. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q • 193-083 • 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Dr,Suite 1400,Anchorage,AK 99503 50-029-22375-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.462 Will planned perforations require a spacing exception? Yes 0 No ❑., DUCK IS UNIT MPI 2-60 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034633 • Endicott Field/Endicott Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,010' • 10,361' • 12,840' 10,238' 2,100 12,840' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' N/A N/A Surface 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Production 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/13CR80 12,388' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SABL-3 7-5/8"Packer and SSSV 12,299MD/9,824TVD and 1,545MD/1,542TVD 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: 3/3/2017 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved tit j.4 ye.N' it"`rA herein will not be deviated from without prior written approval. Contact faf Taylor Wellman Email twellman©hilcorp.com Printed Name Bo York Title Operations Manager Signature \JL i / ret.. Phone 777-8345 Date z/ t 7 / z d 1'7 COMMISSION USE ONLY Conditions of approval: Notify Com 'ssion so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test Location Clearance El ,,,k af-- I'a t%1 O Other: pitch/- L Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /b ._ yg,q RBDMS LL- FEB 2 7 2017 APPROVED BY 2..._/ Approved by: / COMMISSIONER THE COMMISSION Date: 'grL 311 7 A' ?�. .2- /-/7 0 i I Submit Form and Form 10-403 Revised 11/2015 v p f I 1 S Or 12 months from the date of approval. Attachments in Duplicate • • Repair SC Leak 1/1 Well: END 2-60 PTD: 193-083 H;lcorp Alaska,LD API: 50-029-22375-00 Well Name: END2-60 API Number: 50-029-22375-00 Current Status: SI—SC Leak Rig: N/A Estimated Start Date: March 3, 2017 Estimated Duration: 14 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: No Regulatory Contact: Darci Horner 777-8406 Permit to Drill Number: 193-083 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907)777-8547 (0) (509)670-8001 (M) AFE Number: Well EZ Inputs Required: Yes Current Bottom Hole Pressure: —4166psi @ 10,000'TVD (Based on SBHPS on Sept 2008) Maximum Expected BHP: -4166psi @ 10,000'TVD (Based on SBHPS on Sept 2008) Max.Anticipated Surface Pressure: —2100psi (Based on max GL system pressure & passing No Flow test) Recent T/I/O Surface Pressures 400/250/0 psi (Taken 1/17/17) Brief Well Summary: Well 2-60 is a gas lifted producer with a confirmed surface casing leak at 11.5' below the OA valve. The well is a high water cut(-92%)well that requires artificial lift to flow(confirmed w/passing No-Flow test on 03/09/15). A WeIlLock treatment of the SCxConductor annulus was attempted on 3/12/16 and a passing N2 test to 600 psi was obtained but diesel was again observed in the annulus when well was RTP'd.Well has been shut in since . 4/30/16. 08/16/09:Crude noted in conductor 08/18/09: MIT-OA Failed to 500 psi w/N2.At 400psi,bubbling observed and at 500psi first lowered 02%observed 08/23/09: MIT-OA Failed to 500 psi.At 500psi lowered 02%in flutes confirm SC leak to surface. 08/25/09:Set TTP @ 12376', MIT-T Passed to 3000 psi 12/11/09:CMIT-TxIA Passed to 3000 psi 12/19/09:MIT-OA w/N2. Pressure to 800psi with no change in 02%. 12/20/09:MIT-OA w/N2.At 1000psi,observed lowered 02%.SC leak strapped at 11.5' 03/06/10:Liquid Leak Rate down OA. Unable to psi up OA above 1480 psi 09/04/10: Liquid Leak Rate down OA.8 gpm @ 350 psi 09/16/10: Liquid Leak Rate down OA.0.35 bpm @ 950 psi, lost pressure above 1100 psi and LLR became 5 bpm @ 800 psi 10/31/11:CMIT-TxIA Passed to 3000 psi. 11/20/11:Wellhead Seal Test of the tubing-Passed to 5000 psi, Replaced broken LDS 12/05/14:MIT-T to 3000psi—Passed,CMIT-TxIA to 3000 psi—Passed. 02/27/15:MIT-T to 2958psi—Passed.CMIT-TxIA to 3122psi—Passed. 03/09/15:No-Flow Test—Passed.Well returned to production. 3/12/2016:WeIlLock Resin applied through flutes in conductor to repair surface casing leak. 3/20/2016: MIT-OA passed td 600 psi with N2. No returns 3/21/2016: Diesel observed in SCxConductor annulus,attempt to MIT-OA with diesel. Pressure up to 600 psi but observed returns in annulus. Follow up with Nitrogen and observe bubbles on the conductor wall. 7/19/2016: Pump 1.4bpm @ 14psi for 4bbls of surfactant into OA with direct returns to conductor. Conduct conductor top job and place 4.5bbls of cement in conductor. 7/20/2016: MIT-OA failed w/1:1 returns from the conductor. OA Status: Open shoe. OA fluid level near surface, displaced entirely with diesel. Estimated that Production Casing TOC at 4100', 1400' below SC shoe(^'340 bbls class G at.03825bpf in 7-5/8 by 9-7/8" annulus). Injectivity not • achievable w/the hole in the surface casing. • Repair SC Leak Well: END 2-60 PTD: 193-083 Hilcorp Alaska,LLI API: 50-029-22375-00 SC Leak Depth/Rate: Leak was determined to be 11.5' below the OA valve. Leak rate was established at 1:1 ratio @ pump pressure w/diesel using a triplex pump. Objective: Mitigate flow of hydrocarbons to surface through the SCxConductor annulus by excavating to the leak site and repairing with an external casing patch. Procedure: Pre-Sundry Work Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 2100psi high. a. Use GL system pressureb( tt- 3. MU plug toolstring and set a 3-1/2" (2.75")X plug @ 12,376' md. �' d a. Note: Last plug set in this nipple was successful on 2/20/15. b. Bleed down the tubing pressure to confirm set. 4. RDMO Operations 5. Remove wellfouse and begin to thaw ground. 6. Bleed down T/I/O to Opsi. 7. Disconnect flowline and instrumentation. 8. Complete an ACWR(Area Civil Work Request)which includes a locate for all utilities,thermosyphons and all underground infrastructure. Sundry Work(Approval required to proceed) Tree&Wellhead 9. Verify tubing, IA and OA pressures have been bled to Opsi. 10. Close the master valve. 11. Remove SSV barrel. 12. Contingency—If upper tree is determined to be an obstacle/hindrance to work area or moving equipment in/out of repair area. a. Pressure test against the master valve to 300psi low and 4500psi high. b. Unbolt and remove the upper production tree. c. Install dry hole tree (master valve,swab valve&tree cap). d. Pressure test the upper tree assembly to 4500psi. ----- Operations 13. Excavate and install shoring to a depth of—15' below pad level and grade out the front for secondary egress. a. Primary plan is to use modular shoring boxes. Hold additional onsite JSA to determine if adjacent wells(END 2-58& END 2-62)will remain online or be shut in to move the shoring boxes in place. b. All excavations will comply with the ASH handbook and OSHA Regulations. c. A competent person will be onsite during the excavation and perform daily checks prior to entry by personnel. d. Use of mechanical excavation tools are not to come within 3' of cellar as per ASH handbook. . • Repair SC Leak Well: END 2-60 PTD: 193-083 • Hilcorp Alaska,LD API: 50-029-22375-00 14. Install high volume water pumps into a low spot in the floor of the excavation. a. A test hole was dug near END 2-60 in November 2016 which found water at"'9'below pad grade. 15. Deconstruct and remove the existing well cellar. 16. Install secondary containment around lower edge of conductor. 17. Install clamp to secure landing ring of conductor to the wellhead. 18. Drill holes (cold cutting drill bit) in the conductor and remove cement as needed to expose clean casing for inspection. 19. Once a final depth is determined where uncorroded surface casing is found, drill additional holes (minimum of 3 @ 120deg, 240deg & 360deg) to confirm depth of competent cement and good surface casing is found. 20. Flush conductor with water from the upper inspection holes while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 21. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined oh site prior to proceeding with accurate gas readings and fluid returns observed. b. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 22. Cut and remove additional conductor from this depth up. a. Prior to cutting conductor install continuous gas monitoring for LEL's from the conductor. b. 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. c. Two horizontal cuts(below landing ring and one at bottom of conductor section)and two vertical cuts will be required to remove the conductor. 23. Chip away excess cement and WellLock from the surface casing. Buff and prepare surface casing for inspection and welding. a. Once final patch length is determined,cut patch to required length. 24. Inspection department to UT the exposed surface casing. a. Areas to weld bands to for external patch to be identified marked and inspected on a grid to ensure competency for welds. b. The tubing tally lists the hanger as 2.99'followed by full 40'casing joints below the wellhead and the external patch will require bands to be welded above and below this connection so that the patch will be around the collar. c. If leak site can't be visually determined, use compressed air to pressure OA and spray bottles of soap to determine leak site is at the collar connection. 25. Install bands/rings for the upper and lower patch areas and weld circumferentially to the surface casing. a. Band material: A572 Grad50,thickness=5/8". 26. Install clamshell patc4 and weld circumferentially to the bands/rin s and vertically to the other patch half. < s a. Patch material:A572-13A Grade 50, ID=11-5/8", OD=12-1/8". �' ,4 °' b. Band material:A572 Grad50,thickness=5/8". 27. Inspect the welds to ensure competency. 1-Hs cr 28. Conduct an MIT-OA to 1000psi. _may ��'� /'�fns 29. Weld external alignment band to the conductor. 30. Weld on new conductor extension. a. New conductor material: 20",0.375"WT,A-53 31. Rebuild well cellar and backfill ground around conductor and cellar. a. Deconstructed cellar to be used if able to be salvaged. b. Non frost susceptible gravel will be used to backfill the excavation. During backfill operations the gravel will be placed in 6-12" lifts and compacted with jumping jacks within the trench • • Repair SC Leak Well: END 2-60 PTD: 193-083 Iiilcoro Alaska,LU API: 50-029-22375-00 shoring, or an excavator mounted compaction unit will be used aftercthe trench shoring has been pulled. C1 <k L1;) Tree &Wellhead 32. Verify tubing, IA and OA pressures are still Opsi. 33. Install SSV barrel. 34. Contingency—If a dry hole tree was installed. a. Close the master valve. b. Pressure test against the master valve to 300psi low and 4500psi high. c. Unbolt and remove the dry hole tree. d. Install upper production tree. e. Pressure test the upper tree assembly to 4500psi. Operations 35. Re-install flowline, instrumentation, and wellhouse. Slickline 36. RU SL unit. 37. Pressure test PCE to 300psi low/2100psi high. 38. RIH and pull 3-1/2" PXN Plug at 12,376' md. 39. RD SL unit. Attachment: Schematic `14 • • Endicott Unit Well: END 2-60 SCHEMATIC Last Completed: 1/30/1994 Hileorp Alaska,LLC PTD: 193-083 TREE&WELLHEAD RT Elev.:55.3'/BF Elev.:16.12' Tree 4-1/2",5000psi/Cooper Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead R4 !� OPEN HOLE/CEMENT DETAIL Surface 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole t♦' a Casing Leak 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole t n @11' CASING DETAIL t.' Size Type Wt/Grade/Conn Drift ID Top Btm BPF y. 1 #; 30" Conductor 48/H-40/N/A N/A Surface 110' N/A :q 10-3/4" Surface 45.5/J-55/BTC. 9.95" Surface 2,721' 0.0962 e 7-5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 10-3/4"'a a TUBING DETAIL 2 3-1/2" Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 I JEWELRY DETAIL No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) 3 2 3,691' GLM#7 3 6,211' GLM#6 4 8,350' GLM#5 5 9,397' GLM#4 4 6 10,317' GLM#3 7 10,993' GLM#2 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 5 10 12,299' Baker SABL-3 7-5/8"Packer 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID) 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID 6 WELL INCLINATION DETAIL Max Deviation is 49 deg.@±6,700' Angle at Top Perf:40 de.@ 12,615' 7 <Ma. PERFORATION DETAIL $ q Endicott Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status V,' 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 0-V 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open ' N/A 12,697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed 9 ! i l N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed ' a N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed GENERAL WELL INFO 0 41 9 API:50-029-22375-00-00 b= Drilled,Cased&Completed by Doyon 15 -1/30/1994 ' to f Perforate 6/20/1995 Perforate-5/8/1996 44 ,`'i ' 11f.l Y- Perforate-9/12/1996 l'2 Set Plug in SWS Nipple-8/26/2009 '/ oPull Plug from SWS Nipple-12/11/2014 * 13 Pull Plug and RTP-3/8/2015 I0p Perfs SAFETY NOTE: Iski H2S readings average 230 to 260 PPM on TOC@12860 A/L&gas injectors.Well requires a SSSV 4/29/1996 x4_ Squeezed Perfs 4 yg. . 7'? - FISH:Full Bore / , : r Spinner Cone© 7 5 8 1 ±12,917 TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Revised By:TDF 8/11/2016 STATE OF ALASKA I As k KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Pull Plug ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Cement OA to Surfaces 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development s Exploratory ❑ 193-083 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22375- RECEIVED 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0034633 DUCK IS UNIT MPI 2-60 AUG 1 2 ZOib 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool AOGCC 11.Present Well Condition Summary: �N Total Depth measured 13,010 feet Plugs measured 12,840 feet true vertical 10,361 feet Junk measured N/A feet Effective Depth measured 12,840 feet Packer measured 12,299 feet true vertical 10,228 feet true vertical 9,824 feet Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' N/A N/A Conductor 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Surface 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Production Perforation depth Measured depth See Attached Schematic 0 j� 2 0201 SCA g,+ f-N True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13-CR/NSCT 12,388' 9,895' 12,299(MD) 1,545(MD) Packers and SSSV(type,measured and true vertical depth) SABL-3 SSSV 9,824(TVD) 1,542(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,500 0 Subsequent to operation: 0 0 0 50 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [j Exploratory Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil s Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: t 3162 ' 2J p Contact Taylor Wellman �,` �� Email twellman(c�hilcorp.com Printed Name Mike Dunn Title Operations Manager Signature b — '*'a "lit'L dwylA Phone 777-8382 Date 8/11/2016 )t <te.?-1' 1/6 Form 10-404 Revised 5/2015 3/;e?C ' RBDMS 1,1.- AUG 1 5 2016 Submit Original Only • • Endicott Unit Well: END 2-60 , n SCHEMATIC Last Completed: 1/30/1994 PTD: 193-083 nil...,Alaska.LLA. TREE&WELLHEAD RT Elev.:55.3'/BF Elev.:16.12' Tree 4-1/2",5000psi/Cooper Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead 30"1 .., 1 �� OPEN HOLE/CEMENT DETAIL Surface 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole Casing Leak 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole @1r CASING DETAIL 1. Size Type Wt/Grade/Conn Drift ID Top Btm BPF c 1 30" Conductor 48/H-40/N/A N/A Surface 110' N/A 10-3/4" Surface 45.5/.1-55/BTC. 9.95" Surface 2,721' 0.0962 7-5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 10-3/4"A ► TUBING DETAIL 2 3-1/2" Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 JEWELRY DETAIL No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) 3 2 3,691' GLM#7 3 6,211' GLM#6 4 8,350' GLM#5 5 9,397' GLM#4 4 6 10,317' GLM#3 7 ' 10,993' GLM#2 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 5 10 12,299' Baker SABL-3 7-5/8"Packer 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID) ( 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID 6;1 WELL INCLINATION DETAIL Max Deviation is 49 deg.@±6,700' Angle at Top Perf:40 de.@ 12,615' 7 PERFORATION DETAIL Endicott Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 8 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open s N/A 12,697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed -;s N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed ' N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed GENERAL WELL INFO 9 API:50-029-22375-00-00 Drilled,Cased&Completed by Doyon 15 -1/30/1994 10 Perforate-6/20/1995 Perforate-5/8/1996 It11 Perforate-9/12/1996 12 Set Plug in SWS Nipple-8/26/2009 "1 A Pull Plug from SWS Nipple-12/11/2014 13 Pull Plug and RTP-3/8/2015 #I Open Peds SAFETY NOTE: H2S readings average 230 to 260 PPM on TOC©12,860 ', Squeezed Perfs A/L&gas injectors.Well requires a SSSV ri 4 " 4'''''V4 A FISH:Full Bare 0-q "^ , Spinner Cane @ 7-5/8 R." r. 0., : ±12,917 TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Revised By:TDF 8/11/2016 • • 111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 Pump Truck 50-029-22375-00-00 193-083 7/5/16 7/19/16 Daily Operations: 6/29/2016-Wednesday No activity to report. 6/30/2016-Thursday No activity to report. 7/1/2016- Friday No activity to report. 7/2/2016-Saturday No activity to report. 7/3/2016-Sunday No activity to report. 7/4/2016- Monday No activity to report. 7/5/2016-Tuesday T/I/0=1783/1450/20 OA inj. Pump 21 bbl.'s of DSL down OA. Start out at 3 bbl.'s/min @ 1,400psi increase rate to 5 bbls/min @ 3 bbls away. Pressure fell to 1,100psi @ 21 bbls away. Monitor OA psi for 1 4110 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 Pump Truck 50-029-22375-00-00 193-083 7/5/16 7/19/16 Daily Operations: 7/13/2016-Wednesday No activity to report. 7/14/2016-Thursday No activity to report. 7/15/2016- Friday No activity to report. 7/16/2016-Saturday No activity to report. 7/17/2016-Sunday No activity to report. 7/18/2016- Monday Rig up equipment, PJSM, PT surface equipment. Pump surfactant, at 2.4 bbls away, OA pressuring up to 1,700psi then OA lost all pressure and started getting 1 for 1 returns through the conductor.Pump 3 more bbls surfactant with direct communication to confirm surface casing leak appears to have worsened. Prep to change scope to Conductor top job. PJSM. Start top job into conductor to provide back pressure for 2nd attempt later. Start top job with AS1cement weighted to 15.65 ppg. Hesistate top job. — 1/2 bbls at a time to swap with diesel. End top job. ^ 3 bbls cement pumped into conductor. Cement is 1 ft. down from the flutes. SLB cleaning up equipment and rigging down. 7/19/2016-Tuesday Rigup Triplex to OA and attempt to pressure up with diesel following cement top job. 1 for 1 returns through SC leak.Top Job Unsuccessful. RDMO II • . VOF T„ � t.„,y/y�cv THE STATE Alaska Oil and Gas tib- ALAsKA Conservation Commission stom.-. -_-=_A -=== tt, _-- j— 333 West Seventh Avenue 1. GOVERNOR BILL WALKER ^ti., Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASICP Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager ,© 1 Hilcorp Alaska, LLC .., s,itt 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-60 • Permit to Drill Number: 193-083 Sundry Number: 316-328 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (1/41 "le-t4- ._ Cathy . Foerster Chair DATED this 2J day of June, 2016. RBDMS (,L' JUN Z 4 2016 • RECEIVED STATE OF ALASKA JUN 0 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 4/ 2_3/I 6 APPLICATION FOR SUNDRY APPROVALS ry r r 20 AAC 25.280 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: Cement OA to Surface❑✓ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 193-083 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22375-00-00 • 7. If perforating: 8,Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes ❑ No ❑., DUCK IS UNIT MPI 2-60 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0034633 ' Endicott Field/Endicott Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,010' 10,361' 12,840' 10,228' 2,100 12,840' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' N/A N/A Surface 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Production 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/13CR80 12,388' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SABL-3 7-5/8"Packer and SSSV 12,299MD/9,824TVD and 1,545MD/1,542TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 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: 6/15/2016 Commencing Operations: OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman T?"✓ Email twellman@hilcorp.com Printed Name / Mike Dunn Title Operations Manager Signature Phone 777-8382 Date 619/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. , C _ Q...- [i]Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No El Subsequent Form Required: / c', L r' ' RBDMS L SUN 2016 APPROVED BY / Approved by: P � t0 COMMISSIONER THE COMMISSION Date: _ 23_/ 341 o /rid �R l GIN4L, Submit Form ane Form 10-403 Revised 11/2015 r v I rfor 12 months from the date of approval. �/ ,,,�Attachments in Duplicate �-** C 9 /( „./SL`> 6 /c)./c, • • Repair SC Leak Well: END 2-60 PTD: 193-083 Hitcorp Alaska,LL' API: 50-029-22375-00 Well Name: END2-60 API Number: 50-029-22375-00 Current Status: SI Rig: N/A Estimated Start Date: June 15, 2016 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 193-083 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907)777-8547 (0) (509) 670-8001 (M) AFE Number: Well EZ Inputs Required: Yes Current Bottom Hole Pressure: —4166psi @ 10,000' TVD (Based on SBHPS on Sept 2008) Maximum Expected BHP: —4166psi @ 10,000' TVD (Based on SBHPS on Sept 2008) Max. Anticipated Surface Pressure: —2100psi (Based on max GL system pressure & passing No Flow test) Recent TWO Surface Pressures 300/1600/0 psi (Taken 5/4/16) Brief Well Summary: Well 2-60 is a gas lifted producer with a confirmed surface casing leak at 11.5' below the OA valve. The well is a high water cut (-92%) well that requires artificial lift to flow(confirmed w/ passing No-Flow test on 03/09/15). A WeIlLock treatment of the SCxConductor annulus was attempted on 3/12/16 and a passing N2 test to 600 psi was obtained but diesel was again observed in the annulus when well was RTP'd.Well has been shut in since 4/30/16. 08/16/09:Crude noted in conductor 08/18/09: MIT-OA Failed to 500 psi w/N2.At 400psi, bubbling observed and at 500psi first lowered 02%observed 08/23/09: MIT-OA Failed to 500 psi.At 500psi lowered 02%in flutes confirm SC leak to surface. 08/25/09:Set TTP @ 12376', MIT-T Passed to 3000 psi 12/11/09:CMIT-TxIA Passed to 3000 psi 12/19/09: MIT-OA w/N2. Pressure to 800psi with no change in 02%. 12/20/09: MIT-OA w/N2.At 1000psi,observed lowered 02%.SC leak strapped at 11.5' 03/06/10: Liquid Leak Rate down OA. Unable to psi up OA above 1480 psi 09/04/10: Liquid Leak Rate down OA.8 gpm @ 350 psi 09/16/10: Liquid Leak Rate down OA.0.35 bpm @ 950 psi, lost pressure above 1100 psi and LLR became 5 bpm @ 800 psi 10/31/11:CMIT-TxIA Passed to 3000 psi. i 11/20/11:Wellhead Seal Test of the tubing-Passed to 5000 psi, Replaced broken LDS 12/05/14: MIT-T to 3000psi—Passed, CMIT-TxIA to 3000 psi—Passed.- 02/27/15: MIT-T to 2958psi—Passed. CMIT-TxIA to 3122psi—Passed. 03/09/15: No-Flow Test—Passed.Well returned to production. 3/12/2016:WeIlLock Resin applied through flutes in conductor to repair surface casing leak. 3/20/2016: MIT-OA passed to 600 psi with N2. No returns 3/21/2016: Diesel observed in SCxConductor annulus, attempt to MIT-OA with diesel. Pressure up to 600 psi but observed returns in annulus. Follow up with Nitrogen and observe bubbles on the conductor wall. OA Status: Qpen shoe. OA fluid level near surface, displaced entirely with diesel. Estimated that Production Casing TOC at 4100', 1400' below SC shoe (^'340 bbls class G at .03825bpf in 7-5/8 by 9-7/8" annulus). Good injectivity confirmed on 09/16/10 w/5 bpm @ 800 psi. • • Repair SC Leak Well: END 2-60 PTD: 193-083 Hilcorp Alaska,Lb API: 50-029-22375-00 Est. OA volume OA volume = .03969 bpf* 2721' = 108 bbls 7-5/8 by 9-7/8"Open Hole annulus = .03825 bpf* 1380' = 53 bbls Maximum OA+OH Annular volume = 161 bbls SC Leak Depth/Rate: Leak was determined to be 11.5' below the OA valve. Leak rate was established at"9.6gpm @ 350 psi w/ diesel. During this test,the casing shoe broke down and later attempts to pump down the OA had injectivity down and out the casing shoe of 5 bpm @ 800psi. Later attempts had a vac truck taking returns from the surface casing x conductor annulus so a true leak rate could not be determined. Objective: Mitigate flow of hydrocarbons to surface through the SCxConductor annulus by cementing OA to surface. Procedure: Pre-Sundry Work Operations 1. Rig up pump truck to OA 2. Rig up vac truck with stinger in the SCxConductor annulus. Prepare to take returns off the annulus through the SC leak. 3. Pump diesel down the OA at max rate up to max pressure of 2000 psi to establish LLR. 4. Bleed IA to 0 psi. 5. Bleed OA to 0 psi. 6. Install OA companion Valve - Sundry Work(Approval required to proceed) Cementing 1. Rig up cementers to OA via a flanged union. 2. Rig up vac truck with stinger in the SCxConductor annulus. Preare to take returns off the annulus through the SC leak. 3. Pump the following down the OA at max rate up to max pressure of 2. 000 psi. Track pump rate vs pressure throughout displacement: ***Note: Cement volumes based on casing-casing and casing-openhole estimates only. Actual volumes pumped will vary. Aggregate may be added to cement based on injectivity response.*** 1) 20 bbls of surfactant preflush 2) 140 bbls of Class G cement 3) 10 bbls Arctic Set 1 4. Shut down pumps and leave the well SI. 5. Flush across OA valves with water to retain function of OA valve and pressure gauges. Do not flush down the OA to maximize cement height. 6. Replace OA valves and gauges 7. RDMO cementers Operations 1. After cement is cured,verify IA and OA pressure at 0 psi then remove valve. 2. Tag and record cement top in the OA with respect to OA valve. 3. Replace OA valve • Repair SC Leak Well: END 2-60 PTD: 193-083 Ililcurp Alaska,LL, API: 50-029-22375-00 ***Contingency—Top Job*** If OA cement top greater than 5' below OA valve: 1. Pump SqueezeCrete or epoxy resin in the OA until clean 1:1 returns are observed. Take returns from OA companion valve to a grounded bucket or tank. 2. Flush across OA valves with water to retain function of OA valve and pressure gauges. Do not flush down the OA to maximize cement height. 3. Rigup nitrogen bottle manifold and pressure up to 2000 psi max or until SqueezeCrete or epoxy resin returns are observed in conductor. 4. RDMO Operations 5. Once final cement job is cured, RTP and monitor for 28 days for signs of SCxConductor returns Attachment: Schematic ` 14 0 * Endicott Unit Well: END 2-60 SCHEMATIC Last Completed: 1/30/1994 Hamra Alaska,LLC PTD: 193 083 TREE&WELLHEAD RT Elev.:55.3'/BF Elev.:16.12' Tree 4-1/2",5000psi/Cooper Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead 30' 41 W`. -- cp�l� ( OPEN HOLE/CEMENT DETAIL 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole CASING DETAIL � Size Type Wt/Grade/Conn Drift ID Top Btm BPF 1 30" Conductor 48/H-40/N/A N/A Surface 110' N/A 10-3/4" Surface 45.5/1-55/BTC. 9.95" Surface 2,721' 0.0962 7-5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 10-3/4" ' _ I TUBING DETAIL 2 / i 3-1/2" I Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 JEWELRY DETAIL 7 :Vs A. 1O / I No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) . 0 3 1 7 61r 3 / 2 3,691' GLM#7 ' I 3 6,211' GLM#6 4 8,350' GLM#5 / 5 9,397' GLM#4 4 / 6 10,317' GLM#3 7 10,993' GLM#2 / 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 5 10 12,299' Baker SABL-3 7-5/8"Packer i 11 12,330' SWS Nipple(2.75"ID) LA(d`'' 12 12,376' SWS Nipple(2.75"ID) , fi I la 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID 6 fir° WELL INCLINATION DETAIL Max Deviation is 49 deg.@±6,700' Angle at Top Peri:40 de.@ 12,615' 7 PERFORATION DETAIL ' Endicott Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 8 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open N/A 12,697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed GENERAL WELL INFO e 9 API:50-029-22375-00-00 Drilled,Cased&Completed by Doyon 15 -1/30/1994 10 Perforate-6/20/1995 Perforate-5/8/1996 - 11 Perforate-9/12/1996 12 Set Plug in SWS Nipple-8/26/2009 -- Pull Plug from SWS Nipple-12/11/2014 13 • Pull Plug and RTP-3/8/2015 'Open Peds SAFETY NOTE: H25 readings average 230 to 260 PPM on TOC @ 12,86a 1 A/L&gas injectors.Well requires a SSSV 4/29/1996 r Squeezed Perfs i '. J Full Bore ,-3/0'i,„ , rt",a 'o Spinner Cone @ ±12,917' TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(WD) Revised By:TDF 2/17/2016 STATE OF ALASKA ALPIlk OIL AND GAS CONSERVATION COMI ION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Pull Plug ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ SC Repair w/WellLock 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 193-083 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22375-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ' ADL0034633 DUCK IS UNIT MPI 2-60 ` v 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Endicott Field/Endicott Oil Pool MAY 0 6 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 13,010 feet Plugs measured 12,840 feet true vertical 10,361 feet Junk measured N/A feet Effective Depth measured 12,840 feet Packer measured 12,299 feet true vertical 10,228 feet true vertical 9,824 feet Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' N/A N/A Conductor 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Surface 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Production I /� Perforation depth Measured depth See Attached Schematic_ I�E JUN 1 5 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13-CR/NSCT 12,388' 9,895' 12,299(MD) 1,545(MD) Packers and SSSV(type,measured and true vertical depth) SABL-3 SSSV 9,824(TVD) 1,542(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 2,100 284 Subsequent to operation: 68 3,821 2,131 1,950 306 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ DevelopmentLI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 444 R&etre 316-129 Contact 4-o r Taylor Wellman Cry email twellman@hilcorp.com Printed Name Mi - Dunn Title Operations Manager Signature LLL Phone 777-8382 Date 5/5/2016 , 54r lb Form 10-404 Revised 5/2015 RBDMS Ll2016 . gv 1 0 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 N/A 50-029-22375-00-00 193-083 2/24/16 4/30/16 Daily Operations. :. , 2/24/2016-Wednesday Use power washer and vac truck to clean out surface casing by conductor annulus. 2/25/2016-Thursday Use power washer and vac truck to clean out surface casing by conductor annulus. 2/26/2016-Friday Use power washer and vac truck to clean out surface casing by conductor annulus. 2/27/2016-Saturday Use power washer and vac truck to clean out surface casing by conductor annulus. 2/28/2016-Sunday No activity to report. 2/29/2016- Monday No activity to report. 3/1/2016-Tuesday No activity to report. • • 1;1Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 N/A 50-029-22375-00-00 193-083 2/24/16 4/30/16 Daily Operations: 3/2/2016-Wednesday No activity to report. 3/3/2016-Thursday No activity to report. 3/4/2016- Friday No activity to report. 3/5/2016-Saturday No activity to report. 3/6/2016-Sunday No activity to report. 3/7/2016- Monday No activity to report. 3/8/2016-Tuesday Depart Endicott to pickup Microsand. Micro sand to be used to control the exothermic reaction of WeIlLock if the need arises. Depart Halliburton for Endicott.Arrive at Endicott; Check in with Safety Officer. Start mixing R1 and R2. Check Wellhead temperatures prior to adding H1 and A2.Add H1 and A2.Take batch samples of mixed WeIlLock.Take batch samples of 1st 3 gallons.Transport 3 gallons WeIlLock to 02-60 and apply. Measure Temperature of WeIlLock at 73 degF. Start Mixing R1 and R2 for 2nd 3 gal batch. Add H1.Add A2. Take batch samples of mixed WeIlLock. Transport 3 gallons Welllock to 02-60. Pour WeIlLock into Conductor Annulus. Start Mixing R1, R2 and Microsand for 3rd batch.Add 13.8 lbs. of Microsand to 3 gallons of WeIlLock. Add H1. Add A2. Transport 3 gallons Welllock to 02-60/Pour WeIlLock into Conductor Annulus. Clean Mixing Equipment. Monitor temps every half hour through the night. • I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 N/A 50-029-22375-00-00 193-083 2/24/16 4/30/16 Daily Operations: 3/9/2016-Wednesday Monitor Well Lock temperatures/set in conductor annuls. Apply tarp over 1/2 of Well Head to increase temperature in SCxConductor annulus. Continue monitoring temps. 3/10/2016-Thursday Monitoring temperatures/Well Lock. 1st stage of WeIlLock Set. Prepare to Mix WellLock 2nd state. Start Mixing 1st batch of R1, R2 and Microsand. Check Well House Temp.Stopped mixing R1, R2, and Microsand. Check on temp of Well House. Add H1. Add A2.Take batch samples of mixed WellLock. Collect sample of mixed WeIlLock. Transport 3 gallons Welllock to 02-60. Pour into conductor annulus. Start Mixing 2nd batch of 2nd stage. Mix R1, R2 and Microsand. Check Well House Temp. Stopped mixing R1, R2, and Microsand. Check on temp of Well House. Add H1. Add A2. Take batch samples of mixed WeIlLock. Collect sample of mixed Transport 3 gallons Welllock to 02-60. Pour into conductor annulus. 3/11/2016- Friday Start Mixing 3rd batch for 2nd stage of WeIlLock. Mix R1, R2 and Microsand. Check Well House Temp. Stopped mixing R1, R2, and Microsand. Check on temp of Well House.Add H1. Add A2.Take batch samples of mixed WeIlLock. Collect sample of mixed WeIlLock. Transport 3 gallons Welllock to 02-60. Pour into conductor annulus. Start Mixing 4th batch for 2nd stage of WeIlLock. Mix R1, R2 and Microsand. Check Well House Temp. Stopped mixing R1, R2, and Microsand. Check on temp of Well House. Add H1. Add A2.Take batch samples of mixed WeIlLock. Collect sample of mixed WeIlLock. Transport 3 gallons Welllock to 02-60. Pour into conductor annulus. Monitor temps on the hour. Determined at this point that the exothermic reaction is no longer a concern. WeIlLock resin has dropped from high temp of 1_20 degrees down to 103. WeIlLock set. Wellsite suprevisor confirms with HES and had verified that the WeIlLock had indeed set;Collect Leftover Materials and Equipment. RDMO 3/12/2016-Saturday No activity to report. 3/13/2016-Sunday No activity to report. 3/14/2016- Monday No activity to report. 3/15/2016-Tuesday No activity to report. • I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-60 N/A 50-029-22375-00-00 193-083 2/24/16 4/30/16 Daily Operations: 3/16/2016-Wednesday No activity to report. 3/17/2016-Thursday No activity to report. 3/18/2016-Friday Pressure up OA to 620 psi. Used 1K psi of 2K bottle. Monitor for N2 returns at flutes for 15 minutes. No N2 measured. OA at 600 psi . Pressure OA to 625 and monitor for N2 at flutes. No N2 measured. Well POP. No N2 measured. OA a@ 90 psi. No fluid in SCxC annulus. 3/19/2016-Saturday No activity to report. 3/20/2016-Sunday 8" of diesel measured in SCxC annulus. Shut in well. 3" of diesel measured in SCxC annulus. Continue to measure diesel level. 3" of diesel in SCxC annulus at end of monitoring. 3/21/2016- Monday Pressure up OA to 620 psi. Used 1K psi of 2K bottle. Monitor for N2 returns at flutes for 30 minutes. No N2 measured. OA at 600 psi . Pump diesel to check for injectabilty.Pump at 235 psi catch pressure with 2 bbl away. Shut down at 630 psi. Find returns bleeding into SCxC annulus. Bleed OA to 0 psi. Pressure with N2 to 630 psi. Observe bubbles on the Conductor wall. Bleed to 0 psi. (� 3/22/2016-Tuesday No activity to report. IP • OF TtJ • ,e,l'Ay/�.t.?, THE STATE Alaska Oil and Gas ofLASI�:A Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager SEAMED k 0 4 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-60 Permit to Drill Number: 193-083 Sundry Number: 316-129 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster �,�_ Chair DATED this 2- cci y of February, 2016. RBDMS t,L FEB 2 6 2016 0 0RECEIVED STATE OF ALASKA FEB 7 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION SIS 2./Z4-//,‘ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing r-J / Other: SC Repair WeIlLock 0 . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 193-083 3.Address: Stratigraphic ii! Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22375-00-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes ❑ No 0 DUCK IS UNIT MPI 2-60?U13 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0034633 Endicott Field/Endicott Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,010' , 10,361' ' 12,840' 10,228' 2,100 12,840' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' NIA N/A Surface 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Production 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#!13CR80 12,388' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SABL-3 7-5/8"Packer and SSSV 12,299MD/9,824TVD and 1,545MD/1,542TVD 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: ;/_ /6 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman Tj',./ Email twellman(@hilcorp.com Printed Name Mike Dunn Title Operations Manager resr t� Signature V�+k Phone 777-8382 Date 2i 16 ,I. `_e. -, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ c-(-4-125-Other: t. J 3 XA��:^b., ---f/ �.a. C-�-,. �lz:<�.ti-•i ea.it-1C�1' p -_ ) ✓'� !1 1 / Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ©' Subsequent Form Required: / 0 `I 044 RBDMS 1,L FEB 2 6 201E 2167 �� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2,—2_,4-....4,�'�., ?‘„ A -..R .—Uzi OaiGiiNAL Submit Form and Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate • Repair SC Leak Well: END 2-60 • PTD: 193-083 uik•orp Alaska,LL' API: 50-029-22375-00 Well Name: END2-60 API Number: 50-029-22375-00 Current Status: Online Rig: N/A Estimated Start Date: February 21, 2016 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 193-083 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: —4166psi @ 10,000' TVD (Based on SBHPS on Sept 2008) Maximum Expected BHP: —4166psi @ 10,000' TVD (Based on SBHPS on Sept 2008) Max. Anticipated Surface Pressure: —2100psi (Based on max GL system pressure & passing No Flow test) Brief Well Summary: Well 2-60 gas lifted producer that has a confirmed surface casing leak at 11.5' below the OA valve. The well is a high water cut (-92%) well that requires artificial lift to flow(confirmed w/ passing No-Flow test on 03/09/15). The well currently operates under Sundry# 315-053 and is online. 08/16/09: Crude noted in conductor / 08/18/09: MIT-0A Failed to 500 psi w/ N2. At 400psi, bubbling observed and at 500psi first lowered 02 observed 08/23/09: MIT-OA Failed to 500 psi. At 500psi lowered 02 % in flutes confirm SC leak to surface. 08/25/09: Set TTP @ 12376', MIT-T Passed to 3000 psi 12/11/09: CMIT-TxIA Passed to 3000 psi 12/19/09: MIT-OA w/ N2. Pressure to 800psi with no chang0n-02 %. - 12/20/09: MIT-OA w/N2. At 1000psi, observed lowered 02 %. SC leak strapped at 11.5'`; 03/06/10: Liquid Leak Rate down OA. Unable to psi up OA above psi- 09/04/10: Liquid Leak Rate down OA. 8 gpm @ 350 psi 09/16/10: Liquid Leak Rate down OA. 0.35 bpm @ 950 psi, lost pressure above 1100 psi and LLR became 5 bpm @ 800 psi 10/31/11: CMIT-TxIA Passed to 3000 psi. 11/20/11: Wellhead Seal Test of the tubing- Passed to 5000 psi, Replaced broken LDS 12/05/14: MIT-T to 3000psi—Passed, CMIT-TxIA to 3000 psi—Passed. 02/27/15: MIT-T to 2958psi—Passed. CMIT-TxIA to 3122psi—Passed. 03/09/15: No-Flow Test—Passed. Well returned to production. OA Status: Open shoe. Est.TOC 1000+' below SC. Good injectivity confirmed on 09/16/10 w/5 bpm @ 800 psi. SC Leak Depth/Rate: Leak was determined to be 11.5' below the OA valve. Leak rate was established at—9.6gpm @ 350 psi w/ diesel. During this test,the casing shoe broke down and later attempts to pump down the OA had injectivity down and out the casing shoe of 5 bpm @ 800psi. Later attempts had a vac truck taking returns from the surface casing x conductor annulus so a true leak rate could not be determined. • • Repair SC Leak Well: END 2-60 PTD: 193-083 Hilcorp Alaska,LL API: 50-029-22375-00 Objective: Mitigate flow of hydrocarbons to surface through the SCxConductor annulus. �f l; • b plc Timing: Scheduled for late February 2016. The current timing for repair under Sundry#315-053 is fo the well to be repaired or shut in on February 20, 2016.The proposed procedure would allow the well to remain online untilL the scheduled repair can be conducted or an alternative repair option (excavation &external patch) can be completed in late ice road season (approx.April 1, 2016). The timing is based on the following reasoning for the excavation repair: 1. Minimal amount of water influxing into the excavation. The frozen sea should provide the minimal amount of water to be handled while the excavation is in place based on best practices shared from other operators. 2. Extreme temperatures. The repair time in late ice road season vs. early ice road season will allow for avoiding the worst months in terms of extreme cold for exposure to personnel. Procedure: 1. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. Use of a steam wand washing the annulus with water and solvent will be conducted. b. The conductor is 20"x30" insulated conductor,48#, H-40. 2. Place heater in wellhouse circulating air through the conductor to dry it out of any fluids. 3. Use a boroscope down the conductor to inspect 10-3/4" surface casing for corrosion and leak site. 4. Contingency: If there is not a hard bottom in the conductor add in steps for a top job to be pumped. 5. Mix WeIlLock as per recommended volumes, concentration, and pumping procedure to place a volume (minimum of 11.6gal or 1') into the lower portion of the conductor. (6c.ceos.s /«i) a. The SCxConductor volume=0.276bpf or 11.fgpt 6. Allow WeIlLock to cure for 2-3 days minimum. r�5r ti C_ ) /&rj`f a. Monitor temperature during curing phase. �;,,, cpo A . 7. Pressuring of the OA to 600psi w/ N2 will be conducted with N2 bottler j..c Nev a. Passing Criteria: No visible indication of N2 returns to the conductor and no reduction in 0 41 measured 02 levels from the conductor. This is due to the open casing shoe and an appropriate pressure test with fluid will be unattainable. 8. Contingency: Repeat steps 5-7 with an additional volume of WeIlLock (maximum treatment volume is ^'133 gal). Attachment: Schematic • Endicott Unit Well: END 2-60 ' II • SCHEMATIC Last Completed: 1/30/1994 Il ileorp Alaska,LLC o,,,A';)s)' ` PTD: 193-083 TREE&WELLHEAD RT Elev.:55.3'/BF Elev.:16.12'( Tree 4-1/2",5000psi/Cooper fi ��, Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead 3°" V,„0OPEN HOLE/CEMENT DETAIL C' 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole i ± h� 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole 4. € A IC ,y1 4 CASING DETAIL i "' Size Type Wt/Grade/Conn Drift ID Top Btm BPF St, L 1 4, 30" Conductor 48/H-40/N/A N/A Surface 110' N/A r , 'r 10-3/4" Surface 45.5/1-55/BTC. 9.95" Surface 2,721' 0.0962 i. l O" 7-5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 10-3/4" TUBING DETAIL 2 3-1/2" Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 JEWELRY DETAIL No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) ,I 3 2 3,691' GLM#7 3 6,211' GLM#6 4 8,350' GLM#5 5 9,397' GLM#4 4 6 10,317' GLM#3 7 10,993' GLM#2 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 5 10 12,299' Baker SABL-3 7-5/8"Packer 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID) 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID 6 WELL INCLINATION DETAIL Max Deviation is 49 deg.@±6,700' t ei .; Angle at Top Perf:40 de.@ 12,615' 7 4 u s PERFORATION DETAIL Endicott Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 8 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 4' 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open l N/A 12,697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed ,, N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed s N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed to " GENERAL WELL INFO API:50-029-22375-00-00 urs; ile. 9 t,,.1Drilled,Cased&Completed by Doyon 15 -1/30/1994 tt ' :10 Perforate-6/20/1995 Perforate-5/8/1996 E ;11 .1" Perforate-9/12/1996 12 Set Plug in SWS Nipple-8/26/2009 'I' Pull Plug from SWS Nipple-12/11/2014 13 Pull Plug and RTP-3/8/2015 -• jOpen Perts SAFETY NOTE: H2S readings average 230 to 260 PPM on TOC@12,860' ,,,i. A/L&gas injectors.Well requires a SSSV 4/29/1996 s 1 Squeezed Perfs 4.' FISH:Full Bore ''''°' . ' „` Spinner Cone @ 7-5/6 1, .stt.__<a. _' ±12,917 ' TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Revised By:TDF 2/17/2016 STATE OF ALASKA ALQA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Pull Plug ❑., Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Return to Production ❑., 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 2Exploratory ❑ 193-083 ��4'" 3.Address: Stratigraphic❑ Service ❑ 6.API Number: /A-4)--- 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22375-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: E C E I V E D y ` ADL0034633 DUCK IS UNIT MPI 2-60/U13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool FEB 17 2016 11.Present Well Condition Summary: AOGCC ,I \V GC Total Depth measured 13,010 feet Plugs measured 12,840 feet true vertical 10,361 feet Junk measured N/A feet Effective Depth measured 12,840 feet Packer measured 12,299 feet true vertical 10,228 feet true vertical 9,824 feet Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' N/A N/A Conductor 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Surface 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Production Perforation depth Measured depth See Attached Schematic SCANNED MAR 0 8 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13-CR/NSCT 12,388' 9,895' 12,299(MD) 1,545(MD) Packers and SSSV(type,measured and true vertical depth) SABL-3 SSSV 9,824(TVD) 1,542(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,350 0 Subsequent to operation: 19 60 2,308 2,000 305 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-053 Contact Taylor Wellman 1jJ Email twellman(a�hilcorp.com Printed Name Bo York Title Operations Engineer Signature7M, —. Phone 777-8345 Date 2/17/2016 A02 -,2d--lG Form 10-404 Revised 5/2015 M '7"l ABDMS 1-L' FEB 1 8 2016 Submit Original Only ' 14 • • Endicott Unit 60 Well: END 2- SCHEMATIC Last Completed: 1/30/1994 Ililearp Alaska,LLC PTD: 193-083 TREE&WELLHEAD RT Elev.:55.3'/BF Elev.:16.12' Cj GaS' Tree 4-1/2",5000psi/Cooper 64% Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead A iii �� OPEN HOLE/CEMENT DETAIL 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole CASING DETAIL V. { Size Type Wt/Grade/Conn Drift ID Top Btm BPF LA, 1 � r 1 30" Conductor 48/H-40/N/A N/A Surface 110' N/A , 10-3/4" Surface 45.5/1-55/BTC. 9.95" Surface 2,721' 0.0962 1 7-5/8" Production 29.7/NT95HS/NSCC 6.875" Surface 12,998' 0.0459 i i. _ 10-3/4"10 TUBING DETAIL 2 3-1/2" Tubing 9.2/13-CR/NSCT 2.992" Surf 12,388' 0.0087 JEWELRY DETAIL No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) 3 2 3,691' GLM#7 3 6,211' GLM#6 4 8,350' GLM#5 5 9,397' GLM#4 4 6 10,317' GLM#3 I 7 10,993' GLM#2 8 11,700' GLM#1 9 12,250' SWS Nipple(2.75"ID) 5 10 12,299' Baker SABL-3 7-5/8"Packer 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID) 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID 6 WELL INCLINATION DETAIL i'. a Max Deviation is 49 deg.@±6,700' Angle at Top Perf:40 de.@ 12,615' 7 *, PERFORATION DETAIL 1 Endicott Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 441 t, 8 ' 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 3C4/3C3 12,690' 12,720' 10,127 10,150' 10' 6/20/1995 Open N/A 12,697' 12,717' 10133' 10,147' 20' 1/29/1994 Squeezed N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed GENERAL WELL INFO F ; 9 API:50-029_223:51:00011:30830: 2237 -00 00 A Drilled,Cased&Completed by Doyon 15 -1/30/1994 10 Perforate-6/20/1995 r Perforate-5/8/1996 l l Perforate-9/12/1996 ;12 Set Plug in SWS Nipple-8/26/2009 Pull Plug from SWS Nipple-12/11/2014 13 Pull Plug and RTP-3/8/2015 A Open Parrs SAFETY NOTE: 74. H2S readings average 230 to 260 PPM on TOC©12,86(Y , . I A/L&gas injectors.Well requires a SSSV 4/29/1996 *. t Squeezed Pals x ." 0 FISH:Full Bore r"' a`" ,;' Spinner Cane @ 7-5/8' m, „„ ±12,917 TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Revised By:TDF 2/17/2016 • • Hilcorp Alaska, LLC Ilileorp AIa ka, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 2-60 50-029-22375-00-00 193-083 2/18/2015 3/8/2015 Daily Operations: 2/18/15-Wednesday DRIFTED TO TOP OF BBE W/2.84"CENT TO 1545' MD. PULL 3.5" BBE (SER#NBB-312) FROM 1545' MD. RAN 3.5" BRUSH & 2.72" GAUGE RING WORKING BRUSHED NIPPLES FROM 12200' SLM OUT TT TO 12,380'SLM .SET 3.5" PX PLUG BODY(4 x 3 1/16" EO,Z ports) @ 12343'SLM/12376' MD. LDFN 2/19/15-Thursday RAN 3.5" CHECK SET TO 12343'SLM/12376' MD.GOOD SET ON PLUG BODY.SET PX PRONG ( 1 3/4" FN, OAL 84")@ 12343' SLM/12376' MD. PERFORMED DRAW DOWN TEST, (T/I/0-2050/1560/0) BLEED TUBING DOWN TO 1650 PSI,AND HOLDING (T/I/0-1650/1560/0). PULL 1.5"S/O FROM STA#5 @ 8328'SLM/8350' MD. 2/21/15- Friday Loaded IA taking returns up the tubing down the FL w/10 bbl neet spear, 293 bbls of seawater and 80 bbls of diesel. U- tube Diesel from IA to tubing for freeze protect. Bled 2 bbls down Flowline for FP. Final WHP T/I/0 250 250 0. RDMO. 2/22/15-Saturday SET 1.5"S/O IN ST#5 @ 8350' MD. MIT-T TO 2500 PSI. PASSED, LOST 134 PSI IN FIRST 15 MIN & 19 PSI IN SECOND 15 MIN FOR A TOTAL OF 153 PSI IN 30 MINUTES. RDMO. 2/26/15=Sunday Passing AOGCC witnessed MIT-T and CMIT-TxIA to 3000 PSI. • 2/27/15-Monday • INITIAL T/I/0=250/0/0 PSI. PRESSURE TEST PCE TO 300PS1 LOW/2300PS1 HIGH. PULLED PX PRONG W/1-3/4" FN FROM 12328'SLM PULLED 3-1/2 PX PLUG FROM 12337'SLM RD SL UNIT. 3/8/15-Tuesday Complete AOGCC witnessed passing No Flow Test. • • RECEIVEDPost Office Box 244027 g Anchorage,AK 99524-4027 Hilcorp Alaska,LLC ,JUL. 3 0 201` 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 (V' Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 %WED AUG 2 3 2016 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 152— Q Anchorage, AK 99501 S/ ,� CJ 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 "I" 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 I API_WeIINo I PermitNumberl WellName I WellNumber I WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-288/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E • ti OF riff, �w...\ j�,s� THE STATE Alaska Oil and Gas "..,1...-- -- em '� ofAI4AsKA Conservation Commission k4ifittvelpz.t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 O"ALAS'11. Fax 907.276 7542 www aogcc.alaska.gov June 4, 2015 Mr. Taylor Wellman Operations Engineer—Northstar& Endicott Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 �l&E) .ft)r\. 0 9 J. RE: No-Flow Verification �Cp► Duck Island Unit 2-60/U13 PTD 1930830 Dear Mr. Wellman: On March 9, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Duck Island Unit well 2-60/U13 located on the Endicott Main Production Island, offshore North Slope. The well is operated by Hilcorp Alaska, LLC (Hilcorp) and has been shut in since August 2009 with a known shallow surface casing leak. This no-flow test was required as an approval condition for restarting production from Duck Island Unit 2-60/U13 — reference Sundry approval 315-053. Additional safeguards were imposed by the AOGCC's Sundry approval. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-02A — was rigged up on Duck Island Unit 2-60/U 13 prior to the test. The well had been lined up and flowing to an atmospheric bleed trailer for more than 12 hours prior to the start of the no-flow test. The well was shut in for 1 hour followed by a series of flow monitoring and subsequent shut in periods over a 5-hour test. Resulting flow rates (oil and gas) were below the regulatory limits, passing the no-flow test. AOGCC granted verbal approval to restart production March 10, 2015. In addition to allowing the well to be placed on production, AOGCC also authorizes Hilcorp to produce Duck Island Unit 2-60/U 13 without a subsurface safety valve based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265 and Sundry Approval 315-053. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in Duck Island Unit 2-60/U 13 will necessitate a subsequent no flow test. Mr.Taylor Wellman June 4,2015 Page 2 of 2 Sincerely, tit James B. Regg Petroleum Inspection Supervisor ecc: Wyatt Rivard (Hilcorp) P. Brooks AOGCC Inspectors p117 X73 - 0i(3 Loepp, Victoria T (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, June 03, 2015 2:48 PM To: Regg,James B (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: End 2-60 (PTD 193-083) No Flow Test per Sundry 315-053 Follow Up Flag: Follow up Flag Status: Flagged Jim, Thank you for the quick response. Please address it to Taylor Wellman. Taylor Wellman Operations Engineer—Northstar & Endicott Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 SCANNED JUN 1 0 2015 Thanks, Wyatt Rivard I Well Integrity Engineer U: (90 7) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Harm? 1.1,(: From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Wednesday, June 03, 2015 2:38 PM To: Wyatt Rivard Cc: Loepp, Victoria T(DOA) Subject: RE: End 2-60 (PTD 193-083) No Flow Test per Sundry 315-053 Who should the letter be addressed to? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 1 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information trom the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Friday, May 29, 2015 8:52 AM To: Wyatt Rivard Cc: Regg, James B (DOA) Subject: RE: End 2-60 (PTD 193-083) No Flow Test per Sundry 315-053 Yes,we will get back to you on Monday- From: Wyatt Rivard [mailto:wrivard@ahilcorp.cot ] Sent: Thursday, May 28, 2015 3:51 PM To: Loepp, Victoria T(DOA) Subject: End 2-60 (PTD 193-083) No Flow Test per Sundry 315-053 Hello Victoria, I wanted to follow up on the no flow approval letter for Endicott 2-60(PTD 193-083).A no flow test was conducted in March as per sundry 315-053 and email approval was given to flow the well on 10Mar15 based on the test results but I don't have a record of an approval letter being received on our end. Is it possible to see if a formal approval was sent? Thanks, Wyatt Rivard ,Nell Integrity Engineer 0: (907) 777-6347 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 llikr� ,Aliou4a 11.14: 2 Pro 193 -D 3 Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, March 10,2015 3:43 PM To: Loepp,Victoria T(DOA) Subject: RE: End 2-60(PTD 193-083, Sundry 315-053) Return to Production Follow Up Flag: Follow up Flag Status: Flagged Victoria, Just wanted to say thank you again for sitting and talking with us today and for such a quick turn around on this. Thank you, Taylor Taylor \\'ellniaii Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 SCANNED ltAk 3 9 f iiil, Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, March 10, 2015 3:29 PM To: Taylor Wellman Subject: End 2-60 (PTD 193-083, Sundry 315-053) Return to Production Taylor, Approval is granted to return this well to production without a SSSV given the passing no flow test assuming the remaining conditions on the approved sundry have been met.An approval letter for the no flow test/SSSV will follow later this week. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp a(�alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 Loepp. Victoria T (DOA) From: Regg,James B (DOA) Sent: Tuesday, March 10, 2015 3:18 PM To: Loepp,Victoria T(DOA) Subject: RE: End 2-60 (PTD 193-083) Passing No Flow Test Follow Up Flag: Follow up Flag Status: Flagged Got a summary of test from Matt, and should see formal report later this week. Endicott 2-60 is ok to flow without SSSV. I will follow up with letter after I receive Matt's report. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Tuesday, March 10, 2015 2:54 PM To: Regg, James B (DOA) Subject: End 2-60 (PTD 193-083) Passing No Flow Test Hi Jim- Hilcorp indicated the no flow test is complete(Matt witnessed)and you should be getting results very soon. Let me know when "the approval letter" is going out. They are ready to return this well to production Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loeppa,alaska goy CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ezj t DATE: 3/9/2015 P. I. Supervisor FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector Duck Island Unit 2-60/U13 Hilcorp PTD 1930830 3/912015: On arrival to Endicott I met with Hilcorp's Senior Operator. We discussed how the no-flow meter was rigged up and how I wanted to test it. They told me that well 2-60 had been opened to atmosphere for over 12 hours. The pressure gauge and the flow meter were rigged up to bleed trailer. Asked operator if well had issues bleeding down periodically or bringing up small amounts of fluid —there were none. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:30 0/0/0 0 0 Initial; well shut in 10:00 3/0/0 0 0 10:30 5.3/0/0 1000+ 0 Opened well; bled to 0 SCFH < 1 Min 11:00 3.8/0/0 0 0 Shut in 11:30 6.0/0/0 - 0 0 12:00 7.9/0/0 0 0 13:00 9.6/0/0 1000+ Trace Opened well; bled to 0 SCFH < 1 Min Pressures are T/IA/OA Summary: The well was opened to flow after one hour of shut in. Initial flow meter gas rate was just in excess of 10 x 100 standard cubic feet per hour (1000 scfh). Flow was bled down to 0 scfh in less than 1 minute after opening up the well. There were no liquids produced. Test results for Duck Island Unit (Endicott) 2-60/U13 appear to meet the no flow test criteria for removal of the SSSV. $CANNED MAY 2 2 2015 2015-0309 No-Flow DIU 2-60 mh.docx Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 03,2015 TO: Jim Reggc� o 2/ P.I.Supervisor ( f't SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-60/U13 FROM: Jeff Jones DUCK IS UNIT MPI 2-60/U13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry,Tee-- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-60/U13 API Well Number 50-029-22375-00-00 Inspector Name: Jeff Jones Permit Number: 193-083-0 Inspection Date: 2/27/2015 Insp Num: mitJJ150228063153 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min N 2-60/U13 1- 1 N -- - 9824 b T 755 3090 2979 ' 2958 ' - Well,_ 193os3o Type Inj TVD � Tubing � — 1 SPT 3000 - 419 480 483 490 PTD Type Test Test psi IA Interval-POTHER 1P/F P _1—OA 0 o o — — Notes: MIT-T per sundry 315-053.TTP set C 12343'SLM to facilitate test (Ct✓�y Wek (1 0 l) SCANNED Tuesday,March 03,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Reggr".1.- fl DATE: Monday,March 02,2015 P.I.Supervisor . ` f 1 41 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-60/U13 FROM: Jeff Jones DUCK IS UNIT MPI 2-60/U13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry CP---- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-60/U13 API Well Number 50-029-22375-00-00 Inspector Name: Jeff Jones Permit Number: 193-083-0 Inspection Date: 2/27/2015 Insp Num: mitJJ150228063704 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 2-60/U13 • Type Inj N-ITVD 7 9824 - Tubing 2500 3467 3445 j 3437 1 PTD-1 1930830 - Type Test SPT"Test psi 3000 - IA 452 3153 3131 1 3122 t Interval ;OTHER— — P/F 1 P ' j OA o 1 o 0 a Notes: CMIT.T X IA per sundry 315-053 • SCANNED i„,_^_: . ,, Monday,March 02,2015 Page 1 of 1 OF ry '(/, „w\��y,�s, THE STATE Alaska Oil and Gas = 7 of T Conservation Commission �"� � Al ftJ(ft �;tom'x='itritt333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 OF ALAS�� r- 6 b ;\\1- Fax. 907 276 7542 E© r_C www.aogcc alaska goy Taylor Wellman q3 Operations Engineer 0 Hilcorp Alaska, LLC 1613 qt 3 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, Duck Island Unit MPI 2-60/U13 Sundry Number: 315-053 Dear Mr. Wellman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F erster Chair DATED this 2Ay of February, 2015 Encl. i • • RECEIVED • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 4 2015 APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: Return to Production Q • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 193-083 • 3.Address: Stratigraphic EI Service CI6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22375-00-00 , 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O.462 Will planned perforations require a spacing exception? Yes ❑ No 0 DUCK IS UNIT MPI 2-60/U13 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034633 ' Endicott Field/Endicott Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,010 • 10,361 • 12,840 10,238 12,840 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" 110' 110' Surface 2,721' 10-3/4" 2,721' 2,717' 3,580psi 2,090psi Intermediate Production l 12,998' 7-5/8" 12,998' 10,352' 8,180psi 5,140psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: (Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/13CR80 J 12,388' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SABL-3 7-5/8"Packer and SSSV 12,299MD/9,824TVD and 1,545MD!1,542TVD 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/5/2015 Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman(a,hilcorp.com Printed Name Taylor Wellman Title Operations Engineer' ar u Signature .. Phone 777-8449 Date 713/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31S-053 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ' Location Clearance ❑ tri Other: II • o 71' to CefY, cllfr,UnS '—'1 � c ��C� cn �C/bi C C �, CC u 6 � k1c) a— o � prv1 -c3 s�k, cl*i�J ars-r S3 / 7 CIl fO C G I l � I Ub15 fc L sv LI CI L �, ��)]� c l'� tWi_ Spacing Exception Required? Yes ❑ No Subsequent Form Required: Jl0-- 4,0 • APPROVED BY Approved by: a4.7 , ` �y`_ COMMISSIONER THE COMMISSION Date: 2 ....u..../50 3irR$/►� nLZForm 10 403(Revised 1012012) I AIL d for 12 months from the date of approval. Attachment in Duplicate VTL 2/y //5 �- , a-L -/- , S y,s. Endicott End 2-60(PTD 193-083,Sundry 315-053)CONDITIONS FOR SUNDRY APPROVAL 1. Approved surface casing(SC) leak repair must be completed within a year of this sundry approval. 2. Well must pass a "No Flow"test witnessed by the AOGCC. 3. AOGCC witnessed MIT-T and MIT-IA required. 4. Well must be equipped with an OA pressure shut down trip.The p-pilot to be connected to an actuated valve on the gas lift line to shut in the source of pressure. OA trip pressure to be set at 350 psi. 5. LEL detector to be installed in the well house mounted to the tree directly above the well cellar. The LEL alarm points to be set at 40%. 6. Testing of additional safety equipment(LEL alarm;shut downs will be a part of the SVS testing) 7. Maintain sign on the well and information in the well house: Sign to read"Waived well-SC- leak".A one page summary describing the well condition and waiver stipulations must be maintained in the well house and clearly identified. . MIT-T/CMIT-TxIA/Pull Plug Well: END 2-60 PTD: 193-083 Hi!cora Alaska,LL, API: 50-029-22375-00 Well Name: END2-60 API Number: 50-029-22375-00 Current Status: SI—Surface Casing Leak Rig: Slickline Estimated Start Date: February 10, 2015 Estimated Duration: 1 days Reg.Approval Req'std? N/A Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 193-083 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) Second Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374(M) Current Bottom Hole Pressure: —3951psi @ 9,500' TVD (Based on SBHPS on 2-60 9/15/08) Maximum Expected BHP: 3951 psi @ 9,500' TVD (Based on SBHPS on 2-60 9/15/08) Max.Anticipated Surface Pressure: 3,000psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: Well 2-60 gas lifted producer that has a confirmed surface casing leak at 11.5' below the OA valve. The well is a high water cut (-92%)well that requires artificial lift to flow. The well was shut in by the previous operator since the leak depth was confirmed in August 2009. 08/16/09:Crude noted in conductor 08/18/09: MIT-OA Failed to 500 psi w/N2.At 400psi, bubbling observed and at 500psi first lowered 02% observed 08/23/09: MIT-OA Failed to 500 psi.At 500psi lowered 02%in flutes confirm SC leak to surface. 08/25/09:Set TTP @ 12376', MIT-T Passed to 3000 psi 12/11/09:CMIT-TxIA Passed to 3000 psi 12/19/09: MIT-OA w/N2. Pressure to 800psi with no change in 02%. 12/20/09: MIT-OA w/N2.At 1000psi,observed lowered 02%. SC leak strapped at 11.5' 03/06/10: Liquid Leak Rate down OA. Unable to psi up OA above 1480 psi 09/04/10: Liquid Leak Rate down OA.8 gpm @ 350 psi 09/16/10: Liquid Leak Rate down OA.0.35 bpm @ 950 psi, lost pressure above 1100 psi and LLR became 5 bpm @ 800 psi 10/31/11:CMIT-TxIA Passed to 3000 psi. 11/20/11:Wellhead Seal Test of the tubing-Passed to 5000 psi,Replaced broken LDS 12/05/14: MIT-T to 3000psi—Passed,CMIT-TxIA to 3000 psi—Passed. 12/06/14: PXX Pulled Objective: Pressure test the well to prove tubing and production casing integrity and then pull plug from the well in preparation to return the well to production. Install additional safeguards in place prior to re-activation of the well. Procedure: Slickline & Pumping . MIT-T/CMIT-TxIA/Pull Plug Well: END 2-60 PTD: 193-083 Hikorp Alaska.LI. API: 50-029-22375-00 1. MIRU SL unit and pump truck. 2. Pressure test to 300psi low and 3200psi high. 3. Pull 3-1/2" BBE SSSV. 4. RIH and set a 3-1/2" PXX plug in the 3-1/2" SWS Nipple at 12376' md. 5. Pull GLV#5 (8,350' md). 6. Circulate seawater down the IA while taking returns from the tubing. Cap with 60/40 meth/water and equalize to the tubing. 7. Set a GLV in station#5 (8,350' md). 8. MIT-T to 3000psi. Bleed down to^'2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads. 9. CMIT-TxIA to 3000psi. a. The well has live GLV's installed. Pumping down the IA will provide communication to the tubing. 10. If both test pass: a. Bleed down tubing and IA pressure to "300psi. i. The plug should be overbalanced by approximately 500psi (based on Sbbls of 60/40 on top of a column of seawater). b. Pull 3-1/2" PX Plug from 12,376'. c. Set 3-1/2" BBE SSSV. Operations 11. Conduct "No-Flow" Test. a. Passing criteria: Less than 6.3 gal/hr liquid rates and less than 900 scf/hr gas rates. 12. Install OA pressure shut down trip. The p-pilot connected to an actuated valve on the GL line to shut in the source of pressure. The set point recommendation is at 350psi for the following reason — Lowest pressure with gas that indicated an SC leak(bubbling but not lowered 02 readings)was 400psi. 13. Install LEL detector in the wellhouse. Attachments: As-built Well Schematic and Deviation Survey. , . 11 Endicott Unit Well: END 2-60 SCHEMATIC Last Completed: 1/30/1994 Hiker')Alaska,LLC PTD: 193-083 CASING DETAIL RTEIev.:55.3'/BFEIev.:16.12' Size Type Wt/Grade/Conn Drift ID Top Btm 30" Conductor 48/H-40/N/A N/A Surface 110' 30". G(N�� 10-3/4" Surface 36/K-55/Btrc. 9.95" Surface 2,721' G\ ' 7-5/8" Production 26/L-80/Btrc 6.875" Surface 12,998' N\' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 12,388' JEWELRY DETAIL t No Depth Item 1 1,545' SSSV Landing Nipple(2.75"ID) _2 _ 3,691' GLM#7 10-3/4" A 6 3 6,211' GLM#6 2 4 8,350' GLM#5 5 9,397' GLM#4 6 10,317' GLM#3 7 10,993' GLM#2 8 11,700' GLM#1 3 9 12,250' SWS Nipple(2.75"ID) 10 12,299' Baker SABL-3 7-5/8"Packer 11 12,330' SWS Nipple(2.75"ID) 12 12,376' SWS Nipple(2.75"ID) 4 13 12,387' 3-1/2"WLEG 9-CR-Bottom @ 12,388'-2.99"ID PERFORATION DETAIL Endicott Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5 3C5 12,615' 12,635' 10,071' 10,086' 20' 9/12/1996 Open 3C4 12,655' 12,667' 10,101' 10,110' 12' 6/11/1995 Open 3C4/3C3 12,690' 12,720' 10,127' 10,150' 10' 6/20/1995 Open N/A 12,697' 12,717' 10,133' 10,147' 20' 1/29/1994 Squeezed II 6 N/A 12,759' 12,769' 10,178' 10,186' 10' 1/29/1994 Squeezed N/A 12,785' 12,797' 10,198' 10,207' 12' 1/29/1994 Squeezed N/A 12,801' 12,821' 10,210' 10,224' 20' 1/29/1994 Squeezed OPEN HOLE/CEMENT DETAIL 10-3/4" 998 cu/ft PF"E"1,432 cu/ft"G"in a 13-1/2"Hole 7-5/8" 2,289 cu/ft Class"G"in a 9-7/8"Hole 8 _ WELL INCLINATION DETAIL Max Deviation is 49 deg.@±6,700' Angle at Top Perf:40 de.@ 12,615' TREE&WELLHEAD Tree 4-1/16",5000psi/Cameron Wellhead 13-5/8"/5,000psi/FMC PBD Standard Wellhead GENERAL WELL INFO 9 API:50-029-22375-00-00 •10 Drilled,Cased&Completed by Doyon 15 -1/30/1994 Perforate-6/20/1995 • 11 ' Perforate-5/8/1996 ,,12 Perforate-9/12/1996 Set Plug in SWS Nipple-8/26/2009 13 Pull Plug from SWS Nipple-12/11/2014 }Open Fe,ts SAFETY NOTE: TOC ,86 - H2S readings average 230 to 260 PPM 4/29/1996 'Squeezed Pets on A/L&gas injectors Full Bore 7-5/8„ "• ,:'L,' *S1pi 9r Cane @ 17 TD=13,010'(MD)/TD=10,361'(TVD) PBTD=12,840'(MD)/PBTD=10,238'(TVD) Created By:TDF 1/27/2015 MD TVD Inclination Azimuth 0 0 0 310.24 100 100 0.2 310.24 200 200 0.08 74.05 300 300 0.16 30.26 400 400 0.08 45 500 500 0.06 111.8 600 600 0.68 291.8 700 700 2.72 271.21 800 800 4.5 270.15 900 899 5.61 268.59 1000 999 5.72 271.04 1100 1098 5.42 271.58 1200 1198 5.04 268.3 1300 1297 4.73 268.89 1400 1397 4.35 273.78 1500 1497 4.32 279.47 1600 1597 4.39 280.54 1700 1696 2.19 285.8 1800 1796 1.01 217.79 1900 1896 0.95 201.11 2000 1996 0.12 253.79 2100 2096 0.29 358.31 2200 2196 0.29 348.12 2300 2296 0.19 346.84 2400 2396 0.36 354 2500 2496 0.24 341.37 2600 2596 0.46 333.11 2700 2696 0.49 345.32 2800 2796 0.4 322.8 2900 2896 2.83 267.44 3000 2996 4.94 258.33 3100 3095 5.95 258.21 3200 3195 7.46 258.45 3300 3293 9.51 257.71 3400 3391 10.73 256.72 3500 3488 14.11 253.42 3600 3584 17.82 250.69 3700 3677 20.81 251.66 3800 3768 24.43 252.42 3900 3856 29 252.73 4000 3940 32.66 252.37 4100 4022 34.35 252.11 4200 4104 35.36 250.96 4300 4184 36.53 250.51 4400 4264 36.72 250.36 4500 4342 39.15 249.64 4600 4416 41.95 249.43 4700 4488 44.18 248.9 4800 4557 46.19 250.06 4900 4625 47.29 250.21 5000 4692 48.15 249.43 5100 4760 47.3 248.66 5200 4828 46.74 247.88 5300 4898 45.78 248.95 5400 4967 45.97 249.57 5500 5038 45.21 248.25 5600 5109 44.49 249.25 5700 5181 44 248.28 5800 5254 43.4 247.89 5900 5327 42.53 247.96 6000 5402 42.1 248.39 6100 5477 41.27 247.8 6200 5550 42.89 248.65 6300 5622 44.31 250.13 6400 5693 44.27 250.02 6500 5765 43.98 249.66 6600 5837 44.16 249.24 6700 5909 44.17 249.25 6800 5978 45.91 249.04 6900 6047 46.89 248.88 7000 6115 46.89 249.18 7100 6183 47.19 247.32 7200 6251 46.92 250.5 7300 6320 46.92 249.03 7400 6387 47.94 249.93 7500 6453 48.48 249.83 7600 6519 48.66 251.07 7700 6585 48.53 250.57 7800 6651 48.81 250.21 7900 6717 48.83 251.23 8000 6782 49.49 253.23 8100 6848 48.41 251.55 8200 6915 48.33 252.31 8300 6981 48.32 253.75 8400 7049 46.88 253.8 8500 7118 46.82 253.84 8600 7186 46.87 254.3 8700 7254 47.09 254.01 8800 7323 46.72 254.48 8900 7392 46.23 253.69 9000 7461 46.65 253.64 9100 7528 47.72 253.88 9200 7595 47.96 254.17 9300 7662 47.77 253.37 9400 7732 45.37 253.88 9500 7802 45.71 254.32 9600 7872 46.12 254.37 9700 7941 46.34 254.54 9800 8009 46.93 254.69 9900 8077 47.33 254.5 10000 8145 46.65 254.55 10100 8214 46.61 254.81 10200 8284 45.94 254.97 10300 8353 45.63 253.16 10400 8423 45.99 255.2 10500 8492 46.07 254.8 10600 8561 46.69 255.36 10700 8630 46.53 253.9 10800 8698 46.65 254.1 10900 8767 46.55 253.61 11000 8836 46.86 255.07 11100 8904 46.91 254.66 11200 8973 46.15 256.45 11300 9043 45.38 254.87 11400 9115 44.43 254.07 11500 9188 42.56 254.53 11600 9264 41.22 255.01 11700 9340 40.24 255.07 11800 9417 39.23 256.45 11900 9496 38.15 255.96 12000 9575 37.75 256.34 12100 9654 37.73 256.95 12200 9735 36.53 256.77 12300 9815 36.82 259.05 12400 9893 38.26 259.36 12500 9971 39.28 257.33 12600 10047 40.12 258.73 12700 10122 41.76 261.02 12800 10195 42.74 257.67 12900 10267 43.9 261.11 13010 10346 43.91 261.29 Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, February 19, 2015 5:03 PM To: Loepp, Victoria T(DOA) Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Victoria, Here are some answers to the questions. LEL%alarm set point: 40% (adjustable as required) MIT-T& CMIT-TxIA conducted on 12/4/14: MIT-T Initial T/I/0= 1100/1400/300 Start T/I/O= 3000/1400/300 30 min T/I/O = 2961/1400/300 CMIT-TxIA Initial T/I/0 = 2500/1400/300 Start T/I/0 = 3000/3000/300 30 min T/I/O = 2992/2992/300 These tests were internal tests and even though the pressure trends were showing a stabilizing trend (noted by person conducting the test),the 15 minute pressure readings were not recorded and we can't provide the 15 minute readings to complete an official MIT form. Due to this reason we elected to re-set the deep plug in the well to be able to conduct an official MIT-T and CMIT-TxIA as part of our procedure for return to production. An Inspector was not informed of this test, because at the time our understanding of the regulations did not require a sundry for this type of work. Now with the proposed procedure,we would be able to have this be a witnessed test. If you have any additional questions or would like to talk about this please feel free to contact me, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, February 19, 2015 2:51 PM To:Taylor Wellman Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Taylor, Please provide LEL%alarm points. Also, please submit the MIT results performed on 12/4/14. Were these results witnessed and if not were the inspectors advised of the circumstances with this well? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska 1 Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent: Friday, February 06, 2015 11:00 AM To: Loepp, Victoria T(DOA) Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Victoria, Please see the responses below. I hope that this helps and I can talk more to these if you like as well. Thanks, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email:twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(a alaska.gov] Sent: Thursday, February 05, 2015 11:07 AM To:Taylor Wellman Subject: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Taylor, Several questions on this sundry: 1. Has repair of this SC leak been pursued? Repair options for all the Surface Casing Leak wells are being pursued. Currently we are looking into the best methods to be able to excavate to be able to access the leak points. What are the alternatives? Alternatives include: rig repair—pull tubing, cut and pull casing, run scab liner, cement to surface, cut off wellhead system, and put on new slip on startinghead or pumping a plugging material such as the old Brinker Technologies rubber pellets. What were the reasons BP didn't fix the leak? BP didn't fix the leak on this because they were waiting to prove up their repair method first and had other higher candidates to go after first. They began their first excavation repairs in 2014. 2. What is the production expected? Well test rates: 250bopd, 2500bwpd, 0.8mmscfpd. Incremental rates due to shutting in other wells to bring online: "100bopd. Thanx, 2 Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Thursday, February 19, 2015 1:51 PM To: Loepp,Victoria T(DOA) Subject: RE: End 2-60(PTD 193-083, Sundry 315-053) Return to Prod - Please review conditions and respond Comments: - No flow test must be witnessed by AOGCC - Well produced 16 days in December—unknown since. I guess this is ok if done to assess the well's mechanical condition although integrity issues appear to have been well documented(?) - I prefer trip points for additional shutdowns to be locked in prior to approval of sundry; otherwise it is difficult to track and enforce; 350psi OA trip pressure ok; unclear about%LEL alarm points - Testing of additional safety equipment(LEL alarm; shut downs will be part of SVS testing) - LEL detector installation needs to be more specific than "in the wellhouse"? (should be mounted to the tree directly above the well cellar) - They should send MIT results performed 12/4/14 (were these witnessed, and if not, were Inspectors advised of the circumstances with this well?) SVS tests ok- passed 12/14/14; we have received those test results. Don't see a real commitment to implement repair options—what do terms such as "pursuing" and "looking into" options really mean? Approval ok if the conditions of approval are amended to address above-noted concerns. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or limsegg@alaska.gov. From: Loepp, Victoria T(DOA) Sent:Thursday, February 19, 2015 10:29 AM To: Schwartz, Guy L(DOA); Regg, James B (DOA); Wallace, Chris D (DOA) Subject: End 2-60(PTD 193-083, Sundry 315-053) Return to Prod - Please review conditions and respond Guy,Jim,Chris, Attached please find a request for sundry approval for the Endicott Well 2-60 which is a gas lifted well and has a surface casing leak. Please see correspondence on plans for SC leak repair and the proposed conditions for approval which include a passing no flow test as well as a gas lift shut down pilot if the SC pressure increases to a certain point(Hillcorp recommends 350 psi).While only one barrier exists, using process control to shut in the gas lift on a well that will not 1 r flow unassisted does give another margin of safety. Given these conditions, should we approve this sundry? Your response and comments would be appreciated. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loeppalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepi ©alaska.gov • 2 Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday,January 27, 2015 2:37 PM To: Loepp,Victoria T (DOA) Subject: Endicott 2-60(PTD#1930830) Return to Production Attachments: 2-60 SCHEMATIC 1-27-2015.doc Follow Up Flag: Follow up Flag Status: Completed Victoria, Thank you for the talk about Endicott 2-60(PTD#1930830)today. Enclosed is a brief of the well's condition and the mitigations that will be put in place prior to re-starting the welt along with additional pieces outlined in the Sundry. If these mitigations look reasonable to you,we will move forward with the Sundry Application. Well Condition Well 2-60 gas lifted producer that has a confirmed surface casing leak at 11.5' below the OA valve. The well is a high water cut(-92%)well that requires artificial lift to flow. The well was shut in by the previous operator since the leak depth was confirmed in August 2009. Brief History 08/16/09: Crude noted in conductor 08/18/09: MIT-OA Failed to 500 psi w/N2.At 400psi, bubbling observed and at 500psi first lowered 02%observed 08/23/09: MIT-OA Failed to 500 psi.At 500psi lowered 02%in flutes confirm SC leak to surface. 08/25/09:Set TTP @ 12376', MIT-T Passed to 3000 psi 12/11/09:CMIT-TxIA Passed to 3000 psi 12/19/09: MIT-OA w/N2. Pressure to 800psi with no change in 02%. 12/20/09: MIT-OA w/N2.At 1000psi,observed lowered 02%.SC leak strapped at 11.5' 03/06/10: Liquid Leak Rate down OA. Unable to psi up OA above 1480 psi 09/04/10: Liquid Leak Rate down OA.8 gpm @ 350 psi 09/16/10: Liquid Leak Rate down OA.0.35 bpm @ 950 psi, lost pressure above 1100 psi and LLR became 5 bpm @ 800 psi 10/31/11:CMIT-TxIA Passed to 3000 psi. 11/20/11:Wellhead Seal Test of the tubing-Passed to 5000 psi, Replaced broken LDS Mitigations—Not all items have been conducted to date. These mitigation tests must pass before being counted. 1. MIT-T&CMIT-TxIA to 3000 psi(to prove casing&packer integrity. Max GL supply pressure is 2200psi). 2. No Flow Test Well (to show the formation is not capable of unassisted flow to surface) 3. OA pressure shutdown trip. There is a p-pilot connected to an actuated valve on the GL line to shut in the source of pressure. The set point recommendation is at 350psi for the following reason—Lowest pressure with gas that indicated an SC leak(bubbling but not lowered 02 readings)was 400psi. 4. LEL detector in wellhouse. The detector is linked to an alarm that notifies the control room operator. The well can be isolated and shut in without the need to enter the wellhouse. The GL line can be shut from an isolation valve located behind the wellhouse back in the flowline rack. Thank you and please contact me with any questions or comments, Taylor 1 PTD X93 -,g 3 Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, February 19, 2015 5:03 PM To: Loepp,Victoria T(DOA) Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here are some answers to the questions. SCAMEV LEL%alarm set point: 40% (adjustable as required) MIT-T& CMIT-TxIA conducted on 12/4/14: MIT-T Initial T/I/O = 1100/1400/300 Start T/I/O =3000/1400/300 30 min T/I/O = 2961/1400/300 CMIT-TxIA Initial T/I/O = 2500/1400/300 Start T/I/O =3000/3000/300 30 min T/I/O = 2992/2992/300 These tests were internal tests and even though the pressure trends were showing a stabilizing trend (noted by person conducting the test), the 15 minute pressure readings were not recorded and we can't provide the 15 minute readings to complete an official MIT form. Due to this reason we elected to re-set the deep plug in the well to be able to conduct an official MIT-T and CMIT-TxIA as part of our procedure for return to production. An Inspector was not informed of this test, because at the time our understanding of the regulations did not require a sundry for this type of work. Now with the proposed procedure, we would be able to have this be a witnessed test. If you have any additional questions or would like to talk about this please feel free to contact me, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email:twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, February 19, 2015 2:51 PM To:Taylor Wellman Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Taylor, Please provide LEL%alarm points. Also, please submit the MIT results performed on 12/4/14. Were these results witnessed and if not were the inspectors advised of the circumstances with this well? Thanx, Victoria 1 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria Loepp(a�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Taylor Wellman [mailto:twellman@hilcorp.com] Sent: Friday, February 06, 2015 11:00 AM To: Loepp, Victoria T(DOA) Subject: RE: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Victoria, Please see the responses below. I hope that this helps and I can talk more to these if you like as well. Thanks, Taylor "Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Thursday, February 05, 2015 11:07 AM To:Taylor Wellman Subject: Endicott 2-60(PTD 193-083, Sundry 315-053) Return to Production Taylor, Several questions on this sundry: 1. Has repair of this SC leak been pursued? Repair options for all the Surface Casing Leak wells are being pursued. Currently we are looking into the best methods to be able to excavate to be able to access the leak points. What are the alternatives? Alternatives include: rig repair—pull tubing, cut and pull casing, run scab liner, cement to surface, cut off wellhead system, and put on new slip on startinghead or pumping a plugging material such as the old Brinker Technologies rubber pellets. What were the reasons BP didn't fix the leak? BP didn't fix the leak on this because they were waiting to prove up their repair method first and had other higher candidates to go after first. They began their first excavation repairs in 2014. 2 2. What is the production expected? Well test rates: 250bopd, 2500bwpa, 0.8mmscfpd. Incremental rates due to shutting in other wells to bring online: -1.00bopd. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loeppalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp©alaska.gov 3 Loepp, Victoria T (DOA) From: Wallace, Chris D (DOA) Sent Thursday, February 19, 2015 11:06 AM To: Loepp,Victoria T(DOA) Subject: RE: End 2-60 PTD 193-083,Sundry315-053) Return to Prod - Please review conditions ( and respond Follow Up Flag: Follow up Flag Status: Flagged Victoria, Looks as good as it can. Is 1 year to complete the surface casing leak realistic/agreed? I agree a no flow determination is a large risk mitigation. With the well being shut in for so long since 2009—what would be a good restart production time/rate to re-establish clean reservoir to get the full appreciation of a no flow determination? Would we think the 5 days as per 20 AAC 25.265 (k) and Guidance Bulletin 10-004 be OK? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.caov. From: Loepp, Victoria T(DOA) Sent:Thursday, February 19, 2015 10:29 AM To: Schwartz, Guy L(DOA); Regg, James B(DOA); Wallace, Chris D (DOA) Subject: End 2-60(PTD 193-083, Sundry 315-053) Return to Prod - Please review conditions and respond Guy,Jim, Chris, Attached please find a request for sundry approval for the Endicott Well 2-60 which is a gas lifted well and has a surface casing leak. Please see correspondence on plans for SC leak repair and the proposed conditions for approval which include a passing no flow test as well as a gas lift shut down pilot if the SC pressure increases to a certain point(Hillcorp recommends 350 psi).While only one barrier exists, using process control to shut in the gas lift on a well that will not flow unassisted does give another margin of safety. Given these conditions,should we approve this sundry? Your response and comments would be appreciated. Thanx, Victoria 6 Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Thursday, February 19,2015 10:08 AM To: Loepp,Victoria T (DOA) Subject End 2-60(PTD 193-083, Sundry 315-053) Return GL Well to Production w/SC leak Follow Up Flag: Follow up Flag Status: Flagged End 2-60(PTD 193-083,Sundry 315-053);CONDITIONS FOR SUNDRY APPROVAL 1. Approved surface casing(SC) leak repair must be completed within a year. 2. Well must pass a "No Flow"Test 3. Well must be equipped with an OA pressure shut down trip.The p-pilot to be connected to an actuated valve on the GL line to shut in the source of pressure. Set points must be reviewed with the AOGCC. 4. Install LEL detector in the well house. 5. Maintain sign on the well and information in the well house: Sign to read"Waived well-SC-leak".A one page summary describing the well condition and waiver stipulations must be maintained in the well house and clearly identified. Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 8 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /d;:~"~ '-~)<:~'j~ile Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED -[] Logs :of various kinds · · n Other COMMENTS: Scanned by: 8eve~~ncent TO RE-SCAN Nathan Lowell Date: {'~ "'-(~ Is/ ' [(.~,~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser ~\~' Commissione; Tom Maunder, P. I. Supervisorr~/''- ~,~-.-'0 ~ FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI 1 & 2 May 20,2001: 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 MPi 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. Attachment: SVS DIU 5-20-01jc CC; NON-CONFIDENTIAL SVS DIU 5-20-0 ljc Alaska Oil and Gas Conservation Commis..on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Crisp, Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad _ Separator psi: LPS 235 HPS Date: 5/20/01 Well Pemit Separ Set ~ Test T~t Test Date oil WAG, G~J, Numbgr Number PSI PSI Tdp, Code Code Code Passed G~or~CL~ 1-01/J'19 1880370 235 150 125 p p P OIL , 1-03~16 1951500 235 150 135 p p P OIL 1-05/O20 1861060 1-09~2 1970290 235 150 130 'p '~ P .... OIL 1-15~25 1930560 1-1~M'I' 1961990~ , 1-19~18 1950930 235 150 125 P P 9 OIL 1-21~5 1906020 "' '1-25~ 1970750 '235 '150 150 p e P ' 0I~ 1-27~20 ' 1870090 235 150 135 P ' P P OIL '1_29~5 '1861810 ' ' 1-31~1 1950720 235 150 '125 e e P" 0IL 1-33B~2 1982550 235: 150 145 p p p " oIL , , 1-3~/O25 '1861840 '235 150 135 p e P OIL , 1-39~ 17 1880630 Jr45/Q26 1891240 ,, 1-47~ 1972030 1-49~21 1880780 235 150 130 e ' e P OI~ 1-~5~5 1880210 235 150 145 P P P OIL , 1-57~3 1881140 235 150 140 P P P OIL 1-61/Q20 194i420 23,5. 150 135 e P p' ' ' 0i~ 1-63~22 1890060 235 150 145 e p P OIL 1-65~25 1951880 235 150 150 e e p OIL 2-04~ 19 1860820 , , , 2-06/J22 1870180 , , 2-08~16 1880040 , , , ,,,i , 2-12/Q16 1921170 , , , 2-14/O16 1861490 2-18~16 1900430 ........... ~2-20~i5 1900600 " 2-26~14 1880550 , , 2-28~19 1880860 , 2-30~1 1981880 ,, 2-32/SN3 1901190 ~2-36/Oi4 1900240 2-38/SN1 1901290 , , i2-~¢~/,~ 1941520 ~, i i j i i L ii i ii I I I ii I! I i I I I i Well Pemit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2-42/P 3 2-44A/Q1 1970710 .......... 2-46B/S1 1971370 2-48/O13 1951660 2-50/U08' 1930670 535 ' '1561" 145 e P" e "0IL 2-52/S14 1870920 2'56A/EI 1980580 2-58/S09 1900520 2-60FU13 1930830 235 1501 "130 P P ...... P ......... OIL 2-62/Q1,,7, 1861580 , 2-68/S 17 1880970 , , 5-01/SD7 1801200 , ,,, , ,, ,, , , , ,., Wells: 17 Components: 51 Failures: 1 Failure Rate: ~ .9~% F1 oo var Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc ON OR BEFORE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3176' NSL, 2344' WEL, Sec. 36, T12N, R 16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-60/U- 13 At top of productive interval 1276' NSL, 3157' WEL, Sec. 35, T12N, R16E At effective depth 1235' NSL, 3363' WEL, Sec. 35, T12N, R16E At total depth 1226' NSL, 3428' WEL, Sec. 35, T12N, R16E 9. Permit number/approval number 93-83/Not required 10. APl number 50- 029-22375 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13010 feet 10305 BKB feet 12916 feet 10237 BKB feet Plugs (measured) Junk (measured) Full bore spinner cone 8" X 2" on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 110' 110' 2622' 13 1/2 998 c.f. PF "E"/432 "G" 2721' 2661' 10357' 9 7/8" 2289 cuft Class "G" 12998' 10296' measured 12615'-12635', 12656'-12666', 12690'-12720' (afl open) 12759'-12769', 12785'-12797', 12801'-12821' (all squeezed) ~ E E E IV E D true vertical (subsea) 10015'-10030', 10046'-10053', 10071'-10094' (afl open) 10123'-10130', 10142'-10151', 10154'-1016a'(allsqueezed) OCT 2. 1996 Tubing (size, grade, and measured depth) 3 1/2" 13CR80 at 12388' MD Alasi~, 0il & f~r-~ O0~. 6o,mmif~.~iol~ Packers and SSSV (~pe and measured depth) 7-5/8"X 3-1/2" Baker SABL-3 packer set at 12,299' MD; ' 2t~F2¢'-~SSV ~ 1545' 13. Stimulation or cement squeeze summary Re-perforate (9/12/96), SandbactCAcid Stim (9/23/96), Clean out (9/25/96) Intervals treated (measured) 12615'-12635', 12656'-12666', 12690'- 12720', 12759'-12769', 12785'-12797', 12801'-12821' Treatment description including volumes used and final pressure see attached 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 364 1565 849 0 325 561 1505 1193 0 306 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 hereb_v_certify that-the, J~,egoing is true and correct to the best of my knowledge. Form 10-4(J4/Rev 06/15/88 Date 10/18/96 SUBMIT IN DUPLICAT~ BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE LOCATION: ENDICOTT FROM: R. Clump DATE: 9/25/96 WELL: 2-60/U-13 OPERATION: CLEAN OUT Initial Well I FWHP lAP 0AP GLR FLP FLT StatusI (psi) (psi) (psi) (mscf) (psi) (o F) II ~so 1750 50 3.7 450 118 T I M E OPERATION 7:00 MIRU Camco Coil 4906. Coil Volume=33 BBLS. CFR= 1400 BPD. 5,3 mscf gas rate. 54 % WC. Trico takiin~ flow down 2-62. PT surface lines to 4000 psi. 8:24 Start recoverin~l MEOH. 9:08 Recover 28 bbls. 9:10 Open swab valve. Rih. TIME DEPTH RATE CTP WHP STG BBL REMARKS BPM VOL. RETN. 9:11 0 0 41~) 410 28 RIH. 9:40 3000 0.25 394 66 31 Move fluid. 10:11 6700 .17 374 8 38 Coil suckin~l slick SW. 10:27 8500 .17 336 29 41 10:40 10000 .17 338 25 43 16900# up wt, 10:59 12000 .17 340 17 45 21600# up wt. Well makin~l 500 BPD fluid. 11:05 12500 .16 396 19 46 11:08 12644 2 396 19 46/0 Come on line 2 bpm. Soft tag @ 12680'. 11:12 12644 2 600 335 60 Up rate till we catch fluid. Rih to jet, 11:15 12670 2 1498 338 63/0 Get ready for biozan swap. SW to biozan. 11:19 12638 2 1908 339 5 On biozan. 11:21 12660 2 2265 347 10/0 Back on SW 11:25 12660 2 2174 342 8 11:30 12660 2 2171 324 21 Rih. 11:33 12690 2 2617 298 23 Biozan at nozzle. 11:36 12750 2 2794 302 29 PU. 22 k 11:38 12750 2 3301 320 33 Biozan all out of coil. Chase up hole. 11:42 12631 2 3420 299 43 Chasin~l. 11:45 12558 2 3691 305 47 Biozan to surface, 11:51 12394 2 3501 307 61 Thru tb~l tail. Trico ~lettin~l water & Frac sand bac~ 11:53 12300 2 2500 316 64/0 SW to Biozan. RIH. 11:59 12577 1.67 3493 317 10 Reduce rate. Friction of biozan, 12:02 12700 1.7 3454 311 16 12:08 12700 0 1262 296 25/0 Switch to SW. 12:10 12700 1.5 3411 297 3 12:12 12700 1.5 3489 289 5 Rih. 12:13 12750 1.5 3448 302 8 Biozan at the nozzle. _ 12:17 12800 1.5 3399 305 13 21.5 k up. Rih. 12:20 12840 1.5 3252 319 20 Ta~l hard btm @ 12840'. 12:26 12831 2.0 3507 306 30 12:29 12830 2.0 3500 300 35 Biozan out nozzle. Chase up hole. 12:33 12694 2.0 3618 307 45 Sand to surface. 12:39 12550 2.0 3674 297 58 12:44 12330 2.0 3633 300 67 Pooh pumpin~l @ 86 fpm. 13:13 9590 2 3076 300 132 13:35 6000 2 2990 320 177 13:48 4140 0 65 307 201/0 SWto Meoh. 14:15 0 0 477 494 35 At surface. Done FP coil. Close swab. 14:27 0 0 0 0 Lubricator bled down. Secure well but 40 mph cro winds prevent layin~l down derrick. 15:00 Trico sending fluids down 2-62 flowline. Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (o F) II 9/25/96 450 1750 0 2000 120 i SUMMARY Recover meoh. Rih to Dry Tag @ 12660'- real soft. Pump 10 bbls stage of biozan. Chase up hole. Pump 2nd biozan stage- 25 bbls. Dive into sand again. Tag hard btm 12840' corrected. Poh chasing up hole. Good cleanout. TRICO taking liquid returns back down 2-62 flow line. Still catching trace of frac sand. Too windy to rig down CAMCO derrick. Secure well. FLUIDS PUMPED BBLS. DESCRIPTION 328 FSW w/FRW-14. 35 BIOZAN 35 METHANOL TO FP COIL BOTTOM-HOLE ASSEMBLY #1 Tool Strin~l Descriptions O.D. I.D. Len~lth Comments TC 2.45 0.92 2-CV 2.45 1.23 CNZ 2.50 0.38 Jet I TOTAL 2.53' RECEIVED OCT2 3 BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE FROM: POWERS WELL: 2-60/U-13 LOCATION: ENDICOTT DATE:9/23/96 OPERATION: SANDBACK/ACID STIM Initial Well I FWHP lAP 0AP GLP FLP FLT StatusI (psi) (psi) (psi) (psi) (psi) (o F) II 300 730 0 2so TI M E OPERATION 7:15 MIRU CAMCO 4906. CTV 33.0 8:21 PULL TEST BAKER TOOLSTRING 8:57 PT TO 4000 PSIG 9:16 RECOVER METHANOL TIME DEPTH RATE WHP CTP STG BBL REMARKS BPM VOL. RETN. 9:37 SURF 0 275 65 SI WELL AND RIH 10:24 5000 1190 33 11K UP. 11:07 10000 1000 30 20.8 K. BLEED WHP DOWN TO 2000 PSIG 11:37 12839 945 30 25K OFF BO~-FOM 12:03 12827 0/2 1000 0 PT DOWELL AND START PUMPING SW 12:06 1:8 992 1415 5/0 SW TO GEL 12:08 2.2 1030 2340 ' 3/0 SW TO SLURRY 12:16 2.5 1240 2250 22/0 SW TO GEL 12:17 2.0 1250 3/0 SW TO SW 12:22 1.5 1300 1075 10 SAND AT NOZZLE. PUH AT 10 FPM 12:37 12650 1.5 1500 2835 33 PLF TO SAFETY. HAD TO CRACK CHOKES TO I_/ PLUG IN. 12:38 12500 1.5/00 1600 1070 35 SD AND WAIT. 12:58 GO TAG 13:03 12763 DEEP. 13:08 13:13 12737 SAND TOP IS MOVING UP 13:20 12730 TAG AGAIN. MIX 2ND PLUG BASED ON 100% VOLUME 13:34 12710 1414 850 35/0 STAGE 2ND PLUG 13:38 5/0 SW TO GEL 13:41 3/0 SW TO SLURRY 13:47 12/0 SW TO GEL 13:49 3/0 SW TO SW 14:00 1.5 1500 3150 20 PUH 10 FPM 14:11 12500 1.5/00 1315 1293 35 PARK AT SAFETY 14:28 GO TAG 14:35 12650 GOOD TAG 14:47 . 12648 TAG AGAIN 15:06 SAFETY MEETING 15:14 12599 0/1.5 635 550 5/0 START SW. 15:18 START 15% HCL. 15:36 12635 1.5 1500 3375 26.3/0 SWTO SW 15:40 7 ACID AT NOZZLE. PUH AT 32 FPM LAYING IN AC WITH THE CHOKES CRACKED. 15:56 11800 1.5 520 2106 29.2 CHOKES ARE CLOSED. LOOKS LIKE GOOD AC BREAK. 16:01 1.5/2.0 486 2100 36 WASH DOWN TUBING AND INCREASE RATE TO; BPM. 16:25 12536 2/0 540 200 83.7 SD AND POOH. 18:01 SURF FP AND RD COIL. Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (o F) II 2000 o oo SUMMARY RIH and tagged TD at 12839' CTMD. Layed in a 3400 #s of 20/40 carbolite. Tagged sand top at 12730' CTMD. Layed in a 2nd plug of 1450#'s of 20/40 carbo and 150#s of 100 mesh sand with chokes open maintaining 1500 psig back pressure. Tagged sand at 12648' CTMD. Circulated in 26 bbls of 15% HCL hold ing 1500 psig on well. Saw a good break before acid was fully laid in. BH acid into perfs at 2 BPM and 400 psig WHP. Over displaced with about 30 bbls of SW. POOH and poped well with lift ~las throu~ibTRICO. FLUIDS PUMPED B BLS. DESCRIPTION 12 CLEAN GEL 30 SLURRY (4800#S 20/40 CARBO) 26 15% HCL WITH ADDATIVES 35 METHANOL 167 FSW Endicott Production Engineering Department RE-PERFORATE DATE: 9/12/96 WELL N°: 2-60/U-13 BP EXPLORATION REP: D. VARBLE SERVICE CO: S.O.S. (MAJGHER ) DATE/TIME OPERATIONS SUMMARY I 14OO MIRU SOS 1545 HOLD TGSM. CALL FOR RADIO SILENCE ARM GUN 1615 RIH WITH GR-CCL/20' GUN 1710 OUT T.T. BLEED WHP DOWN FROM 1400 PSI TO 300 PSI 1715 PROBLEMS WITH CCL/GR. STAND BY TO REPAIR. 1745 TIE INTO CBT DATED 1/28/94. ADD 3' 1752 ON DEPTH. LOG INTO PLACE & HANG CCL/GR @ 12609.5' MD (5.5' FROM CCL TO TOP SHOT) _ 1755 SHOOT GUN FROM 12615' - 12635' MD. SLIGHT WEIGHT CHANGE. SHUT IN WELL & LOG OFF 1759 POOH 1846 ©OH. CONFIRM ALL SHOTS FIRED. END RADIO SILENCE. 2OOO RDMO PERFORATION SUMMARY: GUN CBL DEPTH FEET SUBZONE I 12615'-12635' 20' 3C5 _ _ ALL INTERVALS WERE SHOT USING SOS 2 1/8 ENERJET III STRIP GUNS, 4 SPF. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 8. 3176' NSL, 2344' WEL, Sec. 36, T12N, R16E At top of productive interval 9. Well number 2- 60/U- 13 Permit number/approval number 93-83/Not required 10. APl number 50- 029-22375 1276'NSL, 3157' WEL, Sec. 35, T12N, R16E At effective depth 1235' NSL, 3363' WEL, Sec. 35, T12N, R16E At total depth 1226' NSL, 3428' WEL, Sec. 35, T12N, R16E 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13010 feet 10305 BKB feet 12916 feet 10237 BKB feet Plugs (measured) Junk (measured) ,i©IhlAL Full bore spinner cone 8" X 2" on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) Length Size Cemented Measured depth True vedical depth BKB BKB 71' 30" Driven 11 O' 11 O' 2622' 13 1/2 998 c.f. PF "E'F432 "G" 2721' 2661' 10357' 9 7/8" 2289 cu ft Class "G" 12998' measured 12656'-12666', 12690'-12720' (all open) 12615'- 12635', 12759'- 12769', 12785'- 12797', 12801'- 12821' (afl squeezed) true vertical (subsea) 10046'-10053', 10071'-10094' (afl open) /~.[.J b 2 (.; '[gr'~- "~ · ,J ~-~ 10015'"10030', 10123'-10130', 10142'-10151', 10154'"10168'(aflsqueezed) 3 1/2" 13CR80 at 12388'MD Packers and SSSV (type and measured depth) 7-5/8"X 3-1/2" Baker SABL-3 packer set at 12,299' MD; 3 1/2" SSSV @ 1545' 13. Stimulation or cement squeeze summary Water Shut off, Cement Squeeze (4/29/96), Re-Perforate (5/1/96) Intervals treated (measured) 12615;12635', 12656'-12666', 12690'- 12720', 12759'-12769', 12785'-12797', 12801'"12821' Treatment description including volumes used and final pressure see attached 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 778 647 2825 0 350 638 200 1356 0 277 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby-certify that the fel'eaoing is true and correct to the best of my knowledge. Si~ned ~('-~~,~. ~"~)~/'-~'~17' Title Senior TechnicalAssistant lV Form 10-404 ~ev 06/15/88 Date 8/22/96 SUBMIT IN DUPLICATE BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE FROM: POWERS WELL: 2-60/U-13 OPERATION: WSO LOCATION' ENDICOTT DATE'4/29/96 II Initial Well I SlWHP lAP 0AP GLP FLP FLT II StatusI (psi) (psi) (psi) (psi) (psi) (o F) II 900 1500 0 2000 250 ./^ TI M E OPERATION 10:30 MIRU CAMCO 4906. MU BHA. CTV=33.7 BBLS 11:31 PT to 4000 psi- OK. Recover meoh. POP well to bleed off gas head. 12:21 SI well, open swab, and begin bh kill well. TIME DEPTH RATE WHP CTP STG BBL REMARKS BPM VOL. RETN. 12:22 0 4.8 870 760 10 begin BH kill 12:28 4.5 1412 1292 45 12:56 0 780 760 158 FP backside line and RIH. 13:02 120 1 780 1820 0 Pump down coil only. 13:56 5000 1 705 1890 55 9500 14:45 10000 1 708 2150 106 19000 15:11 12850 1 720 2175 133 23.8K OFF BOTTOM 15:13 12850 1/1.8 800 3390 138 BEGIN SUMP COOL DOWN. SAFETY MEETING 15:49 198 CMNT TO WEIGHT. FP CAMCO 15:55 SW TO BJ. 15:58 1.7 777 3000 SW TO ACID 16:06 16/0 SW TO SW 16:15 12580 2.1 3800 915 18 ACID AT PERFS RIH JETTING 16:25 36 SD TO HESITATE 16:31 5 MIN FL 50 CC 16:36 2 3500 688 DISPLACE ACID. 15 MIN FL 56.5 CC 16:47 12400 1.95 3610 709 RIH TO FLAG 16:53 /0 SWTO EF 30 MIN FL 59 CC 17:07 11/0 SW TO CEMENT 17:15 18/0 SW TO EF 17:15 5/0 SW TO SW. EF AT THE NOZZLE 10 17:24 11 CEMENT AT NZL 12 13 17:26 MX/1,3 14 START OOH @ 30 FPM 1.3 15 16 r-'~ ~,~/ 18 19 A:'.m ,, .-. ~ ...... 2O 21 22 PERFS COVERD START LIVE CELL 23 17:35 1200 2783 24 OPEN CHOKES 25 26 27 28 29 PLF 3O 31 32 17:43 12200 1270 33 START GAUGING 17:44 1300 34 17:45 1250 35 1.75 17:46 36 2.75 GO TO 2000 17:47 1/.5 2000 37 3.0 17:49 38 4 17:50 39 5 17:53 40 5.75 17:55 41 6.75 GO'TO 2500 17:57 2500 42 7.25 17:59 43 8.0 18:01 44 9 18:03 45 9.75 18:05 46 10.75 GO TO 3000PSI 18:06 3000 47 18:13 2340 48 TRY HESITATING 18:14 1580 49 SUSPECT WE MAY BE COMUNICATING WITH THE IA 18:18 1635 BUMP PRESSURE BACK UP TO 3000 PSIG AND HOLD WITH CHOKES. 18:23 3000 LIVE CELL AT 33 CC. 18:30 SD AND TRAP PRESSURE 18:35 2925 LINE UP TO REVERSE. 18:42 12200 1.6 1920 28 50.5/0 BEGIN LRO 19:03 12500 2260 12 40 LIVE CELL WAS 46 CC 20:04 12695 1.4 2140 2 128 2.5HR LIVE CELL 57 CC 20:38 12787 2211 3 HR 65 CC 20:57 12840 1.44 2055 STARTED LOSING RETURNS AT ABOUT 12825. LOOKED LIKE WE MAY HAVE KNOCKED A NODE OFF. 21:08 12860 1.45 2034 0 212 WAIT FOR RETURNS TO CLEAN UP. 21:29 1800 250 RETURNS LOOK CLEAN. LINE UP FOR JET PASSES 21:35 1.6 1600 3400 250/0 BEGIN JET PASSES 22:04 12860 1600 1600 46/46 BEGIN FINAL REVERSE OUT 22:27 12860 1.6 2034 13 40 14.5 BBLS CEMENT BACK. 22:32 2000 FI NAL PT 22:37 1850 LOST ABOUT 30 PSI/MIN Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (° F) .. 4/30/96 2000 1850 0 2000 N/A SUMMARY BH killed well with 160 bbls of FSW. Cooled sump with 198 bbls. Layed in 15 bbls of 15%HCL/10% xylene across perfs. saw a slight injectivity response but lost it by the time cement was at the nozzle. Layed in 18 bbls of cement from 12850'-12450' CTMD. Ramped squeeze pressure up to 3000 psig over 20 mins. Lost excessive pressure and reduced squeeze to 1600 psi. Suspected IA comunication and ramped pressure back up to 3000 psi and held with chokes cracked for 15 mins. LRO cement to 12860' CTMD. Started losing returns at about 12825. Recovered 14.5 bbls. Jetted tubing tail and liner. Recovered all pumped fluids. Final 2000 psig PT was 30 psi/min. POOHed holding 1600 psig on the well. 3.5 bbls behind pipe 30 psi/min leakoff (Most likely at the bottom of the lowest set of perfs) FLUIDS PUMPED BBLS. DESCRIPTION 873 FSW 16 15% HCL/10% xylene 18 Cement 40 Methanol CEMENT DETAILS BJ SERVICES 15.8 PPG Class G Cement containing: 0.1% CD-32 O.32% R-11 O.45% FL-33 1 gal/100 sx FP-6L Thickening Time = 6hrs 30 min + 1 hr surface Lab APl Fluid Loss = 72 cc Field APl Fluid Loss = 61 cc i Endicott Production EngineerJng Department DATE' 5/ 8 / 96 WELL N°-: 2-60 / U-13 BP EXPLORATION REP: Re-Perf THOMAS RUT SERVICE COMPANY: ATLAS (WAYNE BARKER, JOHN, SAM) DATE/TIME OPERATIONS SUMMARY I 5/8 0800 MIRU ATLAS. 1 030 RAISE GUNS TO LUBRICATOR & BOPS TO TREE CAP. WELL ALREADY SI. SIWHP = 850 PSI; lAP = 900 PSI; OAP = 0 PSI; CHOKE & WING CLOSED. 1 040 PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (30 FT WITH 43.5' OAL). GR MEASURE PT TO TOP SHOT = 2.5'. SIWHP = 850 PSI. 1240 OPEN CHOKE & WING TO BLOW DOWN PRESSURE FOR UNDERBALANCE. LEAVE CHOKE OPEN TO 176 BEANS FOR PERFORATING. WHP DOWN TO FLOWLINE PRESSURE FOR PERFORATING (-300 PSI). 1245 LOG TIE-IN STRIP UP WITH WELL FLOWING. NOTE: TIED-IN WITH 1/28/94 SBT- GR. MAKE +21 FT CORRECTION TO E-LINE. TAGGED TD AT 12851' MD. DROP BACK DOWN. 1310 LOG UP TO TOP SHOT AT 12690' MD. 1340 FIRE GUN. SAW STRONG CAP BREAK & WEIGHT CHANGE. LOG UP TO CONFIRM TIE-IN, CLOSED CHOKE/WING, AND POOH. 1420 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. ALL SHOTS FIRED. SIWHP = 700 PSI. 1445 ARM GUN #2. PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #2 (10' GUN WITH 33.5 FT OAL). GR MEASURE PT TO TOP SHOT = 12.5' (ADDED 10 FT OF SINKER BAR TO LIGHTER GUN). 1 545 ON BO'I-FOM. OPEN WING AND CHOKE TO 176 BEANS FOR DRAWDOWN. 1555 LOG TIE-IN STRIP UP WITH WELL FLOWING. MAKE +6 FT CORRECTION TO E- LINE. NOTE: TIED-IN WITH 1/28/94 SBT-GR. 1 605 LOG UP TO TOP SHOT AT 12656' MD. 1 610 FIRE GUN. SAW STRONG CAP BREAK ON EBW PKG & WEIGHT CHANGE. LOG UP TO CONFIRM TIE-IN. CLOSE CHOKE & WING AND POOH. 1 700 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. CONFIRM ALL SHOTS FIRED. SIWHP = 850 PSI. 171 5 POP WELL AND REQUEST POST-PERF WELL TEST. ~:~ 1830 RDMO ATLAS. PERFORATION SUMMARY' GUN SBT-GR DEPTH FEET I 12690 - 12720 30 2 12656 - 12666 10 SUBZONE 3C4/3C3 3C4 ALL SHOTS WERE FIRED WITH ATLAS 2-1/2" HSC ALPHA JET GUNS LOADED AT 4 SPF 0°PHASING AND 0° ORIENTATION. NOTE: SEVERAL WEIGHT OVER PULLS WERE OBSERVED IN LINER FROM -12700' TO ~12600' MD, POSSIBLY FROM ABRASIVE GUN SCALLOPS OR FROM DRAG OVER SQZ NODES?? STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging.__ Pull tubing Alter casing __ Repair well Perforate__ Other, X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3176' NSL , 2344' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-60/U- 13 9. Permit number/approval number 93-83/Not required 10. APl number 50- 029-22375 1276' NSL, 3157' WEL, Sec. 35, T12N, R16E At effective depth 1235' NSL, 3363' WEL, Sec. 35, T12N, R16E At total depth 1226' NSL, 3428' WEL, Sec. 35, T12N, R16E 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13010 feet 10305 BKB feet 12916 feet 10237 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 110' 110' 2622' 13 1/2 998 c.f. PF "E"/432 "G" 2721' 2661' 10357' 9 7/8" 2289 cu ft Class "G" 12998' 10296' measured 12615'-12635', 12655'-12667', 12690'-12720', 12759'-12769', 12785'-12797', 12801'-12821' true vertical (subsea)10015'-10030', 10045;10054', 10071'-10094', 10123'-10130', 10142'-10151', 10154;10168' Tubing (size, grade, and measured depth) 3 1/2" 13CR80 at 12388' MD Packers and SSSV (type and measured depth) 7-5/8"X 3-1/2" Baker SABL-3 packer set at 12,299' MD; 3 1/2" SSSV @ 1545' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment 9/6/95 Intervals treated (measured) 12615'-12635', 12655'-12667', 12690'- 12720', 12759'-12769', 12785'-12797', 12801'-12821' Treatment description including volumes used and final pressure 64.5 Bbls seawater/mutual solvent mix, 61.2 Bbls seawater/scale inhibitor mix, 172,5 Bbls seawater/2% surfactant, and 120 Bbls seawater tubing volume. FWHP = 50 psia 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 777 1425 2210 0 637 24 1637 0 Tubing Pressure 325 318 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. Signed ~-'~- ~_~2/~%./?,;~.' ~ , : Title Senior Technical Assistant II Form 10-4~/¢ Rev 06/15/88 SUBMIT IN DdPI{_ICATE ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Perforate X Pull tubing__ Alter casing __ Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3176' NSL, 2344' WEL, Sec. 36, T12N, R16E At top of productive interval 1276' NSL, 3157' WEL, Sec. 35, T12N, R16E At effective depth 1235' NSL, 3363' WEL, Sec. 35, T12N, R16E At total depth 1226' NSL, 3428' WEL, Sec. 35, T12N, R 16E 5. Type of Well: Development Exploratory Stratigraphic Service Other · 6. b-arum elevation (DF or KB) KBE = 56' feet 7. Unit or P~bpertyn~me Duck Island Unit/~ndi~°tt 8. Well number 2- 60/U- 13 9. Permit number/approval number 93-83~Not required 10. APl number 50- 029-22375 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13010 feet 10305 BKB feet 12916 feet 10237 BKB feet Plugs (measured) Junk (measured) Full bore spinner cone 8" X 2" on bottom Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 110' 54' 2622' 13 1/2 998 c.f. PF "E"/432 "G" 2721' 2661' 10357' 9 7/8" 2289 cu ft Class "G" 12998' 10296' measured 12615'-12635', 12655'-12667', 12690'-12720', 12759'-12769', 12785'-12797', 12801'-12821' truevertical ¢ubsea) 10015~10030~ 10045~10054~ 10071~10094~ 10123'-10130~ 10142'-10151~ 10154'-10168' Tubing (size, grade, and measured depth) 3 1/2" 13CR80 at 12388' MD Packers and SSSV (type and measured depth) 7-5/8" X 3-1/2" Baker SABL-3 packer set at 12,299'MD; 3 1/2"SSSV @ 1545' 13. Stimulation or cement sqQeeze summary 14. Intervals treated (measured) ,-, ,.ii Treatment description including volumes used and final pressure ,,,, ~.',.~ :"~ Representative Daily Average Production or Injection Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 99 5699 149 0 658 446 6506 251 0 1103 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing i.s true and correct to the best of my knowledge. Si~ned(~/t,,'~C_c~'¢, /'~~ Title Senior Technical Assistant ll Form 1~-~4 Rev 06/15/88 SUBMIT IN D'UPLI~;A~ Endicott Production Engineering Department OPERATIONS REPORT DATE:6/11/95 WELL Na:2-60/U-13 TYPE OF OPERATION:RE-PERFORATE BP EXPLORATION REP:POWERS/VARBLE SERVICE COMPANY:ATLAS(ESARY) DATE/TIME OPERATIONS SUMMARY 0800 MIRU - INSTALL FUSIBLE CAP - FWHP = 280 PSI; IA = 1550; OA = 300; FWHT = 128; CHOKE @ 176 BEANS 0945 SHUT IN WELL & GLT 0950 RIH WITH PFC, GUN # 1 (12') 2.5 HSC (3.5'FROM CCL TO'TOP SHOT) OVERALL LENGTH = 37.5' 1119 OUT OF TT- POP WELL @ 40 BEANS - SIWHP = 1216 TIE IN TO SBT DATED 1/29/94 ADD 23' 1211 SHOOT GUN # 1 FROM 12655 - 12667' 1217 SI WELL - LOG OFF - POOH - FLAG LINE@ 12500' 1400 RIH WITH GUN # 2 (20') 2.5 HSC & ROLLER SKATES ( SIWHP =550) 1445 SITTING DOWN @ 5200' 1536 CAN'T GET PAST 7400' - POOH 1603 OOH - SHORTEN UP TOOL STRING 1645 RIH WITH GUN # 3 (10') 2.5 HSC WITH ROLLER SKATE 1720 SITTING DOWN@ 4500' - WORK TOOLS UP & DOWN 1750 CAN'T GET PAST 4700' - POOH 1815 OOH - POP TO WARM UP WELL 1850 RDMO PERFORATION GUN 1 SUMMARY' SBT DEPTH FEET SUBZONE 1 2655-1 2667 12 3C4 THE INTERVAL WAS 0 DEGREE PHASING CHARGES. SHOT USING 2.5 ALPHA JET HSC GUNS @ 4SPF, & 0 DEGREE ORIENTATION WITH!-10.5 GRAM Endicott Production Engineering Department OPERATIONS REPORT DATE: 6/13/95 WELL N-°: 2-60/U-13 TYPE OF OPERATION: RE-PERFORATE BP EXPLORATION REP: VARBLE SERVICE COMPANY: ATLAS (ESARY) IDATE TIME OPERATIONS SUMMARY 1330 MIRU ATLAS FWHP=300 IA=1500 OA=80 FWHT=124 CHOKE=176 1 500 SI WELL & GL - SlWHP = 950 RIH WITH CCL & GUN# 1 (20') OVERALL LENGTH IS 34' (2' FROM CCL TO TOP SHOT) 1525 Slq-FING DOWN @ APPROX. 4600' 1615 UNABLE TO GET PAST 4921' POOH 1...640 OOH - ADD 10' STEM TO TOOL STRING (OVERALL LENGTH 44') 171 0 RIH WITH NEW TOOL STRING 1 845 OUT OF TUBING - OPEN WING AND SET CHOKE @ 40 BEANS 1 853 TIE IN TOSBT DATED 1/28/94 - FWHP = 275 PSI 1 930 ADD 40.5' - CCL ON DEPTH @ 12613' 1935 SHOOT GUN FROM 12615'- 12635' LOG OFF POOH TO 12460' - STAND BY AND FLOW WELL FOR 15 MIN. :1'950 S I WELL & POOH 2037 OOH - SIWHP -,380 IA- 960 OA- 0 2050 CONFIRM ALL SHOTS FIRED - R D ATLAS 2055 POP & RELEASE WELL TO PRODUCTION PERFORATION SUMMARY: GUN SBT DEPTH FEET SUBZONE I 12615-12635 20 3C5 THE INTEVAL WAS SHOT WITH A 2.5 ALPHA JET HSC GUN AT 4 SPF, 0 PHASING & 0 ORIENTATION WITH 10.5 GRAM CHARGES. Endicott Production Engineering Department OPERATIONS REPORT DATE: 6/20/95 WELL N-°: 2-60/U-13 TYPE OF OPERATION: RE-PERFORATE BP EXPLORATION REP: R. CLUMP SERVICE COMPANY: ATLAS (D. BARBA) TIME OPERATIONS SUMMARY 0800 MIRU ATLAS. 0930 SI GL & OIL CK. SIWHP = 500 PSh RIH WITH GUN# 1 (30') OVERALL LENGTH IS 41' (3' FROM GR TO TOP SHOT). STOP ABOVE PERFS @ 12500'. OPEN CK TO 40 BEANS. 1100 TIE IN TO SBT DATED 01/29/94 LOGGING UP (+16'). FROM 12800'-12650'. MAKE CONFIRMATION PASS FROM 12800'-12550'(+1). FWHP= 300 PSI. RIH TO 12800'. LOG INTO POSITION 12687' GR DEPTH-12690 TS DEPTH. 1117 SHOOT GUN #1 (12690-12720' MD BKB). GOOD IND. LOG OFF. HUNG UP @ 12665'. STOP FILE. WORK TWICE. CAME LOOSE @ 600# OVER. PULL UP HOLE TO 12500'. WAIT FOR 15 MINS FOR JUNK TO FALL BACK. 1138 POOH. 1 230 OOH. ALL SHOTS FIRED. END RADIO SILENCE. 1245 POP FOC WITH 2 MMSCF GL. PERFORATION SUMMARY' GUN SBT DEPTH FEET SUBZONE I 12690-12720 30 3C3 THE INTEVAL WAS SHOT WITH A 2-1/8", 16GM, SILVER JET STRIP GUN AT 4 SPF, 0° PHASING & 0° ORIENTATION. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 May 1996 RE: Transmittal of Data Sen5 by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-60/U-13 2-60/U-13 DESCRIPTION PLS EiHAL EL+RF ~-~ Run ~ 1 PLS FINAL BL+RF~/ Run # 1 PFC/PERF FINAL BL+RF~/Run ~ 1 PFC/PERF FINAL BL+RF /Run # 1 ECC No. ~973.01 5723.15 6132.07 6132.08 Received by: Please sign and return to: Attn. Rodney D. Paulson Wessern Atlas Logging Services 5600 B Street Suite 201 ~ Anchorage, AK 99518 FAX . 9 ~ 563-7803 ~~~(01) Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSluN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3176' NSL , 2344' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-60/U-13 At top of productive interval 1276'NSL, 3157' WEL, Sec. 35, T12N, R16E At effective depth 1235' NSL, 3363' WEL, Sec. 35, T12N, R16E At total depth 1226' NSL, 3428' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: measured true vertical ?.9 995 a & Gas Cons. c0mmissi0n ch0r ' 13010 feet Plugs (measured) 10305 BKB feet 9. Permit number/approval number 93-83/Not required 10. APl number 50- 029-22375 11. Field/Pool Endicott Field/Endicott Pool Effective depth: measured true vertical 12916 feet 10237 BKB feet Junk (measured) Full bore spinner cone 8" X 2" on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vejti.c._al depth BKB 71' 30" Driven 110' 54' 2622' 13 1/2 998 c.f. PF "E"/432 "G" 2721' 2661' 10357' 9 7/8" 2289 cu ft Class "G" 12998' 10296' measured 12615'-12635', 12655'-12667', 12697'-12717', 12759'-12769', 12785'-12797', 12801'-12821' true vertical (subsea) 10015'-10030', 10045'-10054', 10077'-10091', 10123'-10130', 10142'-10151', 10154'-10168' Tubing (size, grade, and measured depth) 3 1/2" 13CR80 at 12388'MD Packers and SSSV (type and measured depth) 7-5/8" X 3-1/2' Baker SABL-3 packer set at 12,299'MD; 3 1/2"SSSV@ 1545' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (2/12/95) Intervals treated (measured) 12615'-12635', 12655'-12667', 12697'-12717', 12759'-12769', 12785'-12797', 12801'-12821' Treatment description including volumes used and final pressure 62 Bbls diesel/mutual solvent mix, 41 Bbls. seawater/Scale inhibitor mix, 286 Bbls seawater/2% surfactant mix, 88 Bbls seawater , and 10 Bbls meOH. FWHP = 289 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 771 4221 905 0 297 571 85 932 0 285 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. Signed ~'"~-¢'~/3-¢"~~. ~~c'~--~ Title Senior Technical Assistant II Form 10-404 Re¢06/15/88 SUBMIT IN DUPLI~3ATE ~ ~°ERNIT q3-083 q3 08~' ~3-083 93-083 93-n~:3 ~3-083 083 93-08 93-~083 93--083 AOGCC individual Well Geological Materials Inventory DATA T DATA 6012 /12300-12988, OH-DLL GR/CCL BHP CCL L 125=0-i~800~ ~ 1~400-1~q89~ ~_ L 12468-12812 DLL/HLL/GR/SP ~ 12400-12989 GR (JWL) p~Z 122O0--12650 G~,/~C,. ~T. !2700-1~-'000 ~P?'~'-'~'/CL/q~~~ 12550 12880 PLS PROD PROFILE !2500~i2900 6500-12860 SBT/GR/'CCL ~ L i2908-i1000 SSTi/D ~'i2400-!2989 ZDL/CN/GP,./CAL ~ 12400-12989 P a g ¢: · i Da'he' 10/13/95 RUN DATE_RECVD 1 02/24/94 1 06/30/95 i 02/28/94 i 06/26/95 1 02/28/94 1 07/11/94 1 08/09/95 1 02/28/94 ! 06/16/95 1 07/11/94 1 08/09/95 t 02/28/94 1 02/28/94 1 02/28/94 Are dry ditch samples required? yes And receivea? ~fes :n0 ~as tio~- we~i core.~? yes naiysis & descriptioi~i-vedT- yes; no Are well tests required? yes Well is in compliance _..~'~ initial LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 27 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 4-32/K-38 (SDI) 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6132.06 Run # 1 6452.05 Please sign and return to~ Attn. Rodn~ /Anchorage, AK 99518 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Sent by: Dear Sir/Madam, 26 June 1995 Transmittal of Data PRIORITY MAIL Enclosed, please find the data as described below: WELL ~3/0~1 # DESCRIPTION 3-19/R-28 SDI 1 PFC/PERF FINAL BL+RF t PFC/PERF FINAL BL+RF Run # 1 Run # 1 ECC No. 6132.05 6217.13 Please sign and return to: Attn. Rodney D. Paulson ~ Atlas Wire].i~~~~ sm ~t~~___~ ~__~~ /OryX to~(~ 567-7803 Received by~ ~~~ /~.~/// Date: -'- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 2-60/U-13 1 PFC/PERF FINAL BL+RF 2-42/P-13 (MPI) ,~('~ 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6132.04 Run # 1 6209.04 Please sign and re~odney At 1 as~c~e s 5600 ~B~reet ./ /Ancho,~age, AK 99518 ~/ f Or F~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION I PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 ECC No. 6006.05 6132.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and ..~e'tc.r~n, '$o~, ethnical Data Center pet_rot_ --~ion (AlaSka) Ine BP Exp~or~ 900 East Benson Boulevard Da~e ~as~ Oil & Gas C~s. Commission ~chomge ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY_GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 June 1994 RE: Transmittal of Data ECC #: 6132.02 Sent by: ANCHORAGE XPRES Data: PL Dear Sir/Madam, Reference: BP 2-60/U-!3 q 5j ~ ~ ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: PLS FINAL BL /z~P~S FINAL RF SEPIA /~R/JEWL. RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Reeeived by STATE OF ALASKA ALASKA 0IL 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 ~ I'~ ! ~ ! ~ I · ~ 93-83 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 U K I to L 8. APl Number 5 O- 029-22375 4. Location of well at surface 9. Unit or Lease Name 3176' NSL, 2344' WEL, SEC. 36, T12N, R16E .. .......................~ Duck Island Unit/Endicott ~ ~ .... .~.. ;....~,~ At Top Producing Interval i :-:,'-~;'i;j~! ~!'ii';i".i ~ ~ ........ ~ ~ ..... 10. Well Number ....... '; ¥"'~'::~':'~:~'~ ~ 2-60/U-13 At Total Depth :' "~' ~ ..... :i ~ - Endicott Field/Endicott Pool . 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 56' I ADL 34633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 1i6. No. of Completions 1/1/94 1/23/94 1/31/94! 6'- 12' feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey J20. Depth where SSSV set ~1. Thickness of Permafrost 13010'MD/10361'TVD 12916'MD/10293'TVD YES [] NO []I 1545' feet MD ]1465'(Approx.) 22. Type Electric or Other Logs Run Run #1 CCL Run #2 Gyro Run #3 CCL/GR/ACC/VDL/SBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE iNT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive Surface 110' 30" 10-3/4" 45.5~ N T-80/J-55 46' 2721' 13-1/2" 998 cu ft PF 'E"/432 cu ft "G" 7-5/8" 29. 7# NT95HS 40' 12998' 9-7/8" 2289 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 4" ~s~f MD~ v~, 3-1/2", 13CR80 12388' 12299' 12615'- 12635' 10296'- 10086' 12655'-12667' 10101'-10110' 26. ACID, FRACTURE, CEMENT,SQUEEZE, ETC. 12697'-12717' 10132'-10148' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12759'-12769' 10179'-10186' 12785'-12797' 10198'-12206' Freeze protected tubing and annulus w/ 12801'-12821' 10209'-10224' 82 bbls d/esel 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 3/6/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESI~ JGAS-OIL RATIO I ]'EST PERIOD Flow Tubing Casing Pressure CALCULATED DIL-BBL GAS-MCF ~VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence et oil, gas or water. Submit core chips. RECEIVED APR 1 1994 Ai~si¢~ 0il & Gas Cons. Commission _Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ltkilyariak ~ Top Kekiktuk 11846' 12605' 9409' 10007' FORMAT ~ TEsTS ~ 30. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time ol each phase. RECEIVED Gas Cons. Commission herebY certity t t the foregoing is true and correct to the best ot my knowledge Signed iNSTRUCTIONS General: '[his form is designed for submitting a complete and correct welt completion report and log on ses in Naska. . · lion, steam iniecti°n.' air iniecti°n' salt ~, woes of lands and lea .. ,.,,,~ iniection, wate. r !.n!e_c for in-sltu combustion ~'" "- . · -...,,,ice Welts: u,,~ ,-2~.,,ation, iniecu°~ 1: Classification r disp°sal' water supply '"' in, iteltWea~ 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 ' I~ 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 7 Submit a separate form for each additional interval to be separately produced, showing the in item 2 · . ... ,,nh interval. (,DF, KB, etc.). data pertinem item 21: Indicate whether from ground level (,GL) or other elevation Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27: Method of operation: Flowing, GaS Lift, Rod pump, Hydraulic Pump, Submersible, water iection, Gas Iniecti°n' ShUt-in, Other-explain' Item 28: if no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONt PAGE: 1 WELL: 2-60/U-13 MPI BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PEP~IT: APPROVAL: ACCEPT: 12/31/93 02:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 01/01/94 ( 1) TD: 0'( 0) 01/02/94 ( 2) TD: 2294' (2294) 0!/03/94 ( 3) Ti':: 2735' ( 441) 01/04/94 ( 4) TD: 2735' ( 0) 0!/~'5/94,J ( 5) 4741' (2006) ORIENT BHA MW: 8.7 VIS:300 START RIG MOVE FROM WELL 2-24/M-12 @0800 HRS 12/31/93. MOVE AND SPOT RIG ON WELL 2-60/U-13, R/U. FILL PITS START MIXING SPUD MUD, N/U DIVERTER, 20" RISER, R/U CUTTING WASHER & BAGGING UNIT. MIX SPUD MUD, N/U, LOAD PIPE IN SHED & STRAP. THAW OUT AIR TO CLUTCHES ON DRAWORKS, CHANGE OUT PIPE HANDLER ON TOP DRIVE. STAND BACK 2600' OF DRILL PIPE IN DERRICK. R/U ATLAS WIRELINE UNIT W/ GYRODATA. P/U BHA AND ORIENT MTR W/ MWD. R/D ATLAS WIRELINE UNIT MW: 9.1 VIS:125 DRLG TO 391' REPAIR CUTTINGS WASHER. DRLG AND GYRO SURVEY F/ 391-1819' SHORT TRIP 7 STDS. DRLG AND SURVEY TO 2294' N/D RISER & DIVERTER MW: 9.1 VIS:il0 DRILL AND SURVEY F/ 2294-2735' CBU. SHORT TRIP. CIRC HOLE CLEAN. TRIP OUT LAY DOWN BHA. R/U CSG RUNNING TOOLS. RUN 68 JTS !0 3/4" 45.5# CASING W/ HOWCO FLOAT EQUIP. M/U FMC CSG HANGER AND LANDING JT, LAND CSG W/ FLOAT SHOE @2720.67' CIRCULATE. R/U HALLIBURTON, TEST LINES. R/D CSG RUNNING TOOLS & REMOVE LANDING JT. N/D RISER, HYDRIL, DIVERTER. DRILL OUT CMT & FLT EQUIP MW: 9.0 VIS: 57 R/U HALLIBURTON & DID TOP JOB DOWN 10 3/4 X 13 1/2 ANNULUS. NU & TEST FMC SPEED HEAD. NU SAFETY BOSS SPOOL, RISER, BOP STACK & LINES. TEST BOPE. INSTALL WEAR RING. SERVICE RIG & TOP DRIVE. P/U BHA & ORIENT. TRIP IN. CUT DRILL LINE. R/U ATLAS WIRE LINE & GYRODATA. P/U 63 JTS 5" DRILL PIPE, TAG CEMENT @2622' DRILL OUT CMT & FLOAT COLLAR. DRILLING MW: 9.2 VIS: 55 DRILL CEMENT TO FLOAT COLLAR @ 2642. TEST CASG TO 2500PSI FOR 30 MIN. DRILL SHOE TRACK AND 10' NEW HOLE TO 2745' CBU. LEAKOFF TEST TO 15.3 PPG EMW. DRILL TO 2803. SURVEY W/GYRODATA. DRILL TO 3668. SLIDING TO BUILD THE ANGLE. SHORT TRIP TO CASING SHOE. CONTINUE DRILLIN TO 4741, SLIDING TO BUILD ANGLE. RECEIVED APR .. Oil &. Gas Cons. Commission Anchorage WELL : 2-60/U-1 OPEPATION: RiG : DOYON 15 PAGE: 2 01/06/94 ( 6) TD: 5835' (1094) 01/07/94 ( 7) TD: 6800' ( 965) 0!/08/94 ( 8) T2: 7752' ( 952) 01/09/94 ( 9) T2: S900' (1148) /10/94 (10) Ti: 2'375' ( 475) 0!/11/94 (11) Ti~ 1©707' (1332) 01/12/94 (12) Ti: i 0914' ( 207) DRILLING MW: 9.3 VIS: 52 DRILLING, LOST 1 MUD PUMP & ASSEMBLY WAS STARTING TO BUILD. POOH FOR BIT AND BHA CHANGE. CIRC UNTIL HOLE CLEANED UP. TOP DRIVE-CHANGE AND PIPE HANDLER PROBLEM. P/U DP AND RIH TO SHOE. RIG SERVICE AND MWD. RIG TO 4497 HOOK UP TOP DRIVE TO REAM. REAM F/4497 T/5090. DRILLING F/5090 T/5835. DRILLING MW: 9.5 VIS: 46 DRILLING TO 6161. CIRCULATE. POOH. SWABBING, BACK REAMED F/5757 T/4627. SERVICED THE TOP DRIVE. FINISH POOH, CHANGED THE BHA AND RIH. SERVICED THE RIG. RIH. REPAIR DRAWWORKS CHAIN. FINISH RIH -- NO PROBLEMS. DRILLING AND SLIDING F/6161 T/6800. RIH MW: 9.5 VIS: 52 DRILLING AND SLIDING TO 7274' (HIT COAL SEAM @ 6796'). CIRCULATED FOR A SHORT TRIP. SHORT TRIP F/7274 T/6035. 25K OVERPULL AT 6190' NO OTHER TIGHT SPOTS ENCOUNTERED. DRILL T/7752' ROP DROPPED TO <7 FPH W/ VARIABLE TORQUE. CIRCULATE. POOH #1 TURBINE FAILURE, POOH, SERVICE THE RIG, RIH DRILLING MW: 9.6 VIS: 48 FINISH RIH. DRILLING F/7752 T/8900. HAVE BEEN IN BLACK SHALE AT I0 FPH FOR THE LAST 2 HOURS. WILL BE PULLING OUT OF HOLE TO iNSTALL SEC PDC BIT AND TEST BOP'S. (1 DAY EARLY). DRILLING MW: 9.7 VIS: 47 DRILLING T/89!4. BIT SLOWED TO <10FPH. CIRCULATE. POOH. TEST BOP'S. TEST WAS WITNESSED BY AOGCC REP: L.GRIBALDI. CHANGE BHA- NEW MOTOR, NEW MWD. CUT THE DRILLING LINE. RIH. SERVICE TOP DRRIVE AND TEST MWD AT SURFACE CASING SHOE. RIH T/8804. WASH AND REAM TO BOTTOM. DRILLING AND SLIDING F/8914' T/9375' CBU FOR BIT TRIP MW: 9.7 VIS: 48 DRILLING F/9375 T/10107' WAS ABLE TO SLID AS NEEDED UNTIL 10600' HAD DIFFICULTY HOLDING TOOL FACE. DECIDED TO CHANGE BITS. AVG. ROP WITH THIS BIT WAS 90 FPH. CIRCULATED BOTTOMS UP FOR TRIP. WILL BE DROPPING CHECKSHOT SURVEY. DRILLING MW:10.0 VIS: 52 CBU - DROP ~'~HE~K-SHOTO- SURVEY. POOH AND RETRIEVE SURVEY. CHANGE BHA. SERVICE THE RIG. RIH AND TEST MWD AT SHOE. RIH TO BOTTOM, NO FILL. DRILL F/10707 T/10914. TOP OF TUFFS @ 10756. RECEIVED A¥".:?,?.~ Oi! & Gas Cons. Commission WELL : 2-60/U-1 OPERATION: RIG : DOYON 15 PAGE: 3 01/13/94 (13) TD:Ii088' ( 174) 01/14/94 (14) T~:i1494' ( 406) 0!/15/94 (15) T2:!i891' ( 397) 01/!6/94 (16) TD:i!932' ( 41) 0!/!7/94 (17) T~i~;2099' ( 167) 0]/~Q/94 (18) Y[?~;~227' ( 128) DRILLING MW:10.0 VIS: 51 DRILLING F/10914 T/11055. ROP VARIED FROM 10 TO 27 FPH, GENERALLY SLOWING DURING THE LAST 4 HOURS ON #7. CIRC AND THAW PIPE HANDLER. POOH. HAD TO BACK REAM THE 1ST FOUR STANDS. CHANGE THE BHA AND RIH TO SHOE. CUT THE DRILLING LINE AND TEST MWD. RIH TO BOTTOM. DRILL TO 11088. DRILLING MW:10.0 VIS: 52 DRILLING F/11088 T/11446. SHORT TRIP F/11446 - T/10707' HOLE IN GOOD SHAPE. DRILLING F/11446' TO 11494' DRILLING MW:10.0 VIS: 51 DRILLING FROM 11494' T/11891. BASE OF HRZ (TOP OF ITLIKLYRIAK) AT 11797 MD. 9427 TVD BKB.. ROP SLOWED TO +/- 7 FPH IN THE LIMESTONE. DRILLING MW:10.0 VIS: 53 DRILLING F/!1891 T/ 11951. TORQUE BOBBLED A COUPLE OF TIMES. DECIDED TO PULL THE BIT. CBU AND POOH TO CASING SHOE. REMOVE PIPE HANDLER AND IBOP CLOSER FROM TOP DRIVE. POOH AND CHANGE BIT AND BHA. RIH TO SURFACE CASING SHOE. CHANGE SWIVEL PACKING ON TOP DRIVE. TEST MWD. INSTALL PIPE HANDLER AND IBOP CLOSER ON TOP DRIVE. RIH TO BOTTOM. HOLE IN GOOD SHAPE. DRILLING F/11915 T/11932 DRILLING MW:10.0 VIS: 54 DRILLING F/t1932 T/12099. ROP STEADY AT 7FPH. TORQUE - SSTEADY. BOP TEST IS DUE ON 1/16, RECEIVED VARIANCE TO TEST ON NEXT TRIP BY AOGCC REP J. HERRING. DRILLING MW:10.0 VIS: 49 DRILLING ['/12099 T/!2227. ROP VARIES =/- 5 TO 7 FPH. 01/!9/94 (19) TD:12263' ( 36) /29/94 (20) :_ i.;18' ( 155) RIH MW:10.0 VIS: 53 DRILLING F/12227 T/12263. ROP WAS SLOWING TO +/- 4-5 FPH. DECIDED TO PULL BIT AND EXTEND LENGTH OF BELLY ON ROTATING ASSEMBLY. DROP SURVEY. POOH . TEST BOP'S AND INSTALL WEAR RING. VIEWING WAIVED BY AOGCC REP: J. SPALDING. CUT BELL NIPPLE WHERE IT WAS INTERFERING W/STRIPPER RUBBER. (APPARENTLY RIG SUBSIDED) CHANGE BIT AND BHA, NEW MWD AND JARS. PUT NEW IBS ON TOP STAB AND RIH TO SHOE. CUT DRILLING LINE AND TEST MWD. CHANGED OUT 23 JTS "G" PIPE WHILE RIH. DRILLING MW: 9.9 VIS: 56 DRILLING TO 12338' SHORT TRIP - 10 STANDS - TO 11418. TIGHT AT 11987, TOOK 30K OVER. DRILLING AHEAD TO 12418'. RECEIVED APR 1.3 i994 Oil & Gas Cons. Oommission Anchorage WELL : 2-60/U-1 OF~[RATION: RiG : DOYON 15 PAGE: 4 01/2!/94 (21) TZ:12618' ( 200) 01/22/94 (22) TP' ~.f_~731' ( 113) 0!./2~/94 (23) 2941' ( 210) 0!./24/94 (24) Ti: i 2010' ( 69) 0~,/2~/94 (25) Ti : ii'.010' ( O) 01/26/94 (26) Ti''2010' ( 0) DRILLING MW:10.0 VIS: 52 DRILL AND SURVEY T/!2365. CIRCULATE. SHORT TRIP F/12365 T/11449. WASH AND BACKREAM OUT 2 TIGHT SPOTS - 11957 & 11681. DRILL AND SURVEY TO 12618. SHORT TRIP F/12601 T/12618. BACKREAM OUT 2 TIGHT SPOTS, 11957 & 11681'. DRILL AND SURVEY 12601 TO 12618. TIH W/ NEW BIT MW:10.0 VIS: 53 DRILL AND SURVEY T/12731. ROP SLOWED TO 6'PH. WASH AND BACKREAJ4 OUT TIGHT SPOT AT 12691. CIRCULATE HIGH VIS SWEEP. TRIP OUT FOR BIT - SLM. WASH AND BACKREAM - WORKOUT TIGHT SPOT AT 9552 TO 9281. TRIP OUT, SLM. L/D MWD, STAB, J.B AND CHANGE OUT BIT. TRIP IN W/NEW BIT %11. DRILLING MW:10.1 VIS: 57 TRIP IN TO 12600. WASH AND REAM F/12600 T/12731. DRILL TO 12871. SERVICE THE TOP DRIVE. DRILL TO 12897. SERVICE THE RIG, THAW PIPE HANDLER. SHORT TRIP TO 9134-BACKREAM AND WORK OUT TIGHT SPOT 9579 TO 9225. WASH AND REAM 12693 TO 12897. KSW WORKING @ 9159 TO 9363' DRILL TO 12941'. TRIP OUT TO LOG MW:10.1 VIS: 58 DRILLING TO 12991. SHORT TRIP F/12991 T/8798. NO PROBLEMS THRU OLD TIGHT SPOT AREAS. WASH AND REAM TO BOTTOM 12721 TO 12991. DRILL TO TD AT 13010 MD = 10370' TVD AND 10314 SUBSEA. PUMP HI VIS SWEEP. CBU. SHORT TRIP TO 9039. PUMP HI VIS SWEEP, CBU. DROP SURVEY. TRIP OUT TO LOG OPEN HOLE W/ATLAS LOGGING UNIT. DP CONVEYED LOGGING MW:10.1 VIS: 59 TRIP OUT, R/U ATLAS WIRELINE, RIH W/LOGGING TOOLS. UNABLE TO RUN PAST 10600 MD. POOH, R/U DP CONVEYED LOGGING TOOLS, RIH TO 2200. TRiP IN W/DP AND TOOLS TO 2200'. CUT DRILL LINE. TRIP IN TO 10393' MD. M/U SIDE DOOR SUB FOR W/L, CIRCULATE DP VOLUME. CONTINUE RIH W/ TOOLS ON DP TO LOG. CIRCULATING HOLE CLEAN MW:10.3 VIS: 53 RIH W/ ATLAS LOGGING TOOLS ON DP T/ 12400' LOG F/12400 T/12990, F/12990 T/12400. TRIP OUT TO SIDE ENTRY SUB. POOH W/WIRELiNE, L/D ENTRY SUB. TRIP OUT W/DP TO LOGGING TOOLS. R/D ATLAS LOGGING TOOLS. M/U BHA FOR WIPER TRIP. TIH - CLEAN OUT 14' OF FILL TO 13010' CBU - MUD IS VERY VISCOUS. SHORT TRIP T/10158 - NO PROBLEMS. PUMP HI VIS SWEEP, CIRCULATE HOLE CLEAN. RECEIVED Gas Cons. Commission '_Anchora§~ WELL : 2-60/U-1 OPERATION: RIG : DOYON 15 PAGE: 5 0!/~7/94 (27) TD'!3010' ( 0) 01/28/94 (28) Ti~':3010' ( 0) 0!/29/94 (29) T:'--3910' ( 0) 01/20/94 (30) TD'i3010 PB- 0 RUNNING 7-5/8" CASING MW:10.3 VIS: 68 CIRCULATING HI VIS SWEEP. WORK ON PIPE SKATE, CONTINUE CIRCULATING AND RECIPROCATING PIPE WHILE WORKING ON SKATE. TRIP OUT LAYING DOWN 5" DRILL PIPE. STAND BACK 80 STANDS OF 5" IN DERRICK, L/D BHA. PULL WEAR RING, CHANGE RAMS TO 7-5/8" AND TEST. CUT DRILL LINE. R/U TO RUN 7-5/8" CASING. RUN 7-5/8" CASING. RUN WIRELINE GYRO LOG MW: 9.4 VIS: 0 RIH W/315 JTS. OF 7-5/8" CASING. BOTTOME OF SHOE @ 12998.19'. FLOAT COLLAR @ 12915.99' R/U CEMENT HEAD, CIRCULATE W/MUD. FLUSH MUD FROM LINE WITH BRINE. R/U HALLIBURTON, TEST LINES TO 3000 PSI. PUMP 20 BBLS KCL WATER, 70 BBLS ALPHA SPACER, 346 BBLS ll.PPG PREMIUM CEMENT AT 6 BPM 650 PSI, DROP PLUG. DISPLACE WITH RIG PUMP AT 10 BPM, 1500 PS!, 593 BBLS 120 F 9.4 PPG BRINE, BUMP PLUG. HELD 3000PSI ON CASING. CEMENT IN PLACE AT 15:15 HOURS. R/D HALLIBURTON, L/D LANDING JT AND TOOLS. INSTALL AND TEST 7-5/8" PACKOFF (5000PSI) . CHANGE RAMS TO 5", TEST CASING TO 3500 PSI. TEST BOPE. R/U ATLAS WIRELINE, RUN #1 = CCL, JB/6.6" GAUGE RING. RUN #2 = GYRO. ATLAS W/L PERFOkATING MW' 9.4 VIS: 0 W/L RUN #2 = GYRO. W/L RUN #3 = CCL/GR/ACC/VDL/SBT. SERVICE RIG. NIPPLE UP SHOOTING FLANGE AND TEST TO 1500 PSI. W/L RUN #3=4" GUN NO. 1 20' X 4 SPF(CCL MALFUNCTION AFTER 1ST SHOOT). W/L RUN #4 = 4" GUN NO. 2 12' X 4SPF. W/L RUN #5 = 4" GUN NO.3 = 10' AND 20' X 4SPF. W/L RUN #6 = 4" GUN NO. 4 20' AND 12' X 4SPF (MISSFIRE ON ALL SHOTS) W/L RUN #7 = 4" GUN NO. 4 R/R. RUN 3.5" 13CR TUBING MW: 0.0 NaCl W/L RUN #7 = R/R 4" PERF. GUN NO. 4. 20'X12SPF. R/D ATLAS WIRELINE. CHANGE ~%MS TO 3.5". N/D SHOOTING FLANGE. INSTALL FLOW LINE. CHANGE 1BOP AND ACTUATOR ON TOP DRIVE, WHILE CLEANING 3.5" 13 CR. TUBING. TEST 3.5" RAMS. R/U TO RUN 13CR. TUBING. L/D 1 JOINT AND CHANGE OUT 4 TUBING COLLARS DUE GALLED. AT 06:00 WE'VE PICKED UP 272 JTS TUBING AND BAKER PACKER, AND 7 GAS LIFT MANDRELS. RECEIVED ,'; h :',,::2,'.~; OfJ & tbs Cons. Commission Mchera§e. WELL : 2-60/U-1 OPEraTION: RIG : DOYON 15 PAGE: 6 01/31/94 (31) TD-!3010 PS' 0 02/01/94 (32) TY''~ Pi - 0 FREEZE PROT. INJ. WELL MW: 0.0 NaCl RUN 3.5" 13CR. TUBING. P/U SSSV, INSTALL AND TEST CONTROL LINE. RUN 3.5" 13CR TUBING, TOTOAL OF 388 JTS. M/U HANGER AND TEST CONTROL LINES 5000PSI, LAND HANGER IN TUBINBG SPOOL. L/D LANDING JOINT, RUNNING TOOLS AND CONTROL LINE SPOOL. M!PPLE DOWN BOPE. NIPPLE ADAPTER FLANGE AND TEST TO 5000PSI. TEST LINES TO 5000PSI. N/U TREE AND TEST TO 5000 PSI, PULL BPV. R/U LINES AND TEST TO 4500 PSI, DISPLACE ANNULUS TO TREATED BRINE. DROP PACKER SETTING BALL(I-5/16") . SET PACKER W/4000 PSI, TEST ANNULUS TO 3500PSi. INJECT 265 BBLS BRINE, DISPLACED W/ 66 BBLS DIESEL. FREEZE PROTECT TUBING AND ANNULUS TO 2000' 82 BBLS DIESEL. FREEZE PROTECT INJECTING WELL 2-54/Q-12. RIG RELEASED AND MOVED MW: 0.0 NaCl 02/71/94 (33) TD-13010 PB- 0 MW: 0.0 NaCl 0~/nl/94~, ~, (34) TE-~}010 Pn:' 0 RIG RELEASED AND MOVED MW: 0.0 NaCl FREEZE PROTECT INJECTION WELL 2-54/Q-12 AND INSTALL BPV IN 2-60/U-30. RELEASE RIG AT 08:00 HOURS ON 1/31/94. S~S~i~.TURE: (drillin~ superintendent) DATE: SURVEY REPORT B.P. EXPLORATION MPI UNIT WELL ENDICOTT #2-60/U-13 ENDICOTT FIELD, ALASKA FEBRUARY 14, 1994 ORIGINAL t41C OFILMED RECEIVED Oas Corm. Commission Anchorage A Gyroda t a D i re c t i on a i Survey for B.P. EXPLOP~ATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204 Run Date: 28-Jan-94 02:33:40 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.352000 deg. N Sub-sea Correction from Vertical Reference: 58 ft. Bearings are Relative to True North Proposed Well Direction: 253.060 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona I B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0194G204 5/8" ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERT I CAL SUB SEA VERT I CAL SEVERITY DEPTH DEPTH SECTION deg feet feet feet /100ft DIST. feet 0.0 0.00 0.00 0.00 0.0 -58.0 0.0 Survey 100 - 12900 FT GYRODATA MULTISHOT SURVEY IN 7 5/8 CASING(G204) ALL DEPTHS ARE REFERENCED TO R.K.B. OF 58 FEET ABOVE SEA LEVEL CLOSURE AZIMUTH deg. 0.0 0.0 Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .20 311.12 .20 100.0 42.0 .1 200.0 .08 82.99 .26 200.0 142.0 .1 300.0 .18 28.43 .15 300.0 242.0 -.1 400.0 .06 57.78 .13 400.0 342.0 -.2 500.0 .07 91.27 .04 500.0 442.0 -.3 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 00.0 .69 290.12 .76 600.0 542.0 .1 00.0 2.70 271.55 2.06 699.9 641.9 2.8 00.0 4.51 269.96 1.82 799.7 741.7 8.8 00.0 5.60 268.73 1.10 899.3 841.3 17.3 00.0 5.73 270.86 .25 998.8 940.8 26.7 00.0 5.41 271.76 .33 1098.4 1040.4 35.9 00.0 5.05 268.12 .49 1198.0 1140.0 44.7 00.0 4.72 269.14 .34 1297.6 1239.6 52.9 00.0 4.35 273.42 .50 1397.3 1339.3 60.4 00.0 4.32 279.79 .48 1497.0 1439.0 67.3 00.0 4.39 280.22 .08 1596.7 1538.7 74.1 00.0 2.19 286.51 2.23 1696.5 1638.5 79.1 00.0 1.04 217.02 2.07 1796.5 1738.5 81.4 00.0 .92 202.21 .28 1896.5 1838.5 82.6 00.0 .12 236.87 .82 1996.5 1938.5 83.2 .2 311.1 .3 321.6 .4 354.1 .6 8.3 .6 17.7 .11 N .13 W .23 N .19 W .38 N .04 W .55 N .08 E .57 N .18 E 37.9 271.8 1.19 N 37.93 W 47.1 271.4 1.19 N 47.05 55.6 271.0 .98 N 55.56 W 63.5 271.0 1.14 N 63.46 W '71.0 271.6 2.01 N 70.95 W 78.5 272.4 3.33 N 78.44 W 84.2 273.1 4.55 N 84.04 W 86.5 272.9 4.38 N 86.41 W 87.3 271.9 2.91 N 87.26 W 87.7 271.4 2.11 N 87.65 W .8 337.3 .78 N .32 W 3.4 287.9 1.05 N 3.24 W 9.6 276.6 1.11 N 9.53 W 18.4 273.1 1.00 N 18.35 W 28.2 272.0 .97 N 28.22 W A Gyro da t a D i r e c t i ona B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204 MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg feet /100ft 2100.0 .32 355.20 .39 2096.4 2200.0 .26 350.59 .07 2196.4 2300.0 .22 343.60 .04 2296.4 2400.0 .33 355.94 .12 2396.4 2500.0 .27 340.14 .10 2496.4 2600.0 .43 333.30 .16 2596.4 2700.0 .52 344.33 .13 2696.4 2800.0 .37 322.50 .23 2796.4 2900.0 2.84 267.88 2.64 2896.4 3000.0 4.93 258.09 2.18 2996.1 3100.0 5.96 258.45 1.03 3095.7 3200.0 7.46 258.26 1.50 3195.0 3300.0 9.52 257.87 2.06 3293.9 3400.0 10.73 256.59 1.23 3392.3 3500.0 14.11 253.49 3.45 3489.9 3600.0 17.82 250.64 3.79 3586.0 3700.0 20.81 251.69 3.01 3680.4 3800.0 24.43 252.41 3.64 3772.6 3900.0 29.01 252.75 4.58 3861.9 4000.0 32.65 252.34 3.65 3947.7 4100.0 34.36 252.15 1.71 4031.1 4200.0 35.36 250.91 1.23 4113.1 4300.0 36.53 250.56 1.18 4194.1 4400.0 36.73 250.32 .25 4274.3 4500.0 39.14 249.68 2.44 4353.2 1 Survey SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 2038.4 2138.4 2238.4 2338.4 2438.4 2538.4 2638.4 2738.4 2838.4 2938.1 3037.7 3137.0 3235.9 3334.3 3431.9 3528.0 3622.4 3714.6 3803.9 3889.7 3973.1 4055.1 4136.1 4216.3 4295.2 Page HORIZONTAL COORDINATES feet 83.3 83.2 83.2 83.1 83.0 83.1 83.2 83.3 85.8 92.5 101.9 113.5 128.2 145.8 167.2 194.7 227.8 266.2 311.1 362.3 417.5 474.6 533.3 592.9 654.3 87.8 271.5 87.9 271.8 88.0 272.1 88.1 272.4 88.2 272.7 88.5 273.1 88.8 273.6 89.2 274.0 91.8 274.0 98.4 273.2 107.6 271.9 119.0 270.5 133.5 269.2 150.7 267.8 171.7 266.2 198.5 264.2 230.8 262.4 268.7 260.9 313.2 259.7 364.1 258.7 419.0 257.9 475.8 257.1 534.2 256.4 593.6 255.8 654.7 255.3 2.33 N 87.76 W 2.83 N 87.82 TM 3.24 N 87.92 3.71 N 87.99 W 4.21 N 88.09 W 4.76 N 88.34 W 5.54 N 88.63 W 6.23 N 88.95 W 6.40 N 91.62 W 5.42 N 98.30 W 3.50 N 107.58 W 1.14 N 119.02 W 1.92 S 133.46 W 5.82 S 150.60 W 11.44 S 171.34 W 19.98 S 197.46 30.63 S 228.76 42.46 S 265.33 W 55.90 S 308.20 W 71.27 S 357.05 W 88.10 S 409.62 W 106.22 S 463.82 W 125.58 S 519.23 W 145.56 S 575.44 W 166.58 S 633.19 W A Gyrodata B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204 MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg feet /lOOft 4600.0 41.95 249.40 2.82 4429.2 4700.0 44.18 248.92 2.25 4502.2 4800.0 46.18 250.05 2.15 4572.7 4900.0 47.31 250.21 1.14 4641.2 5000.0 48.13 249.42 1.01 4708.5 5100.0 47.32 248~68 .98 4775.8 5200.0 46.72 247.85 .85 4843.9 5300.0 45.80 249.00 1.24 4913.1 5400.0 45.95 249.51 .39 4982.7 5500.0 45.22 248.31 1.12 5052.7 5600.0 44.48 249.17 .95 5123.6 5700.0 44.01 248.37 .73 5195.2 5800.0 43.40 247.78 .73 5267.5 5900.0 42.53 248.07 .89 5340.7 6000.0 42.11 248.28 .44 5414.6 6100.0 41.27 247.92 .87 5489.3 6200.0 42.89 248.53 1.67 5563.5 6300.0 44.31 250.25 1.85 5635.9 6400.0 44.27 249.89 .26 5707.5 6500.0 43.99 249.79 .29 5779.2 6600.0 44.15 249.10 .51 5851.1 6700.0 44.18 249.39 .20 5922.8 6800.0 45.90 248.91 1.75 5993.5 6900.0 46.90 249.00 1.00 6062.5 7000.0 46.88 249.06 .05 6130.8 Directional Survey SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 4371.2 719.1 719.4 254.7 4444.2 787.2 787.4 254.3 4514.7 858.0 858.1 253.9 4583.2 930.7 930.8 253.6 4650.5 1004.6 1004.6 253.3 4717.8 1078.4 1078.4 253.0 4785.9 1151.3 1151.3 252.7 4855.1 1223.3 1223.4 252.5 4924.7 1294.9 1295.1 252.3 4994.7 1366.2 1366.4 252.1 5065.6 1436.5 1436.8 251.9 5137.2 1506.1 1506.4 251.8 5209.5 1574.9 1575.4 251.6 5282.7 1642.8 1643.4 251.5 5356.6 1709.9 1710.6 251.3 5431.3 1776.1 1777.0 251.2 5505.5 1842.9 1844.0 251.1 5577.9 1911.7 1912.9 251.1 5649.5 1981.5 1982.7 251.0 5721.2 2051.0 2052.3 251.0 5793.1 2120.4 2121.8 250.9 5864.8 2189.9 2191.5 250.9 5935.5 2260.5 2262.2 250.8 6004.5 2332.7 2334.6 250.8 6072.8 2405.5 2407.5 250.7 Page 3 HORIZONTAL COORDINATES feet 189.31 S 694.07 W 213.60 S 757.88 \ 238.44 S 824.30 263.19 S 892.79 W 288.72 S 962.23 W 315.17 S 342.26 S 368.83 S 394.26 S 419.96 S 445.53 S 470.80 S 496.60 S 522.21 S 547.25 S 572.05 596.90 621.16 644.96 668.96 693.37 718.06 743.25 769.26 795.38 1031.33 W 1099.28 W 1166.46 W 1233.58 W 1300.22 W 1365.94 W 1430.97 W 1495.07 W 1558.23 W 1620.74 W 1682.46 ~' 1744.69 . 1809.23 W 1874.88 W 1940.24 W 2005.36 W 2070.51 W 2136.62 W 2204.20 W 2272.37 W A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI I/NIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg feet feet feet /100ft 7100.0 47.20 247.43 7200.0 46.92 250.40 7300 . 0 46 · 92 249 . 13 7400 . 0 47 · 94 249 . 83 7500.0 48.48 249.92 1.24 6198.9 2.20 6267.1 .93 6335.4 1.14 6403.0 .55 6469.7 7600.0 48.66 250.99 7700.0 48.52 250.65 7800.0 48.82 250.12 7900.0 48.81 251.33 8000.0 49.51 253.13 .82 6535.8 .29 6602.0 .50 6668.0 .91 6733.9 1.53 6799.2 8100.0 48.40 251.64 8200.0 48.34 252.22 8300.0 48.31 253.83 8400.0 46.89 253.72 8500.0 46.80 253.93 1.58 6864.9 .43 6931.3 1.21 6997.8 1.42 7065.3 .18 7133.7 8600.0 46.88 254.21 8700.0 47.07 254.10 8800.0 46.74 254.39 8900.0 46.21 253.77 9000.0 46.67 253.56 .22 7202.1 .21 7270.3 .39 7338.6 .69 7407.5 .48 7476.4 9100.0 47.69 253.97 9200.0 47.99 254.07 9300.0 47.75 253.47 9400.0 45.38 253.78 9500.0 45.70 254.41 1.06 7544.4 .31 7611.5 .50 7678.6 2.38 7747.3 .55 7817.4 6140.9 2478.4 6209.1 2551.4 6277.4 2624.3 6345.0 2697.8 6411.7 2772.3 6477.8 2847.2 6544.0 2922.1 6610.0 2997.1 6675.9 3072.3 67.41.2 3148.0 6806.9 3223.4 6873.3 3298.1 6939.8 3372.8 7007.3 3446.6 7075.7 3519.5 7144.1 3592.5 7212.3 3665.6 7280.6 3738.6 7349.5 3811.1 7418.4 3883.5 7486.4 3956.9 7553.5 4031.0 7620.6 4105.1 7689.3 4177.7 7759.4 4249.1 CLOSURE DIST. AZIMUTH feet deg. 2480.7 250.6 2553.8 250.6 2626.8 250.6 2700.5 250.5 2775.0 250.5 2850.0 250.5 2925.0 250.5 3000.1 250.5 3075.3 250.5 3151.0 250.6 3226.3 250.6 3301.0 250.6 3375.7 250.7 3449.4 250.8 3522.2 250.8 3595.1 250.9 3668.1 251.0 3740.9 251.0 3813.4 251.1 3885.7 251.1 3959.0 251.2 4033.1 251.2 4107.1 251.3 4179.7 251.3 4251.0 251.4 Page 4 HORIZONTAL COORDINATES feet 822.51 S 2340.33 W 848.84 S 2408.61 W 874.10 S 2477.14 899.91 S 2546.11 ~ 925.56 S 2616.12 W 950.64 S 975.28 S 1000.50 S 1025.34 S 1048.42 S 1071.23 S 1094.42 S 1116.22 S 1136.85 S 1157.17 S 1177.18 S 1197.14 S 1216.97 S 1236.85 S 1257.24 S 1277.74 S 1298.15 S 1318.87 S 1339.34 S 1358.89 S 2686.78 W 2757.61 W 2828.34 W 2899.38 W 2971.42 W 3043.29 W 3114.35 W 3185.77 W 3256.67 W 3326.73 W 3396.87 T" 3467.20 3537.47 W 3607.19 W 3676.73 W 3747.16 W 3818.42 W 3889.63 W 3959 o 28 W 4027.92 W A Gyroda t a D i r e c t i ona 1 Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204 Page MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg feet /100ft SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 9600.0 46.13 254.30 .44 7886.9 9700.0 46.34 254.61 .30 7956.1 9800.0 46.93 254.61 .59 8024.8 9900.0 47.34 254.58 .41 8092.8 10000.0 46.64 254.47 .70 8161.0 7828 7898 7966 8034 8103 .9 4320.9 4322.7 251.4 · 1 4393.1 4394.8 251.5 .8 4465.8 4467.4 251.5 .8 4539.0 4540.6 251.6 · 0 4612.1 4613.6 251.6 1378.26 S 1397.61 S 1416.91 S 1436.38 S 1455.89 S 4097.09 W 4166.67 w 4236.76 4307.42 W 4377.90 W 10100.0 46.62 254.89 .31 8229.7 10200.0 45.93 254.89 .68 8298.8 10300.0 45.64 253.25 1.21 8368.5 10400.0 45.99 255.11 1.38 8438.2 10500.0 46.07 254.88 .19 8507.7 8171 8240 8310 8380 8449 .7 4684.8 4686.2 251.7 .8 4757.0 4758.4 251.7 .5 4828.7 4830.0 251.7 .2 4900.4 4901.6 251.8 .7 4972.3 4973.5 251.8 1475.09 S 1493.93 S 1513.60 S 1533.14 S 1551.77 S 4448.01 W 4517.78 W 4586.69 W 4655.67 W 4725.19 W 10600.0 46.69 255.28 .69 8576.6 10700.0 46.53 253.98 .96 8645.3 10800.0 46.64 254.02 .11 8714.1 10900.0 46.56 253.70 .24 8782.8 11000.0 46.86 254.98 .98 8851.3 8518 8587 8656 8724 8793 · 6 5044.7 5045.7 251.9 · 3 5117.3 5118.3 251.9 · 1 5189.9 5190.9 251.9 · 8 5262.6 5263.5 252.0 .3' 5335.3 5336.3 252.0 1570.41 S 1589.66 S 1609.69 S 1629.88 S 1649.53 S 4795.14 W 4865.21 W 4935.03 W 5004.82 W 5074.90 W 11100.0 46.90 254.76 .17 8919.7 11200.0 46.17 256.35 1.36 8988.5 11300.0 45.35 254.96 1.29 9058.3 11400.0 44.47 253.97 1.13 9129.1 11500.0 42.52 254.63 2.00 9201.6 8861 8930 9000 9071 9143 .7 .5 .3 .1 .6 5408.3 5409.2 252.0 5480.8 5481.6 252.1 5552.3 5553.1 252.1 5622.9 5623.6 252.2 5691.7 5692.4 252.2 1668.58 S 1686.69 S 1704.43 S 1723.34 S 1741.97 S 5145 . 37 ~' 5215.64 5285.04 W 5353.06 W 5419.30 W 11600.0 41.26 254.92 1.27 9276.0 11700.0 40.20 255.16 1.07 9351.8 11800.0 39.26 256.36 1.22 9428.7 11900.0 38.12 256.06 1.16 9506.8 12000.0 37.77 256.24 .36 9585.6 9218.0 9293.8 9370.7 9448.8 9527.6 5758.5 5759.1 252.2 5823.7 5824.3 252.2 5887.5 5888.1 252.3 5949.9 5950.4 252.3 6011.3 6011.8 252.4 1759.51 S 1776.35 S 1792.08 S 1806.97 S 1821.69 S 5483.73 W 5546.77 W 5608.72 W 5669.42 W 5729.12 W A Gyro da t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, JOb Number: AK0194G204 5/8" ALASKA 'Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg /lOOft VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 12100.0 37.72 257.05 .49 12200.0 36.53 256.66 1.21 12300.0 36.82 259.17 1.53 12400.0 38.26 259.25 1.45 12500.0 39.28 257.44 1.53 9664.7 9606.7 6072.4 6072.8 252.4 9744.4 9686.4 6132.6 6133.0 252.4 9824.6 9766.6 6192.1 6192.4 252.5 9903.9 9845.9 6252.7 6252.9 252.6 9981.9 9923.9 6315.1 6315.2 252.6 1835.83 S 5788.68 W 1849.56 S 5847.44 W 1862.06 S 5905.82 ~) 1873.46 S 5965.68 ~ 1886.12 S 6027.00 W 12600.0 40.12 258.62 1.13 12700.0 41.76 261.11 2.31 12800.0 42.74 257.58 2.57 12900.0 43.91 261.20 2.75 10058.8 10000.8 6378.7 6378.8 252.7 10134.4 10076.4 6443.7 6443.8 252.7 10208.4 10150.4 6510.5 6510.6 252.8 10281.1 10223.1 6578.7 6578.7 252.9 1899.36 S 1910.87 S 1923.32 S 1935.92 S 6089.49 W 6153.98 W 6220.02 W 6287.42.W Final Station Closure: Distance: 6578.71 ft Az: 252.89 deg. A Gyr oda t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0194G204S 5/8" ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg feet feet feet /100ft CLOSURE DIST. AZIMUTH feet deg. 0.0 0.00 0.00 0.00 0.0 -58.0 0.0 0.0 0.0 SURVEY DATA INTERPOLATED TO SUBSEA TVD AT 100 FT. INTERVALS 100 - 12900 FT GYRODATA MULTISHOT SURVEY IN 7 5/8 CASING(G204) ALL DEPTHS ARE REFERENCED TO R.K.B. OF 58 FEET ABOVE SEA LEVEL Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 158.0 .13 178.81 .23 158.0 100.0 .1 258.0 .14 51.35 .19 258.0 200.0 .0 358.0 .11 45.46 .14 358.0 300.0 -.2 458.0 .06 77.20 .08 458.0 400.0 -.3 558.0 .43 206.61 .45 558.0 500.0 -.1 658.0 1.86 279.34 1.51 658.0 600.0 1.7 758.2 3.75 270.63 1.92 758.0 700.0 6.3 858.5 5.15 269.24 1.40 858.0 800.0 13.7 959.0 5.68 269.99 .60 958.0 900.0 22.8 1059.4 5.54 271.40 .30 1058.0 1000.0 32.2 1159.9 5.20 269.58 .43 1158.0 1100.0 41.2 1260.3 4.85 268.74 .40 1258.0 1200.0 49.6 1360.6 4.49 271.74 .44 1358.0 1300.0 57.4 1460.9 4.33 277.30 .49 1458.0 1400.0 64.6 1561.2 4.37 280.05 .23 1558.0 1500.0 71.4 1661.4 3.04 284.09 1.40 1658.0 1600.0 77.1 1761.5 1.48 243.76 2.13 1758.0 1700.0 80.5 1861.5 .96 207.90 .97 1858.0 1800.0 82.2 1961.5 .43 223.54 .61 1958.0 1900.0 83.0 .3 317.2 .4 340.4 .6 2.3 .6 13.7 .18 N .16 W .32 N .10 W .48 N .06 E .56 N .14 E .8 354.3 .69 N .26 W 3.4 308.6 .94 N 2.02 W 9.6 281.4 1.08 N 6.90 W 18.4 274.6 1.05 N 14.69 W 28.2 272.4 .98 N 24.17 W 271.9 271.6 271.2 271.0 271.4 37.9 47.1 55.6 63.5 71.0 1.10 N 33.99 1.19 N 43.39 1.06 N 52.18 W 1.08 N 60.35 W 1.67 N 68.02 W 78.5 272.1 2.82 N 75.53 W 84.2 272.8 4.08 N 81.88 W 86.5 273.0 4.44 N 85.50 W 87.3 272.3 3.48 N 86.94 W 87.7 271.6 2.42 N 87.50 W A Gyrodata B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0194G204S 5/8" ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. Directional Survey 2061.5 .24 309.70 2161.6 .28 352.36 2261.6 .24 346.29 2361.6 .29 351.20 2461.6 .29 346.21 DOGLEG VERT I CAL SUB SEA VERT I CAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg feet feet feet feet deg. /100ft 20 21 22 23 24 58.0 58.0 58.0 58.0 58.0 2561.6 .37 335.93 2661.6 .49 340.09 2761.6 .43 330.89 2861.6 1.89 288.85 2961.8 4.13 261.83 .56 .19 .05 .09 .11 25 26 27 28 29 58.0 58.0 58.0 58.0 58.0 3062.2 5.57 258.31 3162.8 6.90 258.33 3263.7 8.77 258.02 3365.1 10.31 257.04 3467.3 13.00 254.50 . 1. 1. 1. 2. 14 15 19 71 36 30 31 32 33 34 58.0 58.0 58.0 58.0 58.0 3570.8 16.74 251.47 3676.3 20.10 251.44 3784.2 23.86 252.29 3895.7 28.81 252.74 4012.4 32.86 252.32 . 3. 3. 4. 3. 47 33 86 52 72 35 36 37 38 39 58.0 58.0 58.0 58.0 58.0 4132.8 34.69 251.74 4255.4 36.01 250.72 4379.6 36.68 250.37 4506.3 39.31 249.66 4639.5 42.83 249.21 . 69 19 54 53 41 40 41 42 43 44 58.0 58.0 58.0 58.0 58.0 56 20 44 47 60 2000.0 83.3 87.8 271.5 2100.0 83.2 87.9 271.7 2200.0 83.2 88.0 272.0 2300.0 83.1 88.1 272.3 2400.0 83.1 88.2 272.6 2500.0 83.1 88.5 273.0 2600.0 83.1 88.8 273.4 2700.0 83.2 89.2 273.8 2800.0 84.8 91.8 274.0 2900.0 89.9 98.4 273.5 3000.0 98.3 107.6 272.4 3100.0 109.2 119.0 271.0 3200.0 122.9 133.5 269.7 3300.0 139.7 150.7 268.3 3400.0 160.2 171.7 266.7 3500.0 186.7 198.5 264.8 3600.0 219.9 230.8 262.8 3700.0 260.1 268.7 261.1 3800.0 309.2 313.2 259.8 3900.0 369.1 419.0 258.6 4000.0 436.3 475.8 257.6 4100.0 507.1 534.2 256.7 4200.0 580.7 593.6 255.9 4300.0 658.3 719.4 255.2 4400.0 746.0 787.4 254.6 Page 2 HORIZONTAL COORDINATES feet 2.25 N 87.72 W 2.64 N 87.80 ~'~ 3.08 N 87.88 3.52 N 87.96 W 4.02 N 88.05 W 4.55 N 88.24 W 5.24 N 88.52 W 5.97 N 88.83 W 6.34 N 90.59 W 5.79 N 95.74 W 4.22 N 104.07 W 2.02 N 114.76 W 1.64 S 128.22 W 4.46 S 144.63 W 9.60 S 164.56 W 17.49 S 189.85 ~ 28.10 S 221.34 , 40.58 S 259.53 W 55.32 S 306.34 W 73.35 S 363.55 W 94.04 S 427.40 W 116.95 S 494.53 W 141.49 S 563.99 W 168.02 S 637.03 W 198.89 S 719.26 W A Gyrodata Di B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204S r e c t i o n a 1 Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERT I CAL SUB SEA VERT I CAL SEVERITY DEPTH DEPTH SECTION deg feet feet feet /lOOft CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4779.2 45.76 249.81 4925.0 47.52 250.01 5073.6 47.53 248.87 5220.4 46.53 248.08 5364.5 45.89 249.33 2.17 4558.0 1.11 4658.0 .99 4758.0 .93 4858.0 .69 4958.0 4500 4600 4700 4800 4900 .0 .0 .0 .0 .0 843.3 949.2 1058.9 1166.0 1269.5 858.1 253.9 1004.6 253.5 1078.4 253.1 1223.4 252.7 1295.1 252.3 233.26 S 810.45 W 269.56 S 910.12 ~'~ 308.19 S 1013.05 ,~ 347.67 S 1112.96 W 385.25 S 1209.78 w 5507.5 45.16 248.38 5648.1 44.25 248.78 5786.9 43.48 247.86 5923.4 42.43 248.12 6058.1 41.63 248.07 1.11 5058.0 .84 5158.0 .73 5258.0 .79 5358.0 .69 5458.0 5000 5100 5200 5300 5400 .0 .0 .0 .0 .0 1371.4 1469.9 1565.9 1658.5 1748.4 1436.8 252.1 1506.4 251.9 1575.4 251.6 1710.6 251.4 1777.0 251.3 421.88 S 1305.15 W 457.68 S 1397.19 W 493.21 S 1486.66 W 528.08 S 1572.89 W 561.66 S 1656.61 W 6192.6 42.77 248.48 6330.9 44.30 250.14 6470.4 44.07 249.82 6609.6 44.15 249.13 6749.8 45.03 249.15 1.61 5558.0 1.36 5658.0 .28 5758.0 .48 5858.O .97 5958.0 55OO 5600 5700 5800 5900 .0 .0 .0 .0 .0 1838.0 1933.3 2030.4 2127.1 2225.0 1844.0 251.1 1982.7 251.0 2052.3 251.0 2191.5 250.9 2262.2 250.8 595.07 S 1740.10 W 628.51 S 1829.51 W 661.85 S 1920.89 W 695.75 S 2011.63 W 730.60 S 2103.40 W 6893.5 46.83 248.99 7039.9 47.01 248.41 7186.7 46.96 250.01 7333.5 47.26 249.36 7482.5 48.39 249.91 1.05 6058.0 .52 6158.0 2.07 6258.0 1.00 6358.0 .65 6458.0 6000 6100 6200 6300 6400 .0 .0 .0 .0 .0 2328.0 2434.6 2541.7 2648.9 2759.3 2334.6 250.8 2480.7 250.7 2553.8 250.6 2700.5 250.6 2775.0 250.5 767.57 S 2199.83 ~ 806.21 S 2299.49 845.33 S 2399.52 W 882.74 S 2500.22 W 921.08 S 2603.88 W 7633.5 48.61 250.87 7784.8 48.78 250.20 7936.9 49.07 251.99 8089.5 48.51 251.80 8240.1 48.32 252.86 64 6558.0 47 6658.0 14 6758.0 58 6858.0 74 6958.0 6500.0 6600.0 6700.0 6800.0 6900.0 2872.3 2985.8 3100.3 3215.4 3328.0 2925.0 250.5 3000.1 250.5 3151.0 250.5 3226.3 250.6 3375.7 250.7 958.91 S 2710.53 W 996.68 S 2817.62 W 1033.86 S 2925.98 W 1068.83 S 3035.73 W 1103.16 S 3142.98 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0194G204S 5/8" ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERT I CAL SUBSEA VERT I CAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg feet feet feet feet deg. /lOOft HORIZONTAL COORDINATES feet 8389.2 47.04 253.73 8535.6 46.83 254.03 8682.0 47.03 254.12 8828.1 46.59 254.21 8973.3 46.55 253.62 40 19 21 48 54 70 71 72 73 74 58.0 58.O 58.0 58.0 58.0 7000.0 3438.7 3449.4 250.7 7100.0 3545.5 3595.1 250.8 7200.0 3652.4 3668.1 250.9 7300.0 3758.9 3813.4 251.0 7400.0 3864.2 3885.7 251.1 1134.63 S 3249.03 W 1164.29 S 3351.68 W 1193.54 S 3454.51 1222.56 S 3557.07 1251.79 S 3658.15 W 9120.3 47.75 253.99 9269.3 47.82 253.66 9415.2 45.43 253.88 9558.4 45.95 254.35 9702.8 46.35 254.61 91 44 10 49 31 75 76 77 78 79 58.0 58.0 58.0 58.0 58.0 7500.0 3971.9 4033.1 251.2 7600.0 4082.4 4107.1 251.3 7700.0 4188.6 4251.0 251.3 7800.0 4291.0 4322.7 251.4 7900.0 4395.1 4467.4 251.5 1281.88 S 3761.62 W 1312.51 S 3867.78 W 1342.32 S 3969.75 W 1370.21 S 4068.33 W 1398.15 S 4168.61 W 9848.9 47.13 254.59 9995.6 46.67 254.47 10141.0 46.34 254.89 10284.9 45.68 253.49 10428.5 46.01 255.05 5O 69 46 13 04 8O 81 82 83 84 58.0 58.0 58.0 58.0 58.0 8000.0 4501.6 4540.6 251.5 8100.0 4608.9 4613.6 251.6 8200.0 4714.4 4758.4 251.7 8300.0 4817.9 4830.0 251.7 8400.0 4920.9 4973.5 251.8 1426.42 S 4271.28 W 1455.03 S 4374.79 W 1482.81 S 4476.60 W 1510.63 S 4576.29 W 1538.45 S 4675.48 W 10573.0 46.52 255.17 10718.4 46.55 253.99 10863.9 46.59 253.81 11009.7 46.86 254.96 11155.7 46.49 255.64 .55 .80 .20 .90 .83 85 86 87 88 89 58.0 58.0 58.0 58.0 58.0 8500.0 5025.1 5045.7 251.9 8600.0 5130.7 5190.9 251.9 8700.0 5236.4 5263.5 252.0 8800.0 5342.4 5409.2 252.0 8900.0 5448.6 5481.6 252.1 1565.38 S 4776.24 W 1593.35 S 4878.08 ' 1622.60 S 4979.66 ~ 1651.38 S 5081.76 W 1678.66 S 5184.49 W 11299.6 45.36 254.96 11439.9 43.69 254.23 11575.8 41.57 254.85 11708.0 40.13 255.26 11837.5 38.83 256.25 i . 1. 1. 1. 1. 29 48 45 08 20 90 91 92 93 94 58.0 58.0 58.0 58.0 58.0 9000.0 5552.1 5553.1 252.1 9100.0 5650.4 5692.4 252.2 9200.0 5742.3 5759.1 252.2 9300.0 5828.8 5888.1 252.2 9400.0 5910.9 5950.4 252.3 1704.37 S 5284.79 W 1730.77 S 5379.48 W 1755.26 S 5468.11 W 1777.62 S 5551.75 W 1797.67 S 5631.49 W A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location- MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0194G204S MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg feet feet feet feet deg. /100ft 11965.0 37.89 256.18 12091.5 37.72 256.98 12216.9 36.57 257.08 12342.1 37.43 259.20 12469.4 38.97 258.00 · 64 9558.0 9500.0 5989.8 6011.8 252.3 .48 9658.0 9600.0 6067.2 6072.8 252.4 1.27 9758.0 9700.0 6142.7 6192.4 252.5 1.49 9858.0 9800.0 6217.6 6252.9 252.5 1.50 9958.0 9900.0 6295.9 6315.2 252.6 12598.9 40.11 258.60 12731.9 42.07 259.98 12868.2 43.54 260.05 12900.0 43.91 261.20 1.13 10058.0 10000.0 6378.0 6378.8 252.7 2.39 10158.0 10100.0 6465.1 6510.6 252.8 2.69 10258.0 10200.0 6557.0 6578.7 252.9 2.75 10281.1 10223.1 6578.7 6578.7 252.9 Page 5 HORIZONTAL COORDINATES feet 1816.54 S 5708.20 W 1834.63 S 5783.63 TM 1851.67 S 5857.32 .! 1866.85 S 5931.01 W 1882.24 S 6008.21 W 1899.22 S 6088.82 W 1914.85 S 6175.08 W 1931.91 S 6266.00 W 1935.92 S 6287.42 W ,. Final Station Closure' Distance: 6578.71 ft Az: 252.89 deg. Quality Control Comparisons B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 Location: MPI UNIT, ENDICOTT FIELD, 5/8" ALASKA Job Number : AK0194G204 / AK0194G204 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 100'0.0 5.86 5.73 .12 2 2000.0 .28 .12 .15 3 3000.0 4.72 4.93 -.21 2 4000.0 32.59 32.65 -.05 2 5000.0 48.24 48.13 .11 2 6000.0 42.18 42.11 .06 2 7000.0 46.89 46.88 .01 2 9000.0 46.73 46.67 .06 2 10000.0 46.90 46.64 .25 2 11000.0 46.90 46.86 .04 2 12000.0 37.87 37.77 .10 2 12900.0 43.91 43.91 .00 2 INRUN Az 69.22 53.59 57.43 52.85 53.61 52.01 51.73 55.70 57.72 57.32 57.87 61.15 For Inclinations Greater than 10 degrees: Average Inclination Difference = .06473 deg. Average Azimuth Difference = 2.2663 deg. OUTRUN Az 270.86 236.87 258.09 252.34 249.42 248.28 249.06 253.56 254.47 254.98 256.24 261.20 Delta -1.64 116.71 -.65 .51 4.19 3.73 2.67 2.13 3.25 2.34 1.63 -.05 0,0 200,0 400,0 600,0 800,0 1000,0 1200,0 ]600.0 i800,0 2000,0 B.P. EXPLORATION ,~ WELL' ENDICOTT NUMBER 2-60/U-13, 7 5/8" Location' MPI UNIT, ENDICOTT FIELD, ALASKA AI401940204 Definitive , . e~i×~ ~..~07~I~' eJ ' 6400,0 5650,0 4900,0 4150,0 3400,0 ?650,0 1900,0 1150,0 400,0 F-'ASTING 6~00,0 5500,0 4800,0 4]00,0 3400,0 a700,O ~000,0 1300,0 bUU,L -100,0 B,P, EXPLORATION WELL' ENDICOTT NUMBER 2-60/U-13, 7 5~8" ,~ Location' MPI UNIT, ENDICOTT FIELD, ALASKA AK0194G204 Definitive .................................................. Bot~'o~ hole' ' L,ocated 7500,0 3500,0 4500,0 5500,0 6500,0 7500,0 8500,0 9500,0 -500,0 VERTICAL DEPTH (-F'2) 10500,0 B.P. EXPLORATION WEI_,L: ENDICOTT NUMBER 2-60/U-13, 5.0 Location' MPI UNIT, ENDICOTT FIELD, ALASKA AKO194G204 Definitive 4,5 4,0 c.~._. 3,5 © (30 3,0 QC 2,0 O0 0,5 0,0 -500,0 1000,0 $500,0 4000 ~ , , . Bo~c~com hote ' ,' ' 'MD', i~900,00 ..~ I ..... .~ '"'. ............................. 4000,0 5500,0 7000,0 8500,0 10000,0 11500,0 13000,0 MEASURES DEPTH (¢'1;) B.P. EXPLORATION WELL' ENDICOTT NUMBER 2-60/U-13, 7 5~8" Location' MPI UNIT, ENDICOTT FIELD, ALASKA AK0 194G204 Definitive 350,0 335,0 320,0 305,0 ;~90,0 275,0 260,0 245,0 230,0 aS,0 200,0 3100,0 Botton hote ............................................................ [oca~ced ~:~', 18900,00 2000 4100,0 5100,0 6100,0 7100,0 8100,0 9100,0 10100,0 11100,0 12100,0 ~F-ASURED DEPTH 13100,0 B.P. EXPLORATION WELL: ENDICOTT NUMBER 2-60/U-13, 7 5~8" 55.0 Locahion: MPI UNIT, ENDICOTT FIELD, ALASKA AKO 194G204 Definitive 43,0 31,0 CO (3 25,0 '-ES Z U-~ 19,0 Z 13,0 Z -5,0 4000 -500,0 1000,0 8500,0 4000,0 5500,0 7000,0 8500,0 10000,0 11500,0 13000,0 PIEASURETD DEPTH (~c) B.P. EXPLORATION WELL' ENDICOTT NUMBER 2-60/U-13, 7 5/8" ~00,0 Locahion' MPI UNIT, ENDICOTT FIELD, ALASKA 185,0 170,0 155,0 /~ ~4.0,0 © L_d ~ 110,0 <2 L_d 95,0 Q_ 80,0 65,0 50,0 -500,0 AK0194G204 Definitive Botz-~om hole located MD: 18900,00 laO00 .10.000 .............. 8000 .......................... 2000 1000,0 2500,0 4000,0 5500,0 7000,0 MEASURED ]3EPTH (-F'-[;) 8500,0 10000,0 11500,0 13000,0 ORIGINAL CO~'A,~ff r'¥i.IDHOE BA?f DRILLINr~ ~L NAME LOCATION 1 Ii'I: E~$ICOT~ LOCATIOIi 2 NSB~ ALASI(A MAC.~'TIC DECLINATION ~5~.~, DATE: OI-J~-~4 km~LL N~ER 0 W~L HEAD LOCATIOH: LAT(~i/-S) 0.00 AZIr~H FRO~ ROTA~RY TABLE TO TAE~ IS TiE iH POINt(TIP) : MYtASURED DEPTH 1637,00 'IS;UE 'TERT DEPTH 1-~.57 I)~LIHATION AZIMUTH 284.50 LATITUDE(H/-S) D~'ARTUEE(L~-W) -82.28 DF(W-W) Date I1 3/O/ 0,00 M~A~F,~ IN~ERVA~ ~TICAL DEPTH D~'TH f~ f~ f~ 1637,00 0,0 1~,57 1~0,35 23.3 1656,~7 17~9,29 96,9 1~76 1651,63 92,5 1~6,26 1~6t ~4,~ 1943.13 *****.,~.~,~ AN~ILk ************** S~JR~.~f C~Of~ATIOh"3 **~**~*** CIECLEAR ~C ?~RGET STATION AZI~ LATiTb~E SECTIDH INCU4. lq-S it deg deg ft 77.85 3.90 284.50 2,96 79.05 3.10 287.~ 3,~ 81,99 1,13 211.87 ~.~ ~ 63,2`? 1.42 194.ff5 1.43 83.?0 0,28 336.88 0,5i DEPARTU~ DiSF'IAC~ME~ at ~Y-W ft it -82,28 82.3~ -83,65 83,72 -86,72 ~6.79 -87,49 87,50 -87.66 87.~6 deg 272.06 272,2c,' 272.19 270.94 270.33 DLS lOOft 0,00 3,50 3.06 0,53 1,75 94~7 2037.84 95,7 21~.51 94.5 ~7.?g 95,4 2T~3.34 96.3 24!9,60 63,83 0,~' ~4,~ 1,14 83,74 0.~ 342.46 1,83 83,7~ 0,35 33'7,10 2,37 B~.B~ 0,~' 341.76 2.94 63,90 0.31 326,62 3,47 -87.9~ 87,96 270,74 0,25 -88,10 8~,,12 271.19 0,18 -~,30 66,33 271,54 0,02 -88,5I 8~.56 271.90 0,04 -~,76 8~,8~ 272.24 0,12 2517.79 2614.68 2805,74 94,6 2514.22 96,9 2611,!0 95.7 2706.60 95.4 2802,15 ~,i 2895,18 83,99 0,~ 335.66 3,87 84,09 0,38 330,~ 4,34 84.09 0.37. 3~,31 4,93 ~,66 0,~ 280.10 5.~ 87.57 2.83 261.11 5.13 -88.98 89,07 272.49 0.08 -89.23 89.33 272.79 0.14 -89,40 89,54 273,15 0.18 -90.13 90.29 273.40 -~,11 93,25 2_73.15 2,17 ~'4,75 3182,17 327?,35', 95,6 30O6.07 3177.29 Q'7 ~ ,, ,,. 32.'73.48 55.8 3367.66 93,92 4,79 255.74 3,78 !02,6~ 5.79 260,31 1,98 113.20 7,45 259.~'J 0,12 127,20 9.20 ~-7,78 -2,68 t~3.37 10,31 257,87 -6,10 -5',33 %',40 272,18 2,07 -107,94 107.96 271,05 1,14 -118,37 118,37 270,06 1.80 -132.16 132,18 268.64 1.82 -148,0i 146,14 267,64 1,16 ~53,69 3~6,61 95,6 3461,50 92,9 3551,40 96.~ 3~3,52 96,1 3733,24 ~.5 3817,34 I62,56 12,89 ~3,30 -10,96 166.07 16.~ W_Y3,13 -18,41' 215,76 19.33 ~0,70 ~D.19 ~.67 ~2,46 -39,21 288,6! 26,43 ~4,19 -50,19 -166,59 166,~5 266,24 2,87 -1P.4,90 189,80 264,43 3,91 -216,91 218.76 262,~ 2,99 -249,60 252,66 261,07 3.54 -286,41 290,77 260.~6 4.14 ~'47.48 .~42,5i 4138,64 4234.(X.~ 4~7,95 98,4 3903,~ 95,0 3984,~ 96,i 95,4 4!4!,43 94.0 4217,17 335,59 30.63 252.18 -63.83 386.05 33,53 252,89 -78,96 4~,98 34.75 250,72 -5,82 495,39 ~,34 251,42 -113.80 ~.550,94 36,20 251,02 -131.69 -331.37 337,46 ~9,10 4,38 -379.51 387,64 258,25 3,07 -430,75 441,28 257,46 1,80 -443.20 496,41 256.75 1,72 -5~,82 851,77 256,19 0,29 44~,30 4518,40 ¢W3.58 4707,06 94,3 .'~,~ ~l %,! 4368,14 95,2 4440.08 93.5 45~,46 96,7 4576.61 607,18 37,10 249,21 -1~0,86 666,B0 39,75 249,81 -171,76 728,97 42,04 248,93 -I~,72 792.56 43,95 249.85 -216,15 860.88 46.CF/ 249.76 -239.76 -588,78 EQ7,80 ,~5,63 1,49 -E~4,72 667,21 255,08 2,78 -703.03 ,~¥.~ 254.59 2,48 -762,70 792,73 254,18 2,15 -626.69 660,95 253.63 2.22 4899,64 4994,81 51~,09 5281,34 55,9 46.42,5~ 95,2 4706,62 ~,2 4770,85 94,0 4835,28 97,3 4~2.65 930,~ 47.26 250.76 -263,31 10~,88 48.13 ~0,~ -286,63 1071.07 47,(Y5 248.89 -31!,00 1139,40 46,46 246,91 -335,67 12C,?.34 45.84 248,,"75 -360.99 -892,55 9~,58 253,56 -958,97 1000,89 253,~ -1024,93 1071,07 253,12 -10~.84 1139,41 252.87 -1154,24 12~?,38 252,63 1,45 0,92 1,72 0,65 2-6 '.3 EEASLF~ I)-Ol~',g~ '~,~ICAL D~ffH D~'TE ft ft ft 5375.04 ~,7 4967.99 54~,47 ~02.4 5039.94 5573, Ii 95.6 5107.91 ~67,~ 94.7 51~,78 5766,70 1~,9 5248,~ 5861.36 5'?63 ~ 60~0,94 6139,70 6255.3& 6425,22. 6520,78 66.!5,56 6711,87 7185,67 7280,!5 7375.61 7470,25 7663,27 7757.72 7852,76 ,94; ,.~-4 8043,45 8i5_4,31 8231,61 6331,62 84,27,69 6523,06 8,6.,17.97 8713,31 8808,29 89¢4,73 8999,55 9094.84 52,7 53i6,22 102,0 539i,44 ~,6 5464,13 7~,8 ~23.~ 95.7 5593,99 94,B 5662,17 ~,0 57,30.17 95,6 5796,72 94,8 5~6o96 96.3 5~J5,85 94.1 6001,9I 92,6 ~65.75 95,2 6130,64 96,6 6196,73 95.3 6261,~ 94.5 6326.10 95,5 6390.91 94.6 6454,26 94,4 6581,94 94,5 6644.40 95,0 6707,10 94,B 6769,02 95.9 E831,04 94~.~ 6893,37 93,3 6955,60 100,2 7022,64 '~5,9 70~7,37 95,4 7152,29 94.9 7217.01 95,3 7262,16 95,0 7347,24 96,4 7413.~ 94.6 7476,57 95.3 7543.15 T~G~ ~ATIDN AZIMUTH IATII%C.E SB~II~..~.IhlCD!, N/-S ft deg deg it !P._76,~ 45,73 249,12 -~5.13 1349.05 45,02 249,02 -41!,17 1416.1! 44.41 247.58 -4~6.05 1481,85 44,00 247,94 -461,04 1~1.36 43.46 2~,46 -406,55 1614,55 42,91 247,63 -510,66 1683.16 42.~ 247,~3 -Jao.~a="' ~ 1746.03 41,61 246,64 -560,B0 17~y,82 40,?? 247.79 -580,0? 1864,10 43,72 249.90 -603,~ 1929,87 44,32 249,27 -626,26 1996.11 44~30 249,10 -649,79 2062,5i 44,03 248,65 -673,79 2128,16 43,69 250,85 -696.56 2195,39 44,~ 249,68 -719,I7 2262,25 46,02 249,71 -742,30 2~,2.2 46,85 249,07 -765,$~ 2398,49 46.BB 2~,27 -791,20 24~.91 47.11 248,91 -616,96 2536,53 47,03 249.46 -841,78 2607.48 46,94 24, 2677.43 47.~ 249.42 -690.54 ~47,63 4~,42 ~0,52 -9!4.61 282i.49 48.71 250,06 -F39.55 285~,19 46,51 249 2962,96 4~.70 -251,53 -967,56 30~.34 48,74 250,09 -1011,04 3106,03 49,69 ~1,27 -10~,77 3179,17 49.74 ~2,~ -1057,61 3250.66 46.11 ~2,47 -I079,23 3~0,17 48,20 ~1,98 -1100,45 3394,66 47,~ 253,29 -11~,66 3465,38 47,24 253,86 -1142,67 3535,27 46.99 253,26 -1162,42 36,~.64 46.56' 254,22 -1181,81 3674,23 46,76 ~3,52 -1201,12 3743,42 46,75 254,43 -1220,22 2813,41 46,36 ~5,10 -1~6,62 3662.41 47,¢~ 253,72 -1257.17 3~52,46 47.62 254,33 -1276,45 DEPARTUF~E DI~'LACEMENT at ~z-W ft ft -I~1..,9~ 1276,40 -1285,00 1~9,18 -~.~,~a 1416, -1406o~ 1~2o16 -1473,41 AZIMUTH Oeg 252,44 252.26 252,07 251,~ 25.1,71 -15~,24 1615,09 ~1,~ -1596,02 1663,66 251,41 -1656,50 1748,65 251,20 -1704,76 1800,76 251,21 -1764,88 1~.5,16 251,13 -1826.65 1931.03 251,06 -1~6,73 1~7.38 251,01 -1~50,83 2063,91 250,95 -2012.55 2129.69 250,91 -2075,92 2196,96 250,89 -2136,76 2263,~ -~01,56 2331,01 2_50, B 2 -2266 ,Z? 2400,43 250,76 -2332.05 2471,02 250,69 -2~7.26 2540,76 250.65 -2461,98 2609,84 250,62 -25~.63 2679.92 250,59 -2593,6~ 2750,22 250,58. -2663.29 2624,16 250,b'7 -2729,76 2894,97 250,55 -2796.57 2965.82 250.~ -2864.02 3037,24 250,56 -2931.74 3109.00 250.~ -3001,24 3162,14 250,59 -3069,4C, 3253,61 250,63 -3155.58 ~23,06 250.66 -3206,68 3397,53 250.70 -~74.52 3466.17 250.76 -334!,56 3537,97 250,82 -3408,17 EM07,26 250,8~ -34~,04 3676,77 250,-73 -3541,55 3745,66 250,99 -3609,11 3615,74 251,06 -3675,59 3864,64 251,i2 -3742,95 3554,61 251.17 DLS deg/ lOOft 0,~ 0.70 1,24 0,50 0,63 0,87 0,84 0,68 1,06 3.22 0.74 0,20 0,44 1,62 1,16 1.34 1,02 0.61 0,54 0,43 0.12 0,64 1,27 0.46 0.43 1,56 1,14 1.37 0,85 1.72 0.41 1,04 0.77 0.53 0,76 0,62 0.71 0,63 1,27 0,77 TH:GET STATION AZII~dTH LATITbl)E S~TiON I~ELN, N/-S ~,2~ 48,17 ~,60 -~274,81 4~4,08 48.12 ~.~ -1313,~ 4162,28 45.23 ~4,5B -133i ,M 4~5.!8 45,86 ~3.94 -I~.U 4298,06 %S,~ ~4,59 -1368,68 DEPAFFL~J~ DISPLACEMENT a't D'-W -3611.31 ~P925.25 -3877,74 4096,02 -3945.41 4164.14 -4010.7~ 4231,97 -4076,13 4~9.78 AZIMUTH deg 25i .24 251,30 251.~5 251.39 251.44 DLS lOOft 1o14 3,11 0,84 0,52 9664,70 9759.O0 9855,49 10(~6,57 10143.46 IO~B,O5 103~.!1 10428,70 10524.65 ~.1 7Wy8,96 ~5,7 94,8 8128.~ 96,3 0194,12 96,9 82~,B! 94,6 8326.49 96,1 835'3,70 94,6 8459.32 96.0 8525,53 4367.20 46,46 255_.,76 ~36.25 46.76 ~-5,13 -1403,75 45~5~16 47,20 255,~ -1421,~? 45~,87 47.63 ~.59 -1436,71 4646,18 46,29 255.72 -1456,i4 4716,3~ 46.70 255,06 -1473,~7 4764,44 45,36 25:>4,57 -149i.70 4~53,~ 45,64 ~4,61 -150~,~ 4921,11 46,~3 255,~ -152_7,29 49~,47 46,43 ~,09 -1~4,11 -4143,01 4368,82 251,50 -420~,91 4437,77 251,56 -4277,61 4507,58 251,62 -4345,21 4577,20 251,66 -44i3,40 4647,41 251,74 -MOl,Si 4717,~ 251,79 -4547,10 4785,53 251,84 -4613,Z? 4054,08 251,68 -4679,13 49~,08 -47~,51 4~1.~, 1.01 0.57 0.6I 0,46 1,40 0,65 1,46 0,50 1,07 0,22 i0~514,65 10716,53 1~11 10905.03 11001,0~ ~0.0 8587,46 103,9 8658.67 93.1 93.4 87k~.21 96,0 &5i.78 50~,~. 46.61 256.78 -1~9.43 5131.20 ~,~ 255.06 -1577..B3 ~99,~ 46,82 ~%-5,74 -1594,94 5267,15 46.9I ?~!.,96 -1612.18 5~7.20 46,~ 254.~ -1&30,58 -4809,99 50.56,47 252,04 -4~83,35 ~t~ o~ 252.09 -4?4%04 51~,69 252,14 -5015.00 5267.77 252,18 -~82.63 5337,7~ 252,21 0,59 1,22 0.53 0,61 0,28 11101.13 11197,56 I12~60 11467,72 100.1 ~920,06 96.4 8986,50 ~.0 9048,16 90,4 9112,16 91.7 9178,29 5410.~ 47,10 256,60 -1646,79 5460,17 45,82 254,78 -1666,05 5542,9B 45.~ 2~,30 -16B2,27 5606,78 44,60 254,E0 -1698.85 S570,20 43,11 k~,12 -I715,45 -5~i,28 54~0.65 252,30 -5281.~ 5543.42 252,33 -5343,64 5607,17 252,36 -5404,?? 5UO.~ 1,47 1,~ 0,78 0,~ 1,67 1i564,18 ! 11o~.1! 11752,20 1182'3.40 11918.83 96,5 ~249,61 93,9 93~,3~. 94,1 9292,49 71.2 9447,9i 95.4 9522.84 5735,19 41,55 255_,~? -173i,71 5796.84 40,71 257.67 -1745,85 ~57,13 39,20 2b-5,E4 -1759,75 5901,80 38.56 Z-,4,96 -177!,0B 59~,B1 37,94 25'7,01 -1785,~3 -5467,87 5735,54 252,43 -5528,01 5797,14 252,47 -5586,80 5857.39 252.52 -5E~0.04 5%)2.04 252,54 -5687,37 5961,03 252,57 1,71 1,54 2,10 1,07 1.49 12201 i~67.61 12379 100.3 9602,06 ~,5 9673,62 ~,0 9747,36 86,0 9816.42 91.7 9B89,C~ 60~,!3 37,66 256,44 -17~.,5i 6077,2! 37,50 -25'7,55 -1811,94 6132.27 36,~ 257,26 -1823.97 6163,37 36,69 258,27 -I634,~2 62~.12 36,~ 2_56,10 -1846,26 -5747,17 6022,31 252,61 -5800,97 6077,37 252,65 -5854,~5 6132.39 252,70 -S~04,% 61B3,47 252,74 -5959,76 6239.I9 252,79 0,45 0,77 1.31 0,97 1,60 12471.67 !25./.3.71 12652,12 92.4 9961,10 92,0 1OO32.09 88,4 10099,20 6??6,68 39,11 ZS8,06 -1858,21 6354,9B 39,96 259,31 -1869,70 6412,10 41,26 ~.60,,.~8 -1679,59 ,.2~6,~ 252.84 -6016,30 z , .~ %073.74 6~.01 252,89 -6130,44 64!2,11 ~,~J~ ~ 0.82 1,26 1,09 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: i~ ?ebruary 199~ RE: Transmitta~ of ~ata ECC #: 6132.O1 Data: PL Dear Sir/Madam, Reference: BP 2-60/U-13 ~ j~ ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAlL SBT/GR/CCL FINAL BL SBT/GR/CCL RF SEPIA PERF/PFC FINAL BL PERF/PFC {~l SEPIA~ Run # 1 Run # 1 Run # 1 ~l_%$O--Iih~ 0 Received by: Date: Please-sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson FEB '~s~a Oil & Gas Cons. Anchorage Commission ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 February 1994 RE: Transmittal of Data ECC #: 6132.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP 2-60/U-13 NORTH SLOPE, AK Enclosed, please find the data as described below: prints/Films: Sent by U.S. MAIL SSTVD/MWD FINAL BL SSTVD/MWD RF SEPIA BORE. PROF. FINAL BL Bo .PROF. RF SEPIA DLL/MLL/G~F SEPIA ZDL/CN/GR FINAL BL ZDL/CN/GR/~ RF SEPIA Run # 1 Run # 1 17_q0C,~i~kq~C~ ~ Run # 1 Run # 1 [zgOO~l~_c;%c'~ ~ Run ~ 1 Run # 1 12qOO--iLci~ lC5 Run ~ 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Received by: Date: Anchorage, AK 99518 Attn. Rodney D. Paulson ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 February 1994 RE: Transmittal of Data ECC #: 6132.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP 2-60/U-13 NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL DLL LDWG TAPE+LIST Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: MEMORANDU,., State o. Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairmarr'~ January 30, 1994 THRU: Blair Wondzell,-~'-~ FILE NO: P. I. Supervisor z/'/~'~' QKHJA4BD.DOC FROM: LOU Gri maldi,¢¢//~ SUBJECT: Petroleum Inspector Rig/BOPE inspection Doyon #15 BPX well #2-60/U-13 Endicott Field, DIU PTD #93-83 Sunday, January 30, 1994: I traveled to the main production island in the Endicott field to make a Rig/BOPE inspection on Doyon Rig #15. When I arrived the rig was just completing this well so I observed the spaceout and landing of the tubing hanger. I made a tour of the rig and found all BOP equipment to be in apparent good shape and having regular maintenance. I checked the clamp type connections that were intalled between the choke manifold and pit skid as a result of a past noncompliance, the new connections that were installed met our requirements of type but were installed in a fashion that left threaded connections on either side of the clamp. I informed Clarence Ballard (BPX Rep.) that these threads need to be welded before work begins on the next well. Summary: I made a Rig/BOPE inspection on Doyon Rig #15. One noncompliance noted, this being threads in the choke system. Attachment: QKHJA4BD.XLS ALASKA STATE OF ALASKA AND GAS CONSERVATION COM ';SION RIG / BPS INSPECTION REPORT OPERATION: Drilling Workover X Compl. UIC DATE: '1-30-94 Well Name 2-60/U-13 PTD# 93-83 Drig Contractor Doyon Drilling Rig# 15 Rep. Al Sinclair Operator: BPX Rep. Clarence Ballerd Rig Ph.# 659-6510 Location' Section 36 T. 12N R. 16E M. UM ii ii:.ii~i~iiii:.ii!ii?:iiiiii]NSPE~lON:rrEMS, .... , , ,,, , , , , ,, ,, ~: IN COMPLIANCE :. :: :: : INSPECTION ...... ITEMS IN COMPLIANCE (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill Ln.) X :.:.:.iil ii?:i iil INSPECTION ITEMS IN COMPLIANCE 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor Valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level X i!!!!!':!iiiiiiiiiii!iiiii:;i:~!iiii!?i:-iiiitNSPE~lON ITEMS ~ ~' :~::: :~ IN COMPLIANCE indicators, gauges) X ................ ' .............. ~:::::: ......... ii i i :1 i [ i ii i ii i i i (B.) CLOSING UNIT YEs NO ~'/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) X 18 Operating pressure X 43 Hydraulic choke panelI X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X INSPECTION ITEMS IN COMPLIANCE . . . 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) X 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures X 50 H2S probes X 51 Rig housekeeping X REMARKS: #11&#44 Threaded connections downstream of choke manifold need to be welded before rigging up on next well 'RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: *2-7-94 BOP Test & Results Properly Entered On Daily Record? yes Kill Sheet Current? N/A Distribution: orig - Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector AOGCC REP Louis R. Grimaldi OPERATOR REP: QKHJA4BD.XLS (Rev. 12/92) ANNULAR INJECTION DATA ENTRY SCREEN Asset .~O/L ......................................... Legal Desc 2..4.~Z'.E,.~L,..19ZS:E.~.L,..$~c..3.1,...T..1..11~I....BJ.3.E .................... Research ........................................................................................................................ C~rJ~act...C~ i~y..se~t t..tc~..&QG.C C_.3.~.1.7..~9.7. .................... Rig Name ..................................................... Inj Well Name .Er..0~) ......................................... Permit Start ....... ;1./..1./.~9.3. ...... Permit End.....l.2~.3..1.J..9.3.... Sur Csg Dep ........................... · ............................................................. Cumulative Data Daily Data P-08 1,110 40 950 2~100 Opon 1993 Year End Summar~ P-08 586 375 961 Au.gust 15 throu, flh___~.Au_gus__t 30, 1993 -- -- __. I ALASKA OIL AND GAS CONSERVATION COMMISSION June 11, 1993 'WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Bill Kirton Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 2-60/U-13 BP Exploration (Alaska), Inc. Permit No: 93-83 Sur. Loc. 3176'NSL,2344'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 1201'NSL, 3682'WEL, Sec. 35, T12N, R16E, UM Dear Mr. Kirton: 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 on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commi s s ioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA L,,IL AND GAS CONSERVATION CO'iv~MISSION PERMIT TO DRILL 2O AAC 25.005 i'a. Type of work Drill [] Redrill FlJl b. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation ~DL-. P. O. Box 196612~ Anchorage,Alaska 99519-6612 Duck Island Unit/Endicott,_~ ~ ,, 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~e 20 AAC 2s.o25) 3176' NSI_, 2344" WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval i,2~V' 8. Well number Number ~"1317' NSL, 3298' WEL, SEC. 35, T~¢I, R16E 2-60/U-13 2S100302630-277 At total depth /.~M 9'. Approximate spud date Amount .~ 1201' NSL, 3682' WEL, SEC. 35, TI4W, R16E 6/20/93 $200,000.00 12. Distance to nearest i13. Distance to nearest well 14. Number of acres in property 15. Proposed'depth (MD and'rVO) property line 1201' feet 2-58/S-09-16'@ 819'MD feet 2560 13282'MD/10486' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~, 2o AAC 25.035 (e)(2)) Kickott depth 2800 feet Maximum hole angle '~.~ Maximum surface 3900 pslg At total depth (TVD) 1000074890 psl~l 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 110' Surface 110' 110' Drive 13-1/2" 10-3/4" 45.5# NTSO B TC 2667' 37' 37' 2704' 2667' 4~o sx"E"/35O sx "G"/25o sx "C" 9-7/8" 7-5/8" 29.7# NT95 NSCC 13246' 36' 36' 13282' 10486' 900 sx 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 Surface ~'~: .... '" ...... ' Intermediate Production ., "/ '- '; "~'" Liner Perforation depth' measured ...?~L~.'~;i-.. ';ii !:,: (',:::; " true vertical 20. Attachments' Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce,~ify that th~foregoing is true and correct to the best of my knowledge .. Sk,)ned /~,,~~~ ' ~,,~ Title Drilling EnginoorSuporvisor Date'5"~/'/~,./~'--? · ~'Commission Use Only Permit Number IAPI number IApprovai date ISee cover letter ~'~-~-~ 150'°~- :>"-';~-~> "~"~ . I ~,~ _.~// ,---'/~"~:~ Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes '~q No Hydrogen sulfide measures [] Yes ~ No Directional survey required ]~ Yes [] No Other:Required working pressure for BOPEoR!G~NAL[]SiGNED2M; By, M;_ ~5M'. []1 OM; []1 5M', by order of Approved by ~iJSSELL A. DOUGLASS Commissioner me commission Date~.~ -//~,2' _ Form 10-401 Rev. 12-1-85 Submit in triplicate MPI Z-60/U-13 WELL PLAN SUMMARY SURFACE LOCATION: 3176 FSL 2344' FEL SEC 36 T12N R16E UM TARGET LOCATION: 1317' FSL 3298' FEL SEC 35 T12N R16E UM BOTTOM HOLE LOCATION: 1201' FSL 3682' FEL SEC 35 T11N R16E UM TOTAL DEPTH: 13282 MD/10486 TVD ESTIMATED SPUD DATE: 6/20/93 CONTRACTOR: ELEVATIONS: PAD: 1 O' Pad TO RKB: 46' RKB: 56' DOYON Rig 1 5 DIRECTIONAL INFORMATION: KOP: 2800 BUILD RATE: 2°/100' EOB: 4875'TVD/51Z6' MD AVG ANGLE: 46,53° DIRECTION: DEPARTURE at TD: 253.06° 69O5 FORMATIONS MD TVD BKB SS De.oth Permafrost 1471 1466 1410 SURFACE CSG PT 2704 2700 2644 TOP TUFFS 10637 8666 8610 TOP HRZ 11 335 9146 9090 TOP ITKILYARIAK 11705 9401 9345 TARGET (KEKIKTUK ZONE 3C) 12370 10106 10050 EST TOP OF TAR 12890 10216 10160 EST OWC 12941 10251 10195 TOP ZONE 3B 13040 10319 10263 TOP ZONE 3A 13261 10471 10415 TD 13282 10486 10430 CASING PROGRAM 1. 7-5/8" casing will be run to TD based on Sperry LWD logs. 2. Intermediate casing could be run prior to reaching TD based on hole conditions. Bit Size ~ Weight Grade Connection ToD Driven 30" Struct. WELD 13-1/2" 10 3/4" 45.5# NT-80 BTC 37 9-7/8" 7 5/8" 29.7# NT-95 NSCC 36 Bottom ~eset 2704 13282 Preset 2667 13246 MWD/OPEN HOLE LOGGING PROGRAM 1. 13-1/2" hole: MWD Directional 2. 9-7/8" hole: MWD Directional Sperry IvlWD EWR4/Neutron/DEN/GR from +/- 11 500' MD to TD. CASED HOLE LOGGING PROGRAM 1. SBT from TD to TOC in 7 5/8" casing. 2. GCT: PBTD to surface (After rig leaves) COMPLETION PROGRAM 1. 3-1/Z" coiled tubing completion to be run after rig is released. 2. Six Gas Uft Mandrels. (Gaslift design will be determined after OH logs), SPUD MUD PROPERTIES Weiaht Marsh Vis Yield Pt. 10 sec ael 10 min gel p_~ APl F.L. Hardness Spud 8.7 300 40-60 30-60 60-80 9-10 15-25 <200 Csg Pt. 9.5 100 20-40 15-20 20-30 9-10 1 5-25 <200 pRODUCTION HOLE MUD PROPERTIES Depth Weiaht YP 10 sec Gel 10 min Gel APl F.L. D.~ Hardness to TUFFS 9.5 - 9.8 15 - 25 12 - 15 25 - 30 <12 9.5 - 10.0 < 200 to TD 9.8 - 10.5 20 - 30 12 - 15 25 - 30 6.0 - 8.0 9.5 - 10.0 < 200 At the top of the Tuffs, the fluid loss should be controled by the addition of Drispac SL, Resinex, and/or lignite. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. PRODUCTION HOLE MUD PROPERTIES Depth Weight YP 10 sec Gel 10 min Gel APl F,L. ~ Hardness to TD 9.2-9.4 1 5 - Z5 12 - 15 25 - 30 <8 9.5 - 10.0 < 200 The intermediate hole mud should be watered back to build the production hole mud. The fluid loss should be controlled with Drispac. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. MPI 2-60/U-13 CEMENT PROGRAM HALLIBURTON 10 $/4" SURFACE CASING CASING ~;IZE: 10 3/4" 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 450 THICKENING TIME: 5+ hrs MIX WATER: 11.63 gps TAIL CEMENT TYPE; Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD:1.16 ft3/sx APPROX #SACKS: 350 THICKENING TIME: 4 hrs MIX WATER: 5.00 gps TOP JOB CEMENT TYPE: Type 'C' Permafrost ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps APPROX #SACKS: 250 SPACER: 50 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 35-40F. CEMENT VOLUME 1. Lead slurry + 350 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 250 sx. 7 5/8" PRODUCTION CASING CASING SIZE: 7 5/8", 29.7# CIRC. TEMP 130°F LEAD CEMENT TYPE: Premium ADDITIVES: 0.5% CFR-3 (Dispersant) + 3% Econolite (Extender) + 0.4% Halad-344 (Fluid Loss) WEIGHT: 11.0 ppg YIELD:3.24 ft3/sx MIX WATER: 20.4 gps APPROX #SACKS: 600 PUMP TIME: 5+hrs TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.5% Halad-344 (Fluid Loss) + 0.25% HR-5 (Retarder) Retarder (HR-5) concentration to be based on actual lab tests. WEIGHT: 15.8 ppg YIELD: 1.1 5 ft3/sx MIX WATER: 5.00 gps APPROX. # of SACKS: 300 THICKENING TIME: 3-1/2 hrs +1 hr @surface OTHER CONSIDERATIONS;; Batch mix the Tail slurry only. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 10-12 bpm. SPACERS: Pump 20 bbls ARCO Preflush; 50 bbls ARCO spacer @ 11 ppg. CEMENT VOLUME 1. Lead Slurry based 90% of hole volume from top of tail slurry to surface casing shoe. 2. Tail Slurry to 1000' above shoe w/50% excess. PROPOSED DRILLING AND COMPLETION PROGRAM ENDICOTT MPI 2-60/U-13 PROCEDURE 1) MIRU Doyon 15 Drilling Rig. N/U diverter and function test same. 2) Drill 13-1/2" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and test to 250 psi (low test) and 5000 psi (high test). 3) P/U 9-7/8" BHA and RIH. Test casing to 2500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4) Drill 9-7/8" hole to TD. Log the reservoir while drilling (MWD tools). 5) MU and run 7-5/8" casing and cement as per well plan. 6) NU dry hole tree and test to 5000 psi. Release drilling rig. 7) The present plan is to run 3-1/2" coiled tubing as a completion string. Anticipated BHP: Maximum Anticipated Surface Pressure: Planned Completion Fluid: 4200 psi @ 10050' TVD SS 4000 psi @ 10263' TVD SS 4950 psi @ 10415' TVD SS 3908 psi 8.6 ppg Filtered Sea water Notes: a. The drilling program and surface system will conform to the regulations set forth in 20ACC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. Based on Endicott previous logs, no potential productive zones are anticipated above the Kekiktuk formation. d. No potential hazardous levels of H2S are anticipated in this well. 2-60/U-13 (MPI) Casing Design Specifications SURFACE CASING 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 3130 PBYS (#) 1040000 TJYS (#) 1097000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 14 2700 1966 Burst S.F. 2.65 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2700 1334 Collapse S.F, 2.35 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3571 PBYS Tension S.F. 7.49 Mud Wt. 9.5 ppg TJYS 7.90 String Wt. (#) 138888 2-60/U-13 (MPI) Casing Design Specifications Production Casing 7~5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 80 7150 PBYS (#) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. sn'P 3900 Burst S.F. 2.10 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 10000 0.1 4304 Collapse S.F. 1.66 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 13282 PBYS Tension S.F. 2.44 Mud Wt. 10.2 TJYS 2.53 String Wt. (#) 332977 <KB> 10800 PRUOHOE BAY, DRILLING I ....... ~ i ..... ill / , -, ............. ,, ,, , ,~ , · VERTICAL SECTION VIE~ 1 ~'L : ', -I' I'-?--~'-' : ' --~, 1 ~ . , ] ...... ~ i t t I I I ~-i I.-, .... %.~r, ,, ............. O-i................ % ' ' .... !,, ~ ~,, ~-T-,-,","- .... ~ , Section aL' 253 06 I , ; J ~ ' ~ , ' ' , / ' ' ., , ~ ~ ,, ., .i , ,, .~-=~ , , ......... , ..... TVD Sc81~ ' 1 ~nch ~ 1200 fort ~ ' / ' ' ~ ' : ' ' ' ' ' ' - ~ ..... Oep Scale ' ~ ~nch = 1200 feet I ~ ~/ , ' ' ' I I ~ I ' ~ ~ ~ ' ' ' ' I i I I ' - --. ~; ~ ~ ,- ~, : ~ ..~ ~, Drawn ' 03/22/93 ']'-='F%'='I .... ] ·I ='/ .........I I"-=-'~-': ~' ' ~ ~' _ .. . ...... , : , ..., ......... ~ , ., ,,,~ . , . ,11,, ',"1'~. , ~ I" ...... i ..... . . i . ............ . , ............... . ~:.,~,..?., ..... ~"I ...... I- - ~F'i'-' I ~ ........ r'T'q-'r-- , } : ' MD BKB SECTN iNCLN L T _ : ,_. , , ~ ,_,.j ...... , , , · MarKer Ident~T~cet]on ~ '{ ,'-~' -" : -~7'~ ......... - *" '-'~--: ' ~ ~ : ~ ~ ' ' ", ~' $ :l A) KB 0 0 0 0.00 ..I ~-~ -.ri, III., f,tl - i i ~ ! ~ I - ~ i ~ i; B~ NUDGE KOP BLO 9/~00 600 600 0 0.00 "F~ -m --F .... I / ', ! ! ...... F'"%~ I i : i t / I [ ~ C) END NUDGE BUZLO gO0 899 ~5 6 O0 ' i ~ ; i .... r ..... F'. t · I .... ~'- ' , /~ . I I t ..... k' ' ' ) i ! ' ' : ~ : I ! t I ~ ~ i i-~"-I'"%"-~ ;' i' : ' B) NUDGE DROP ~,/~00 ~400 t397 63 6.00 ~:. ~ ~', ~' !' ~ '7-7-'FI'"1 "' ~ , ;~' '-T' E) ENO NUOGE BROP 2000 ~gg6 ~2 0.00 ' ' I ~ "' '~" I I . I - ~ : ~ ! I ~ :%, , ;' ~ : 'i ;" Fi 6ASTN6 POINt 2704 2700 aP 0.00 . 1' ~--. ~ , , i~l I , I I , - , I : : ._~_.;..= ..... I ' ~..i~ ! ; !~! ~..j I I i ~ t :' ! I I I i! ' .-,, ~I : 6J KOP 8U~LO 2/~00 2800 2796 92 0.00 )- ~ ' ' : · - I · : ( i : Hi ENB ~/tO0 BUILD 5126 d875 986 ~6.53 / : 1: ~, '~I '~ .... [..L.[_J' Il ,~' ¢ " ..... +""-~--m-~+'' I ....... ' ~ CASING POINT ~]720 9ara' 577~ 46.53 ~ _l~l , ~ i . · , - i I ~ . .............. ~ ~ I . I . · , , , . , : ' ', t d) ~ARGET ~2730 ~0~06 6504 46.53 :'""f"T'T-'~'-F-'-N /'1 !' I !'i"T-t"T, , i~ ~ ~. .,.,,...~ .... iI ~ . II '~ ........I 1 I '----:i % ' ' ' ' I ,' , , ; ~ ,' ' I, t .....3 ! I ~ I~ ..... .... , i, ,,:= ..... : ~'%, t , .... ...... ,, ~ ,,, ,-= ...... :. ,.,,.~.., .... ~ , . ) ..... i ' ' "r4--%" ! ' ' . ' ~ ~ ' . . '' "-!" - ' i ' : ..... , ' '. ~ ' , ' , I ~ , · t - , , , I , . , , I , I_~ .... t . ~ .~.. , , , .r' '~~-d-. . , ' I ' ' I ' ~F" ' ; ' '~ , · - - ........ ~-' . ~. I, I ,., I., I ~:.]. t I =..]_ I I , ~ I, .. ........ ,._ I , I I ..!.. ~ ~ '' ~ ' ~ i . ~ . ; ~ --- , .... - , , ' "I'~' ' i ~ ':' , , : ........ f .... T- ~ ' ' .... I ....... I .... I ..... I i ' - I : I ..... ' ' ;~ ..... I ~ ' ' ' ' ' ' . I I._.~ · , , , ~ , .Z. . , _: ............ %_ , ¢ i _...: , . . ! ' ~ ' ~ I ~ ~ I .~'-. , . ~ ~ , ,,. ,' ~F-t',/-'- , ,.. ...... . , .. . ,¢.., .... ~.I.4 . , . , I , ~ J , , I . , . . , ~ {, ......... --..~-~-~. ,.. =.-I-~ .... ~, --. ~ . -.~ . . ; . . .._ ... .:,:-~ _,~-,~.. ; ~.~ F.¢ .,~ , ~ I : I , : : I , ~ , ~-,~ -~. , ..~ ., .;~% .., ~, ...... -- , ~ , : ~ i :,,.-¢¢z~,,-="M-~J, "'1' ~s~-~m~N~- ~ -~-~ ..... ~-~'~?'~-]m~-,'fi~'~"~ .......~I ~T~'~"~-~ ;'~ ~:]]]i ~ ~ ~ ~>', "f:.~.~ -¢~% ~'.. F ..... ~..~.-=-_-~--_~_~.._~ .~_ .~-: .... ~ ............... ... ~-.~_. ..... ,__~.~ · . .. ,,, , · ,!:,, .. .,I ... ~ .... , ,ti ..... ~-1-' -.~- ~.-'-' '.-=-~-~ -- '"~.. ,- , ....... , -, .., ....... ... ... ..... ,. ~_~ -z. ' , . . I . , , ,_ , : ~ i ; I ' i ' ~ I I ~ . ~ : , ' . , · ' '~ ~:-~= .i---.Z ,-~_'I'_I~_Z-- i i.'' ' · ' -' Z I.' I ' ' ' I - I ' i '_.~. ¢.',, "' " .~'~ ,._.. I ..... " ~ --, i_' ' ~ , , ~ , . , . , , , , , I ; ~ i ; ~ ; , . , I ; . ' I ~, ~- .. ~ ~].~,.,,, .~.., ~ ,_., ... .... T~,~-., ,,, ....... ~ . ' , ' " Szo~I~mN'~/" ..-,T~-~.-~.~ -,.%7r~.r--,-~+-mT--,.-~m-,-~.~.,.;j_ ~ .... ~' ! ' ~q ._/' ,,' ', ~ ~~ ~'¢'' : I I! I~: ! [ : I I'"' ' I~- "~ . ..~. ...~ ._.~ ...: ___, _. ' ,' ~ , ..... ,. . .j ¢5kOO (c]92 2ASOU:3P 8~.43 5. 54 PN 2] 0 BOO ~.200 1800 2ziO0 3000 ~600 a200 4800 5400 6000 6800 7200 7800 Section Departure .._ .. ..... PRUDHOE 8~ NUDGE ~OP ~I_D 2/!00 600 C) EWO N'UO6E BLHLO ~0 D) k~OBE D~P ~/]00 ~00 E) END NUDGE ~OP 2000 FI CASING Po[Nr 27O4' · G] KOP BI)JLD 2/JO0 2800 10 EI,~ ~/100 GUILD 5126 I) C,~SI~G PDINT I i'l~O ~:1 TO i3~8~ BAY N/S ON 0 E ON OE l N t6 k' B 'N 68 h' 9 N' 99 N 9 N 99 ~ 252 S 95~ N ]6~5 S 5531 N ]859 S 6233 h' ]926 S 66i6 W DRTLLING 6reat Land t?JrectJona_] Drilling PLAN VIEW CLOSURE · 6905 feet at Azimuth 253.37 DECLINATION- 30.43 E SCALE ' 1 inch = 1000 feet DRA~{N ' 03/22/93 IGLL19 lEI .°.2." 2EOI.H31" BI 43 5. 56 I~ 2J 7000 6500 6000 5500 5000 4500 ~o00 3500 3000 2500 2000 1500 JO00 500 0 500 <- ~'£ST' EAST -> Great Land Directional Drilling, Inc. Collision Avoidance Analysis Client.: Field..: Pad .... : Well...: PRUDHOE BAY DRILLING NSLOPE Main Production Island 260U!3P Me.hoe..: Date .... : WellHd X: We!lHd Y: Normal Plane 03/22/g3 258857.96 5982317.76 Comment: 2-60/U-13 600 ~DGE KOP P1 Wells with minimum separation greater than 200 ft not reported. All depths are relative to the planned well. Existing Well .... i00' ..... ----25' ..... Band Occurs at Warning-Band Serious-Band Closest Depths Enter Leave Enter Leave Point BKD MD MD MD MD MD 15!V20P 250U08P 266SD12P !37P24G 139Pi7G !41023G !43P26G 145Q26G 147Q2!G !49P2!G 155R25G !57R23G !63T22G 167T20G 169V19G 226N14G 228PlgG 230009G 232SN3G 234P!4G 2360!4G 238SN!G 244R12G 246Q15G 252S14G 254Q12G 258S09G 262Q17G 264U!0G 268S17G 270U!SG 175 0 0 49 669 669 30 0 0 187 707 707 197 ! 1 192 0 0 188 1 1 184 550 550 180 1 1 175 726 726 171 1 1 151 777 777 17! 25 25 175 i 1 177 0 0 200 1 1 190 1 ! 180 0 0 170 0 0 158 631 631 120 ! 1 !10 1 ! 80 614 614 68 675 675 40 21 21 30 605 605 8 624 624 9 164 164 16 819 819 36 912 9!3 aa 941 941 0 1945 0 17~1 1 1139 ! 3367 21 1441 0 3451 1 4051 1 3011 1 3771 1 2587 0 2437 979 1032 1014 SUt-,., r" -'HOLE-DIVERTE:,~ SYSTEM ...... Two lines venting 90 deg'. apart in directions that ensure sale down wind venting, and ex- tending to a point at least 100' Irom any' source of lgnilion.- -- .~_10' Full Opening Valves :../ 35' or as required Dresser Sleeve 10' Diver[er Une 1. Ail pipe connections 150¢ ANSI Ranges or welded connections and secured to prevent movemenL 2_ Manual 10" full opening valves m~hanically c~nnec't, ed to ensure that one valve is fail-safe open at all times. 3. All tums are go deg. and targeted. 10' Ful[ opening ball valve w/Hydraulic Actuator Cellar 2~3' Diverter Spool w/10r Side Outlet MEM 1/'3~0 DOYON RIG #15 MUD PIT SCHEMATIC CUTTINGS CONVEYOR .,, DEGASSER MIX PIT TANK DESANDER PIT MUD CLEANER TANK SUCTION TANK PILL 235 BBLS 115 BBLS 210 BBLS 155 BBLS 235 BBLS PIT ,. 101 BBLS HOLE FILL TANK 90 BBLS ............ EQUIPMENT UTILIZED: 2 SETS OF BRANDT TOTAL FLOW SHALE SHAKERS 1 - DEMCO 3 ~ 12" CONE DESANDER 1- TRIFLOW 16 - 4" CONE MUD CLEANER 1- DRILCO DEGASSER 1- PIONEER MARK II CENTRIFUGE 1- DRECO POOR BOY DEGASSER 2- PIONEER S-800 SIDEWINER MUD HOPPERS DOYON RIG #15 MUD PIT SCHEMATIC CUTTINGS CONVEYOR DEGASSER MIX PIT TANK DESANDER PIT MUD CLEANER TANK SUCTION TANK PILL 235 BBLS 115 BBLS 210 BBLS 155 BBLS 235 BBLS PIT 101 BBLS HOLE FILL TANK 90 BBLS EQUIPMENT UTILIZED: 2 SETS OF BRANDT TOTAL FLOW SHALE SHAKERS 1 - DEMCO 3 - 12" CONE DESANDER ' 1- TRIFLOW 16 - 4" CONE MUD CLEANER 1- DRILCO DEGASSER 1- PIONEER MARK II CENTRIFUGE 1- DRECO POOR BOY DEGASSER 2- PIONEER S-800 SIDEWINER MUD HOPPERS DOYON 15 13 5/8" 5,000 psi Stack 9.00 4.65 3.00 2.00 2.00 1.85 RKB '~ I KB TO RF R i FL& I I HYDRIL I ! 5" PIPE RAM 11.32 14.32 BLIND RAM I 4" Choke j MUD CROSS 4 1/2" x 7" VARIABLE PIPE RAM )R lei' 20.17 39.05 13.95 4 FEET ABOVE GROUND LEVEL 2-60U_13.XLS State: Well: Field: State Permit I:l: 2-60/U- 1 Endicott 93-.88 Engineer:. Work Sheet: Date: Cer~enl Vo/z,,me £alculalione 6/31,.93 Ceding Type Ca~'~g Size -Inches Casing Length - Feet Hole Di~cr, eter -Inches Cement-Sacks 111 Cement- Yield Cement- Cubic l't Cement- Cubic ft Cement-Sacks Cement- Yield Cement- Cubic ft ~I2 Cement- Cubic It I~2 Cement- Sacks 113 Cement-Yield 113 Cement- Cubic t~t Cement- Cubic ft Cement- Cubic ft / Vol Cement- Fill Factor Concbcto~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ItDIV/O! Suflace 10.750 2,667.000 13.500 450.000 2.170 976.500 976.500 350.000 1.160 406.000 4OEO00 0.000 0.000 0.000 0.000 ,382.500 1.425 Liner 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ItDIV/O! Ca¢~ng Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks Cement- Yield Cement- Cubic tt Cement- Cubic ft Cement-Sacks ~2 Cement- Yield 112 Cement- Cubic ft a2 Cement- Cubic ft t:I2 Cement-Sacks :1:I3 Cement-Yield Cement- CUbic it 113 Cement- Cubic ft Cement- Cubic tt / Vol Cement-Interval ft Top of Cement- Feet Intermediate ti1 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/0! tI:DIV/0! Intermediate 112 0.000 0.000 0.000 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 tIDIV/O! ItDIV/O! Production 7.625 13,282.000 9.875 600.00 3.24 1,944.00 1,944.00 300.00 1.15 345.00 345.00 0.00 0.00 0.00 0.00 2,289.00 10,658.75 2,623.3 Measured Depth State: Alaska Borough: We~l: 2-60/U-1 Field: Endioott St. Perm # 98-83 2-60U-13.XL$ Date 9/9/93 Engr: M. Minder Casing Interval Interval Size Boffom Top lA 10.75 2667 37 2.A 7.625 10486 86 3A 0 0 0 4A 0 0 0 6A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Length 2667 13246 0 0 0 0 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 45.5 IT-80LHE BTC 0 29.7 NT-95HS NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 219 ,38 4B 5B 6B 7B 8B 919 108 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ft 9.5 0.494 0.394 10.5 0.546 0.446 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3900 5210 1.3 3900 818O 2.1 0 0 #DIV/'0! 0 0 #DIV/0! 0 0 #DIV/'0! 0 0 #DIVi0! 0 0 #DIV/0! 0 0 #DIV,/0! 0 0 #DIM/O! 0 0 #OiV/OI. Tension Strength K/Lbs 1C 121.9485 2C 393.4062 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 1040 8.57 811 0 #DIV/0! 0 #DIV/O.I 0 #DIV/O.i 0 #DN/O.i 0 #DIV/0.1 0 #DIV/'0! 0 #DIV/0! 0 #DIV/O.! Collapse Collapse Pr-Bot-Psi 1051 4677 0 0 0 0 0 0 0 0 Resist CDF 3130 2.979 7200 1.540 0 #DIV/0! 0 #DIV,'O! 0 #DIViOI. 0 #DIViO! 0 #DrY, O! 0 #DIViO! 0 #DiViO! 0 #DIV~tOI. CHECK LIST FOR NEW WELL PERMITS ::* ITEM APPROVE DATE (2) L0q /~¢~, , , ~.~¢//¢,~ [2 thru 8] . 2. 3. 4. 5. 6. 7. (3) Admin [~b'~¢, ~ 9. [9 t-hru 13] 10. [10 & 13] 12. (4) Casg ~,- .~2- ~ ~ 14 [14 thru 22] 15. [23 thru 28] (6) Other '[29 thru 31] (7) Contact [32] (8) Addl ~,. ?;,Z- ~ geD 1 ogy' DWJ RP~ engineerinq' MTM,,/Z-~ RAD~ G- ~i BEW__ JD~L.-',~ ~./~ rev 12/92 jo/6.011 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. NO REMARKS Company '/~ P - 7 YES Is permit fee attached ............................................... ./~. Is well to be located in a defined pool ............................ ;. ~ Is well located proper distance from property line ................... ~( Is well located 'proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is ]ease nLmber appropriate .......................................... Does well have a unique name & mmber ................................ Is conductor st r lng provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter g BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntmber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA .~ SHORE MERIDIAN' remarks' UM X, SM TYPE' -xP,.,~..=~, ~ Red ri ] 1 Inj Rev 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. 2- 60/U- 13 ENDICOTT 12300 Run 1' 25 - January - 1994 DLL/MLI./ZDL/CNIGR Pipe Conveyed 2988 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6132.00 R. ECK C. ZARNDT REMARKS: 2-60/U-13 MPI 500292237500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 03-FEB-94 OPEN HOLE RUN 2 RUN 3 36 12N 16E 3176 2344 56.00 10.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 2720.0 9.875 13010.0 DLL/MLL/ZDL/CN/GR. CIRCULATION STOPPED AT 02: 00, 24-JAN-94. LOG WAS DRILL PIPE CONVEYED. CALIPER FROM ZDL TOOL (C13), PE, & ZCOR, ALL INDICATE THE ZDL TOOL WAS NOT MAKING SUFFICIENT PAD CONTACT WITH THE FORMATION TO PRODUCE QUANTITATIVE DATA. THE ZDL ORIENTATION WAS AFFECTED BY THE MLL TOOL RUN BELOW THE ZDL TOOL. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED (Z Density), CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. AS PER CLIENTS REQUEST, ENVIRONMENTAL & TORNADO CHART CORRECTIONS WERE APPLIED TO DLL/MLL DATA. THE MLL WAS CORRECTED FOR THE EFFECTS OF MUD CAKE & AN "RXO" CURVE WAS OUTPUT. THE DLL DATA WAS CORRECTED FOR BOREHOLE SIZE. THE CORRECTED DLL DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET AN "RT" CURVE & "DI" CURVE (Depth of Invasion). FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 12300.0 12911.0 12351.0 12988.0 12324.0 12935.0 12380.0 12913.0 GR (MEASURED DEPTH) BASELINE DEPTH MLL 12276.0 12276.0 12339.0 12345.0 12354.5 12359.5 12369.0 12377.0 12380.0 12382.5 12390.5 12393.5 12394.0 12394.5 12400.5 12401.0 12407.0 12407.5 12409.0 12421.0 12422.0 12422.5 12425.5 12426.0 12436.0 12442.5 12443.0 12443.5 12447.5 12448.5 12458.0 12458.5 12470.5 12471.0 12477.0 12477.5 12481.5 12482.0 12482.5 12486.0 12490.5 12394.0 12400.0 12407.0 12408.5 12422.0 12426.0 12442.5 12447.0 12471.0 all runs merged; no -- EQUIVALENT UNSHIFTED DEPTH LL3 RHOB NPHI 12276.0 12276.0 12276.0 12339.5 12346.0 12355.0 12359.5 12369.0 12376.5 12383.0 12389.0 12380.5 12394.0 12394.5 12393.5 12400.5 12400.0 12407.0 12407.5 12420.5 12422.5 12422.0 12425.0 12426.0 12435.5 12443.0 12442.5 12444.0 12448.5 12448.0 12456.5 12458.5 12471.0 12471.5 12471.0 12477.5 12482.5 12477.0 12482.5 12490.5 12491.5 12481.0 12486.0 12492. 12493. 12501. 12504. 12507. 12507. 12514. 12515. 12515. 12523. 12525. 12529. 12531. 12536. 12536. 12537. 12540. 12553. 12556. 12566. 12567. 12568. 12569. 12572. 12573. 12574. 12577. 12578. 12597. 12599. 12606. 12607. 12608. 12610. 12618. 12619. 12621. 12628. 12638. 12639. 12652. 12654. 12659. 12664. 12665. 12669. 12672. 12677. 12681. 12686. 12687. 12687. 12701. 12704. 12708. 12709. 12719. 12720. 12721. 12722. 12492.5 12505.0 12507.5 12515.0 12525.0 12536.5 12540.5 12555.5 12565.5 12568.5 12573.5 12577.5 12606.0 12610.0 12629.0 12660.0 12664.5 12669.5 12686.5 12492.5 12507.0 12514.5 12529.0 12537.0 12567.0 12572.5 12606.5 12609.0 12637.0 12670.0 12686.5 12708.5 12718.5 12721.5 12493.5 12514.5 12537.0 12553.5 12566.0 12569.5 12571.5 12574.0 12596.5 12608.0 12618.0 12621.0 12652.5 12654.5 12659.0 12676.5 12680.0 12685.5 12687.5 12701.5 12493.5 12501.0 12508.0 12515.5 12523.0 12531.0 12553.5 12566.5 12569.0 12578.0 12599.5 12609.5 12620.0 12639.0 12651.0 12664.5 12670.5 12678.0 12687.5 12704.5 12708.5 12719.5 12722.0 12723. 12724. 12726. 12732. 12733. 12736. 12739. 12739. 12744. 12744. 12749. 12749. 12756. 12759. 12764. 12772. 12773. 12773. 12778. 12782. 12783. 12786. 12787. 12787. 12792. 12800. 12800. 12801. 12804. 12807. 12811. 12811. 12813. 12817. 12818. 12821. 12822. 12823. 12824. 12827. 12827. 12830. 12831. 12834. 12837. 12840. 12842. 12842. 12844. 12845. 12848. 12849. 12859. 12860. 12864. 12872. 12877. 12879. 12883. 12884. 12732.5 12740.0 12745.0 12749.5 12772.5 12783.0 12787.0 12810.5 12821.5 12828.5 12831.5 12837.0 12840.0 12845.0 12846.5 12849.0 12859.5 12863.5 12872.0 12883.5 12723.0 12732.0 12744.0 12772.0 12786.0 12791.0 12801.0 12804.5 12807.0 12812.5 12817.5 12821.5 12824.0 12830.5 12842.0 12860.5 12864.0 12879.5 12724.5 12745.0 12748.5 12756.5 12758.5 12773.5 12782.5 12786.0 12787.0 12801.0 12810.5 12817.5 12821.5 12824.0 12827.0 12831.0 12849.5 12863.5 12873.0 12878.0 12885.0 12724.5 12736.0 12739.0 12744.0 12749.0 12757.5 12762.0 12767.0 12779.0 12782.0 12786.5 12801.0 12812.0 12821.5 12835.0 12842.5 12877.5 12880.0 12886.5 12891.0 12891.5 12891.5 12892.0 12893.0 12893.5 12897.5 12898.0 12899.0 12908.0 12908.0 12911.5 12912.0 12922.5 12923.0 12925.5 12926.5 12945.0 12945.0 12951.5 12951.0 12958.5 12958.0 12996.0 12996.0 12996.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 2 DLL 1 2 SDN 1 2 2435 1 2 $ REMARKS: 12887.0 12894.0 12908.5 12996.0 12886.5 12892.0 12894.0 12898.5 12996.0 MERGE TOP MERGE BASE 12300.0 12911.0 12351.0 12988.0 12324.0 12935.0 12380.0 12913.0 MAIN PASS. RXO, CALl (from MLL), SP, MTEM, TEND, & TENS WERE SHIFTED WITH MLL. LLD, RT, & DI WERE SHIFTED WITH LL3. DRHO, PEF, & CALl (from Z Density) WERE SHIFTED RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. RXO = RESISTIVITY OF FLUSHED ZONE RT = TRUE FORMATION RESISTIVITY DI = DEPTH OF INVASION. / ? ?MATCH1. OUT /??MATCH2.OUT /??MATCH3 .OUT /??MATCH4.OUT $ CN : BP EXPLORATION WN : 2-60/U-13 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 2 LL3 DLL 68 1 3 LLD DLL 68 1 4 SP DLL 68 1 5 MTEM DLL 68 1 6 TEND DLL 68 1 7 TENS DLL 68 1 8 DI DLL 68 1 9 RT DLL 68 1 10 RXO DLL 68 1 11 MLL DLL 68 1 12 CALl DLL 68 1 13 RHOB SDN 68 1 14 DRHO SDN 68 1 15 PEF SDN 68 1 16 CALl SDN 68 1 17 NPHI 2435 68 1 18 FUCT 2435 68 1 19 NUCT 2435 68 1 * DATA RECORD (TYPE~ 0) Total Data Records: 121 GAPI 4 OHMM 4 OHMM 4 MV 4 DEGF 4 LB 4 LB 4 IN 4 OHMM 4 OHMM 4 OHMM 4 IN 4 G/C3 4 G/C3 4 BN/E 4 IN 4 PU-S 4 CPS 4 CPS 4 966 BYTES * 4 57 515 01 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 22 779 91 4 22 779 91 4 22 779 91 4 22 779 91 4 98 211 23 4 98 211 23 4 98 211 23 76 Tape File Start Depth = 12996.000000 Tape File End Depth = 12276.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28821 datums Tape Subfile: 2 409 records... Minimum record length: 62 bytes Maximum record length: 966 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 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.2500 MLL 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) : VENDOR TOOL CODE START DEPTH GR 12299.0 DLL 12351.0 12376.0 12324.0 12380.0 STOP DEPTH 12911.5 12963.5 12988.5 12935.0 12913.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL CHT BRID BRID MODL GR CN ZDL KNJT TEMP PCM KNJT MIS DLL FTS MIS MLL $ SWIVEL SUB CABLEHEAD TENSION BRIDLE ISOLATOR BRIDLE ISOLATOR MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB MICRO LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 25-JAN-94 FSYS REV. J001 VER. 1.1 200 24-JAN-94 734 25-JAN-94 13010.0 12989.0 12400.0 12989.0 1200.0 TOOL NUMBER 3944XA 3974XA 3997XA 3997XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 3967XA 1229EA/1229MA 3967XA 1233XA 9.875 2720.0 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHM/~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : 2-60/U-13 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA LSND 10.10 58.O 10.3 5.4 185.0 0.823 0.329 0.720 0.000 1.260 0.000 THERMAL SANDSTONE 2.65 0.000 0.0 74.0 185.0 71.0 0.0 63.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN DI DLL 68 1 IN RT DLL 68 1 OHMM RXO MLL 68 1 OHMM RMLL MLL 68 1 OHMM C24 MLL 68 1 IN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 30 739 95 0 4 20 068 10 1 4 02 969 15 1 4 71 857 46 1 4 40 980 02 1 4 52 443 33 1 4 09 884 61 1 16 PE ZDL 68 1 BN/E 4 17 C13 ZDL 68 1 IN 4 18 CNC 2435 68 1 PU-S 4 19 CNCF 2435 68 1 PU-S 4 20 CN 2435 68 1 PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 262 4 76 731 33 4 67 754 94 4 98 211 23 4 98 211 23 4 52 326 75 4 84 023 70 4 83 368 34 88 Tape File Start Depth = 12996.000000 Tape File End Depth = 12276.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66264 datums Tape Subfile: 3 351 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String ~1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12300.0 12477.5 DLL 12351.0 12530.0 MLL 12376.0 12554.5 ZDL 12324.0 12501.0 2435 12380.0 12479.5 $ 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): 25-JAN-94 FSYS REV. J001 VER. 1.1 200 24-JAN-94 841 25-JAN-94 13010.0 12989.0 12400.0 12989.0 1200.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL CHT BRID BRID MODL GR CN ZDL KNJT TEMP PCM KNJT MIS DLL FTS MIS MLL $ SWIVEL SUB CABLEHEAD TENSION BRIDLE ISOLATOR BRIDLE ISOLATOR MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB MICRO LATEROLOG TOOL NUMBER 3944XA 3974XA 3997XA 3997XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 3967XA 1229EA/1229MA 3967XA 1233XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 2720.0 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMTJM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : 2-60/U-13 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA LSND 10.10 58.0 10.3 5.4 185.0 0.823 0.329 0.720 0.000 1.260 0.000 THERMAL SANDSTONE 2.65 0.000 0.0 74.0 185.0 71.0 0.0 63.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN DI DLL 68 1 IN RT DLL 68 1 OHMM RXO MLL 68 1 OHMM RMLL MLL 68 1 OHMM C24 MLL 68 1 IN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 30 739 95 0 4 20 068 10 1 4 02 969 15 1 4 71 857 46 1 4 40 980 02 1 4 52 443 33 1 4 09 884 61 1 16 PE ZDL 68 1 BN/E 4 17 C13 ZDL 68 1 IN 4 18 CNC 2435 68 1 PU-S 4 19 CNCF 2435 68 1 PU-S 4 20 CN 2435 68 1 PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 105 4 76 731 33 4 67 754 94 4 98 211 23 4 98 211 23 4 52 326 75 4 84 023 70 4 83 368 34 88 Tape File Start Depth = 12562.000000 Tape File End Depth = 12274.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55341 datums Tape Subfile: 4 194 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 5 is type: LIS 94/ 2/ 3 01 **** REEL TRAILER **** 94/ 2/ 4 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 4 FEB 94 8:16a Elapsed execution time = 27.68 seconds. SYSTEM RETURN CODE = 0